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MEMORANDUM

FROM: Rachel Schmeltz , U.S. EPA, Climate Change Division

TO : Docket EPA

- HQ

- OAR

- 201 2

- 0934

DATE: March 1, 2013

SUBJECT: Table of 2013 Revisions to the Greenhouse Gas Reporting Rule

1.0 INTRODUCTION

The 2009 f

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

Since promul gation of the rule, the EPA has identified a number of technical issues that
need to be corrected and specific portions of the Mandatory Greenhouse Gases Reporting Rule
(hereafter referred to as ―Part 98‖) that need to be clarified. The EPA is proposing to amend
specific provisions in the Mandatory Reporting of Greenhouse Gases Rule to better reflect
industry practices and improvements in climate research, correct technical and editorial errors
that have been identified since promulgation , and to clarify or update certain provisions that have
been the subject of questions from reporting entities

.

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

this action

. The table in section 3.0 contains a list of each change proposed, the rule language for

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the current requirement, and the proposed language. A brief explanation of the reason for the
change is included for those items that are not specifically addressed in the preamble for this
proposal. These changes are minor clarifications of the requirements text to better reflect EPA’s
intent, simple corrections to calculation terms or cross

- references that do not revise the output of
the calculations, harmonizing changes within a subpart (such as changes to termin ology), simple
editorial and minor error corrections, or removal of redundant text. In total, these changes do not
represent a change in reporting burden. Also available in the docket for this action is a set of

documents in redline strikeout format for e ach section of Part 98 for which EPA is proposing
changes.

2.0 SUMMARY OF CHANGES INCLUDED

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

The amended tables are available in the redline document for the individual subpart and as

attachments to this memorandum. Tables that have been changed include: Table A

- 1, A

- 6, C

- 1,

C

- 2, AA

- 1, AA

- 2, HH

- 1, HH

- 2, new Table HH

- 4, MM

- 1 NN

- 1, NN

- 2, and TT

- 1.

Subpart

A

- General Provision

C

- General Stationary Fuel Combustion Sources

E

- Adipic Acid Production

G

– Ammonia Manufacturing

H

– Cement production

K

– Ferroalloy Production

L

– F luorinated Gas Production

N

– Glass Production

O

- HCFC

- 22 Production and HFC

- 23 Destruction

P

– Hydrogen Production

Q

- Iron & Steel Production

S

– Lime Manufacturing

V

- Nitric Acid Production

X

– Petrochemical Production

Y

– Petroleum Refineries

Z

- Phosphoric Acid Production

AA

- Pulp & Paper Manufacturing

BB

- Silicon Carbide Production

DD

- Electrical Transmission and Distribution Equipment Use

### 3 Subpart

FF

- Underground Coal Mines

HH

– Municipal Solid Waste Landfills

II

- Industrial Wastewater Treatment

MM

- Suppliers of Petroleum Products

NN

– Suppliers of Natural Gas and Natural Gas Liquids

PP

– Suppliers of Carbon Dioxide

QQ

- Importers and Exporters of Fluorinated Greenhouse Gases Contained in Pre

Charged Equipment or Closed Cell Foams

RR

- Geologic Sequestration of Carbon Dioxide

SS

- Electrical Equipment Manufacture or Refurbishment

TT

- Industrial Waste Landfills

UU

- Injection of Carbon Dioxide



### 3.0 SUMMARY OF TECHNICAL CORRECTION S AND OTHER AMENDMEN TS

The following table summarizes the amendments proposed for various subparts of Part 98

which are being addressed by the proposed 2013 Revisions to the Greenhouse Gas Reporting

Rule

.

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Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

A 98.3(c)(1) 98.3(c)(1) Facility name or supplier name (as

appropriate), and physical street address of the facility or supplier, including the city, State, and zip
code. 98.3(c)(1) Facility name or supplier name (as appropriate), and physical street address of the facility or supplier, including the city, State, and zip code. If the facility does not have a physical street address, then the facility must provide the latit ude and longitude representing the location of facility operations in decimal degree format. This must be provided in a comma

- delimited ―latitude, longitude‖ coordinate pair reported in decimal degrees to at least four digits to the right of the decimal. See preamble text for explanation

A 98.3(c)(11) (None) (viii) The facility or supplier must refer to the reporting instructions of the electronic GHG reporting tool regarding standardized conventions for the naming of a parent company. See preamble text for explanation

A 98.3(c )(13) (None) (13) ORIS code for each power generation unit that has been assigned an ORIS code by the Energy
Information Administration. See preamble text for explanation

A 98.3(h)(4) (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 Administr ator receives a request for extension of the 45

- day period, by e

- mail to an address prescribed by the Administrator, at least two days prior to the expiration of the 45

- day period, and the Administrator does not respond to the request by the end of such pe riod, 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 extension is reasonable and will provide any such addit ional extension. (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) an d (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 prior to the expiration of the 45

- day period, the extension request is deemed to be automatically granted for 30 days. The Administrator may grant an additional extension beyond the automatic 30

- day extension if the owner or operator submits a request for an additional extension and the request is received by the Administrator at least 5 business days prior to the expiration of the automatic 30

- day extension, provided the request demonstrates that it is not practicable to submit a revised report or information under paragraphs (h)(1) and (h)(2) with 75 days. The See preamble text for explanat ion

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Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change Administrator will approve the extension request if the request demonstrates that it is not practicable to collect and process the data needed to resolve potential reporting errors identified pursuant to paragraphs (h)(1) or (h)(2) of this section within 75 days.

A 98.3(j)(3)(ii) (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 request, but in any event no later than 4
weeks before the date f

or the planned process equipment or unit shutdown that was provided in the original request. (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 exten d the 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 or most recently approved request. Clarifies BAMM requirement.

A 98.3(k)(1) (None) (k) Revised Global Warming Potentials. (1) General. Starting with reporting year 2013, facilities and suppliers must use the revised GWPs in
Table A

- 1 of this subpart, Global Warming Potentials (revised 2013), for calculating CO 2 e emissions for determinin g applicability to this part and for calculating CO 2 e emissions in annual GHG
reports. S ee preamble text for explanation

A 98.3(k)(2) (None) (2) Special provision for reporting year 2013. A facility or supplier that was not subject a subpart of part 98 for reporting year 2012, but becomes subject a subpart due to a change in the GWP for one or more compounds in Table A

- 1 of this subpart, Global Warming Potentials (revised 2013), is not required to submit an annual GHG for reporting year
2013. Such facil ities or suppliers must start monitoring and collecting GHG data in compliance with this part starting on January 1, 2014, and submit an annual greenhouse gas report for reporting year 2014 by March 31, 2015. See preamble text for explanation

A 98.3(l) (N one) (l) Special provision for best available monitoring See preamble text for explanation

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Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change methods in 2014. This paragraph applies to owners or operators of facilities or suppliers that first become subject to any subpart of part 98 due to an
amendment to Table A

- 1 of this subpart, Global Warming Potentials (revised 2013).

A 98.3(l)(1) (None) (1) Best available monitoring methods. From January 1, 2014 to March 31, 2014, owners or
operators subject to this paragraph may use best available monitoring methods for any parameter (e.g., fuel use, feedstock rates ) 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 req uired piece of monitoring equipment by January 1, 2014. Starting no later than April 1, 2014, 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 p rovided in paragraph (l)(2) of this section. Best available monitoring methods means any of the following
methods: See preamble text for explanation

A 98.3(l)(1)(i)

- (iv) (None) (i) Monitoring methods currently used by the facility
that do not meet the specifications of a relevant subpart. (ii) Supplier data. (iii) Engineering calculations. (iv) Other company records. See preamble text for explanation

A 98.3(l)(2) (None) (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, 2014. (i) Timing of request. The extension request must be
submitted to EPA no later than January 31, 2014. See preamble text for explanation

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Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change (ii) Content of re quest. Requests must contain the following information:

A 98.3(l)(2)(ii)( A) (None) (A) A list of specific items of monitoring instrumentation for which the request is being made and the locations where each piece of monit oring
instrumentation will be installed. See preamble text for explanation

A 98.3(l)(2)(ii)( B) (None) (B) Identification of the specific rule requirements (by rule subpart, section, and paragraph numbers) for
which the instrumentation is needed. See preamble text for explanation

A 98.3(l)(2)(ii)( C) (None) (C) A description of the reasons that the needed equipment could not be obtained and installed before April 1, 2014. See preamble text for explanation

A 98.3(l)(2)(ii)( D) (None) (D) If the reason for the extension is that the equipment cannot be purchased and delivered by April 1, 2014, supporting documentation such as the date the monitoring equipment was ordered, investigation of alternative suppliers and the dates by
which alte rnative vendors promised delivery, backorder notices or unexpected delays, descriptions of actions taken to expedite delivery, and the current expected date of delivery. See preamble text for explanation

A 98.3(l)(2)(ii)( E) (None) (E) If the reason for th e 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 shut down. 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 [THE DATE OF PUBLICATION
OF THE FINAL RULE IN THE FEDERAL REGISTER] and April 1, 2014, include a justification of why the equipment could not be obtained and installed during that shutdown. See preamble text for explanation

A 98.3(l)(2)(ii)( F) (None) (F) A description of the specific actions the facility will take to obtain and install the equipment as soon See pr eamble text for explanation

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Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change as reasonably feasible and the expected date by which the equipment will be installed and operating.

A 98.3(l)(2)(iii) (None) (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, 2014. The use of
best available methods under this subsection (l) will not be approved beyond December 31 , 2014. See preamble text for explanation

A 98.6 Continuous bleed means a continuous flow of

pneumatic suppl y 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 compared with the process se t

- point to adjust gas pressure in
the valve actuator. Continuous bleed means a continuous flow of pneumatic supply natural gas to the process control 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 compared with the process set

- point to adjust gas pressure in
the valve actuator. Clarifies definition

A 98.6 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 surface pre

- mining, horizontal pre

- mining, and post

- mining systems. Degasification system means the entirety of the equipment that is used to drain gas from underground coal mines. This includes all degasification wells and gob gas vent holes at the underground c oal mine. Degasification systems include gob and premine surface drainage wells, gob and premine in

- mine drainage wells, and in

- mine gob and premine cross

- measure borehole wells. See preamble text for explanation

A 98.6 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. Intermittent bleed pneumatic devices mean automated flow control devices powered by pressurized natural gas and used for automatically maintaining a process condition such as liquid level, pressure, delta

- pressure and temperature. These are

snap

- acting or throttling devices that discharge al l or a portion of the full volume of the actuator intermittently when control action is necessary, but does not bleed continuously. Clarifies definition

A 98.6 (None) Fluidized Bed Combustor (FBC) means a combustion technology (e.g., a fluidized bed boiler) where the maximum steady

- state temperature See preamble text for explanation

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Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change reached within the combustor (excluding periods of startup, shutdown, and malfunction) during the combustion of solid fuels (e.g., coal, tire derived fuel, wood and wood residuals, a gricultural byproducts, coke, municipal solid waste, or mixtures of such fuels) is less than or equal to 19,900 degrees

F.

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

A 98.6 Ventilation system means a system that is used to

control the concentration of methane and other gases within mine working areas through m ine 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. Ventilat ion 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 min e workings to dilute methane
concentrations. See preamble text for explanation

A 98.6 98.6 No definition ORIS Code means the unique identifier assigned to each power plant in the National Electric Energy Data System (NEEDS). The ORIS code is a 4 digit number assigned by the Energy Information Administration (EIA) at US Department of Energy to power plants owned by uti lities. Definition added for new term used in rule

A Table A

- 1 Table A

- 1 See Appendix A for changes to Table A

- 1 See preamble text for explanation

A Table A

- 6 Table A

- 6 See Appendix A for changes to Table A

- 6 Changed numbering of two data elements for subpart

HH

C 98.33(b)(1) (None) (viii) May be used for the combustion of a fuel listed
in Table C

- 1 if the fuel is combusted in a unit with a maximum rated heat input capacity greater than 250 mmBtu/hr (or, pursuant to §98.36(c)(3), in a group of
units served by a common supply pipe, having at least one unit with a maximum rated heat input capacity greater than 250 mmBtu/hr), provided that both of the following conditions apply: (A) The use of Tier 4 is not required. (B) The fuel provides less than 10 pe rcent of the See preamble text for explanation

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Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change annual heat input to the unit, or if §98.36(c)(3) applies, to the group of units served by a common supply pipe.

(ix) May not be used for the combustion of waste coal (i.e., waste anthracite (culm) and waste bituminous (gob)).

C 98.33(b)(3)(ii )(A) (A) The use of Tier 1 or 2 is permitted, as described

in paragraphs (b)(1)(iii), (b)(1)(v), and (b)(2)(ii) of
this section. (A) The use of Tier 1 or 2 is permitted, as described in paragraphs (b)(1)(iii), (b)(1)(v ), (b)(1)(viii), and (b)(2)(ii) of this section. Harmonizing change with addition of paragraph 98.33(b)(1)(viii).

C 98.33(e)(1)(ii ) (ii) The procedures in paragraph (e)(5) of this

section. (ii) The procedures in paragraph (e)(4) of this
section. Corrects reference

C 98.33(e)(3)(iv )(B) (B) Multiply the result from paragraph (e)(3)(iv)(A)

of this section by the appropriate default factor to determine the annual biogenic CO 2 emissions, in metric tons. For MSW, use a default factor of 0.6 and for tires, use a default factor of 0.20. (B) Multiply the result from paragraph (e)(3)(iv)(A) of this section by the appropriate default factor to determine the annual biogenic CO 2 emissions, in metric tons. For MSW, use a default factor of 0.55 and for tires, use a defa ult factor of 0.20. See preamble text for explanation

C

98.36(b)(3) (3) Maximum rated heat input capacity of the unit in

mmBtu/hr for boilers and process heaters only and
relevant units of measure for other combustion units. (3) Maximum rated heat input capacity of the unit in
mmBtu/hr. Standardize units of measure for all reporters.

C 98.36(c)(3) (3) ...As a second example, in accordance with

§98.33(b)(1)(v), Tier 1 may be used regardless of unit size when natural gas is transported through the common pipe, if the annual fuel consumption is obtained from gas billing records in units of therms.

... (3) ...As a second example, in accordance with §98.33(b)(1)(v), Tier 1 may be used regardless of unit size when natural gas is transported through the common pipe, if the annual fuel consumption is obtained from gas billing records in units of therms

or mmB t u

. ... Consistency across the subpart

C Table C

- 1 Table C

- 1 See Appendix A for changes to Table C

- 1 See preamble text for explanation

C Table C

- 2 Table C

- 2 See Appendix A for changes to Table C

- 2 See preamble text for explanation

E 98.53(b)(3) (3) You must measure the adipic acid production rate

during the test and calculate the production rate for the test period in metric tons per hour. (3) You must measure the adipic acid production rate during the test and calculate the production rate for the test period in tons per hour. Corrects a requirement for consistency throughout the subpart.

E 98.53(d) (d) If any N 2 O abateme nt technology ―N‖ is located

after your test point, you must determine the destruction efficiency according to paragraphs (d)(1), (2), or (3) of this section. (d) If the adipic acid production unit exhausts to any

N 2 O abatement technology ―N‖, you must determine the destruction efficiency according to paragraphs (d)(1), (d)(2), or (d)(3) of this section. Clarifies requirement.

E 98.53(e) (e) If any N 2 O abatement technology ―N‖ is located

after your test point, you mu st determine the annual (e) If the adipic acid production unit exhausts to any

N 2 O abatement technology ―N‖, you must determine Clarifies requirement.

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Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change amount of adipic acid produced while N 2 O abatement technology ―N‖ is operating according to §98.54(f). Then you must calculate the abatement
factor for N 2 O abatement technology ―N‖ according to Equation E

– 2 of this section. the annual amount of adipic acid produced while

N 2 O abatement technology ―N‖ is operating according to §98.54(f). Then you must calculate the
abatement factor for N 2 O abatement technology ―N‖ according to Equation E

– 2 of this section.

E 98.53(e) Equation E

- 2 Harmonizes equation with its definition.

E 98.53(g)(1) DF = Destruction efficiency of N 2 O abatement

technology ―N‖ (percent of N 2 O removed from vent stream). DF = Destruction efficiency of N 2 O abatement technology ―N‖ (decimal fraction of N 2 O removed from vent stream). Clarifies a calculation term.

E 98.53(g)(1) AF = Abatement utilization factor of N 2 O abatement

technology ―N‖ (percent of time that the abatement technology is operating). AF = Abatement utilization factor of N 2 O abatement technology ―N‖ (decimal fraction of time that the abatement technology is ope rating). Clarifies a calculation term.

E 98.53(g)(2) DF 1 = Destruction efficiency of N 2 O abatement

technology 1 (percent of N 2 O removed from vent stream). DF1 = Destruction efficiency of N 2 O abatement technology 1 (decimal fraction of N 2 O removed from vent stream). Clarifies a calculation term.

E 98.53(g)(2) AF 1 = Abatement utilization factor of N 2 O abatement

technology 1 (percent of time that abatement technology 1 is operating). AF1 = Abatement utilization factor of N 2 O abatement technology 1 (decimal fraction of time that abatement technology 1 is operating). Clarifies a calculation term.

E 98.53(g)(2) DF 2 = Destruction efficiency of N 2 O abatement

technology 2 (percent of N 2 O removed from vent stream). DF 2 = Destruction efficiency of N 2 O abatement technology 2 (decimal fraction of N 2 O removed from vent stream). Clarifies a calculation term.

E 98.53(g)(2) AF 2 = Abatement utilization factor of N 2 O abatement

technology 2 (percent of time that abatement
tech nology 2 is operating). AF2 = Abatement utilization factor of N 2 O abatement technology 2 (decimal fraction of time that abatement technology 2 is operating). Clarifies a calculation term.

E 98.53(g)(2) DF N = Destruction efficiency of N 2 O abatement technology N (percent of N 2 O removed from vent stream). DF N = Destruction efficiency of N 2 O abatement technology ―N‖ (decimal fraction of N 2 O removed from vent stream). Clarifies a calculation term.

E 98.53(g)(2) AF N = Abatement utilization factor of N 2 O

abatement technology N (percent of time that abatement technology N is operating). AF N = Abatement utilization factor of N 2 O abatement technology ―N‖ (decimal fraction of time that abatement technology N is operating)

. Clarifies a calculation term.

E 98.53(g)(3) DF N = Destruction efficiency of N 2 O abatement technology ―N‖ (percent of N 2 O removed from vent stream). DF N = Destruction efficiency of N 2 O abatement technology ―N‖ (decimal fraction of N 2 O removed from vent stream). Clarifies a calculation term.

E 98.53(g)(3) AF N = Abatement utilization factor of N 2 O

abatement technology ―N‖ (percent of time that the AF N = Abatement utilization factor of N 2 O
abatement t echnology ―N‖ (decimal fraction of time Clarifies a calculation term.

### 12

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change abatement technology is operating). that the abatement technology is operating).

E 98.53(g)(3) FC N = Fraction control factor of N 2 O abatement

technology ―N‖ (percent of total emissions from unit ―z‖ that are sent to abatement technology ―N‖). FC N = Fraction control factor of N 2 O abatement technology ―N‖ (decimal fraction of total emissions
from unit ―z‖ that are sent to abatement tech nology ―N‖). Clarifies a calculation term.

E 98.54(e) (e) You must determine the monthly amount of

adipic acid produced. You must also determine the monthly amount of adipic acid produced during
which N 2 O abatement technology, located after the test point, is operating. These monthly amounts are determined according to the methods in paragraphs (c)(1) or (2) of this section. (e) You must determine the monthly amount of adipic acid produced. You must also d etermine the monthly amount of adipic acid produced during
which N 2 O abatement technology is operating. These monthly amounts are determined according to the methods in paragraphs (c)(1) or (c)(2) of this section. Corrects a requirement for consistency thr oughout the subpart.

E 98.54(f) (f) You must determine the annual amount of adipic

acid produced. You must also determine the annual amount of adipic acid produced during which N 2 O abatement technology located after the test point is operating. These are determined by summing the respective monthly adipic acid production quantities determined in paragraph (e) of this section. (f) You must determine the annual amount of adipic acid p roduced. You must also determine the annual amount of adipic acid produced during which N 2 O abatement technology is operating. These are determined by summing the respective monthly adipic acid production quantities determined in paragraph (e) of this sect ion. Corrects a requirement for consistency throughout the subpart.

G 98.73(b)(4) (4) You must calculate the annual process CO 2

emissions from each ammonia processing unit k at your facility summing emissions, as applicable from Equation G

– 1, G

– 2, and G

– 3 of this section using Equation G

– 4. (4) You must calculate the annual process CO 2 emissions from each ammonia processing unit k at your facility according to Equation G

- 4 of this
section: Clarifies calculation methodologies.

G 98.73(b)(4) Equation G

- 4 (Eq. G

- 4) Corrects a calculation term

G 98.73(b)(5) Equation G

- 5 (Eq. G

- 5) Corrects a calculation term

G 98.73(b)(5) E CO 2 k = Annual CO 2 emissions from each ammonia

processing unit (metric tons). E CO 2 ,k = Annual CO 2 emissions from each ammonia processing unit k (metric tons). Clarifies a calculation term.

G 98.73(b)(5) n = Total number of ammonia processing units. j = Total number of ammonia processing units. Corrects a calculation term

G 98.75(b) (b) For missing feedstock supply rates or waste (b) For missing feedstock supply rates used to Correction to missing data procedures to remove

### 13

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change recycle stream used to determine monthly feedstock consumption or monthly waste recycle stream quantity, you must determine the best available estimate(s) of the parameter(s), based on all available process d ata. determine monthly feedstock consumption , you must determine the best available estimate(s) of the parameter(s), based on all available process data. reference to parameters that are no longer part of the regulations.

G 98.76(a) (a) If a CEMS is used to measure CO 2 emissions,

then you must report the relevant information required under §98.36 for the Tier 4 Calculation Methodology and the following inf ormation in this paragraph (a): (a) If a CEMS is used to measure CO 2 emissions, then you must report the relevant information required under §98.36 for the Tier 4 Calculation Methodology and the information in paragraphs (a)(1) and (a)(2) of this section: Clarifies a requirement.

G 98.76(b) (b) If a CEMS is not used to measure emissions, then

you must report the following information: (b) If a CEMS is not used to measure emissions, then you must report all of the following information in this paragraph (b): Clarifies that all information must be reported.

G 98.76(b)(13) (13) CO 2 from the steam reforming of a hydrocarbon

or the gasification of solid and liquid raw material at the ammonia manufacturing process unit used to produce urea and the method used to determine the
CO 2 consumed in urea production. (13) Annual CO 2 emissions (metric tons) from the steam reforming of a hydrocarbon or the gasification of solid and liquid raw material at the ammonia manufacturing process unit used to produce urea and
the method used to determine the CO 2 consumed in urea production. Clarifies the units of the CO 2 emissions.

H 98.86(a)(2) (2) Monthly cement production from each kiln at the

facility. (2)Annual facility cement production. See preamble text for explanation

K 98.113(d)(1) Equation K

- 3

2000/2205 = Conversion factor to convert

tons to metric tons. 2/2205 = Conversion factor to convert kg CH 4 /ton of product to metric tons CH 4
. See preamble text for explanation

K 98.116(e)(2) No current requirement (2) Annual process CH 4 emissions (in metric tons) from each EAF used for the production of any ferroalloy listed in Table K

– 1 of this subpart. See preamble text for explanation

### 14

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

L 98.126(j) Introductory paragraph (j) Special provisions for reporting years 2011 and

2012 only. For reporting years 2011 and 2012, the owner or operator of a facility must comply with paragraphs (j)(1), (j)(2), and (j)(3) of this section. (j) Special provisions for reporting years 2011, 2012, and 2013 only. For reporting years 2011, 2012, and 2013, the owner or operator of a facility must comply with paragraphs (j)(1), (j)(2), and (j)(3) of
this section. See preamble text for explanation

L 98.126(j)(1) (1) Timing. The owner or operator of a facility is not

required to report the data elements at §98.3(c)(4)(iii) and §98.126(a)(2), (a)(3), (a)(4), (a)(6), (b), (c), (d), (e), (f), (g), and (h) of this section until the later of March 31, 2014 or the date set forth for that data element at §98.3(c)(4)(vii) and Table A

– 7 of Subpar t A of this part. (1) Timing. The owner or operator of a facility is not required to report the data elements at §98.3(c)(4)(iii) and §98.126(a)(2), (a)(3), (a)(4), (a)(6), (b), (c), (d), (e), (f), (g), and (h) of this section until the later of March 31, 2015 or the date set forth for that data element at §98.3(c)(4)(vii) and Table A

– 7 of Subpart A of this part. See preamble text for explanation

L 98.126(j)(3)(i ) (i) If you choose to use a default GWP rather than

your best estimate of the GWP for fluorinated GHGs
whose GWPs are not listed in Table A

– 1 to this subpart, use a default GWP of 10,000 for fluorinated GHGs that are fully fluorinated GHGs and use a
default GWP of 2000 for other fluorinated GHGs. (i) If you choose to use a default GWP rath er than your best estimate of the GWP for fluorinated GHGs
whose GWPs are not listed in Table A

– 1 of s ubpart A of this part, use a default GWP of 10,000 for fluorinated GHGs that are fully fluorinated GHGs
and use a default GWP of 2000 for other fluorinate d
GHGs. Correction to referenced table

N 98.143 Introductory paragraph You must calculate and report the annual process

CO 2 emissions from each continuous glass melting furnace using the procedure in paragraphs (a) and (b)
of this section. You must calculate and report the annual process
CO 2 emissions from each continuous glass melting furnace using the procedure in paragraphs (a) through (c) of this section. Corrects reference

N 98.143(b) (b) For each continuous glass melting furnace that is

not subject to the requirements in paragraph (a) of this section, calculate and report the process and
combustion CO 2 emissions from the glass melting furnace by using either the procedure in paragraph (b)(1) of this section or the procedure in paragraphs (b)(2) through (b)(7) of this section, except as specified in paragraph (c) of this section. (b) For each continuous glass melting furnace that is not subject to the requirements in paragraph (a) of
thi s section, calculate and report the process and
combustion CO 2 emissions from the glass melting furnace by using either the procedure in paragraph (b)(1) of this section or the procedure in paragraph (b)(2) of this section, except as specified in paragraph (c) of this section. Corrects reference

N 98.143(b)(2)( iv) MF i = Annual average mass fraction of carbonate

based mineral i in carbonate

- based raw material i (percentage, expressed as a decimal). MF i = Annual average decimal mass fraction of
carbonate

- ba sed mineral i in carbonate

- based raw
material i. Clarifies the equation term

N 98.143(b)(2)( iv) F i = Fraction of calcination achieved for carbonate

based raw material i, assumed to be equal to 1.0 (percentage, expressed as a decimal). F i = Decimal fraction of calcination achieved for
carbonate

- based raw material i, assumed to be equal
to 1.0. Clarifies the equation term

N 98.144(b) (b) You must measure carbonate

- based mineral mass

fractions at least annually to verify the mass fraction (b) You must measure carbonate

- based mineral mass fractions at least annually to verify the mass fraction See preamble text for explanation

### 15

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

d ata provided by the supplier of the raw material; such measurements shall be based on sampling and chemical analysis using ASTM D3682

– 01 (Reapproved 2006) Standard Test Method for Major
and Minor Elements in Combustion Residues from
Coal Utilization Proces ses (incorporated by reference, see §98.7) or ASTM D6349

– 09 Standard Test Method for Determination of Major and Minor Elements in Coal, Coke, and Solid Residues from Combustion of Coal and Coke by Inductively Coupled Plasma

— Atomic Emission Spectrometry (in corporated by reference, see §98.7). data provided by the supplier of the raw material; such measurements shall be based on sampling and
chemical analysis using consensus standards that specify X

- ray fluorescence. For measurements made in years prior to the emissions reporting year 2014, you may also use ASTM D3682

– 01 (Reapproved 2006) Standard Test Method for Major and Minor
Elements in Combustion Residues from Coal Utilization Processes (incorporated by reference, see §98.7) or ASTM D6349

– 09 Standard Test Method for Determination of Major and Minor Elements in Coal, Coke, and Solid Residues from Combustion of Coal and Coke by Inductively Coupled Pl asma

— Atomic Emission Spectrometry (incorporated by reference, see §98.7).

N 98.146(b)(4) (4) Carbonate

- based mineral mass fraction (percentage, expressed as a decimal) for each
carbonate

- based raw material charged to a

co ntinuous glass melting furnace. (4) Carbonate

- based mineral decimal mass fraction
for each carbonate

- based raw material charged to a continuous glass melting furnace. Clarifies the requirement

N 98.146(b)(6) (6) The fraction of calcination achieved for each

carbonate

- based raw material, if a value other than 1.0 is used to calculate process mass emissions of
CO 2
. (6) The decimal fraction of calcination achieved for
each carbonate

- based raw material, if a value other than 1.0 is used to calculate process mass emissions
of CO 2
. Clarifies the requirement

N 98.146(b)(7) (7) Method used to determine fraction of calcination. (7) Method used to determine decimal fraction of
calcination. Clarifies the requirement

N 98.147(b)(5) (5) The fraction of calcination achieved for each

carbonate

- based raw material (percentage, expressed as a decimal), if a value other than 1.0 is used to calculate process mass emissions of CO 2
. (5) The decimal fraction of calcination achieved for
each carbonate

- based raw material, if a value other than 1.0 is used to calculate process mass emissions
of CO 2
. Clarifies the requirement

O 98.153(c) (c) For HCFC

– 22 production facilities that do not

use a thermal oxidizer or that have a thermal ox idizer that is not directly connected to the HCFC

– 22 production equipment, HFC

– 23 emissions shall be estimated using Equation O

– 4 of this section: (c) For HCFC

– 22 production facilities that do not
use a destruction device or that have a destruction
device that is not directly connected to the HCFC

– 22 production equipment, HFC

– 23 emissions shall be estimated using Equation O

– 4 of this section: Harmonizing change for consistency of destruction device terminology within subpart.

O 98.153(d) (d) For HCFC

– 22 production facilities that use a

thermal oxidizer connected to the HCFC

– 22 production equipment, HFC

– 23 emissions shall be estimated using Equation O

– 5 of this section: (Eq. O

- 5) (d) For HCFC

– 22 production facilities that use a
destruction device connected to the HCFC

– 22 production equipment, HFC

– 23 emissions shall be estimated using Equation O

– 5 of this section: (Eq. O

- 5) Harmonizing change for consistency of destruction device terminology within subpart.

### 16

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

Where:

E D = Mass of HFC

– 23 emitted annually from thermal oxidizer (metric to ns), calculated using Equation O

– 8 of this section. Where:

E D = Mass of HFC

– 23 emitted annually from destruction device (metric tons), calculated using Equation O

– 8 of this section.

O 98.154(j) (j) The number of sources of equipment type t with

screening values less than 10,000 ppmv shall be the
difference between the number of leak sources of equipment type t that could emit HFC

- 23 and the number of sources of equipment type t with screening values greater than or equal to 10,000 ppmv as determined under paragraph (h) of this
section. (j) The number of sources of equipment type t with screening values less than 10,000 ppmv shall be the
difference between the number of leak sources of equipment type t that could emit HFC

- 23 and the number of sources of equipment type t with screening values greater than or equal to 10,000 ppmv as determined under paragraph (i) of this
section. Correct paragraph reference.

O 98.156(c) (c) Each HFC

- 23 destruction facility shall report the

concentration (mass fraction) of HFC

- 23 measured at the outlet of the destruction device during the facility's annual HFC

- 23 concentration
measurements at the outlet of the device. (c) Each HFC

- 23 destruction facility shall report the concentration (mass fraction) of HFC

- 23 measured at the outlet of the destruction device during the facility's annual HFC

- 23 concentration
measurements at the outlet of the device. If the
concentration of HFC

- 23 is below the detection limit of the measuring device, report the detection limit
and that the concentration is below the detection
limit. See preamble text for explanation

P 98.163(b) (b) Fuel and feedstock material balance approach

.

Calculate and report CO 2 emissions as the sum of the
annual emissions associated with each fuel and feedstock used for hydrogen production by following paragraphs (b)(1) through (b)(3) of this section. (b) Fuel and feedstock material balance approach. Calculate and report CO 2 emi ssions as the sum of the
annual emissions associated with each fuel and feedstock used for hydrogen production by following paragraphs (b)(1) through (b)(3) of this section. The carbon content and molecular weight shall be obtained from the analyses conduc ted in accordance with §98.164(b)(2), (b)(3), or (b)(4), as applicable, or from the missing data procedures in §98.165. If the analyses are performed annually, then the annual value shall be used as the monthly average. If the analyses are performed more f requently than monthly, use the arithmetic average of values See preamble text for explanation

### 17

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change obtained during the month as the monthly average.

P 98.163(b)(1) Fdstk

n = Volume of the gaseous fuel and feedstock

used in month n (scf (at standard conditions of 68 °F and atmospheric pressure) of fuel and feedstock).
CC

n = Average carbon content of the gaseous fuel and feedstock, from the results of one or more analyses for month n (kg carbon per kg of fuel and feedstock). If measurements are taken more frequen tly than monthly, use the arithmetic average
of measurement values within the month to calculate a monthly average.

MW

n = Average molecular weight of the gaseous
fuel and feedstock from the results of one or more analyses for month n (kg/kg

- mole). Fdstk

n = Volume of the gaseous fuel or feedstock used in month n (scf (at standard conditions of 68 °F and atmospheric pressure) of fuel or feedstock).
CC

n = Average carbon content of the gaseous fuel and feedstock for month n (kg carbon per kg of fuel
or feedstoc k).

MW

n = Average molecular weight of the gaseous fuel or feedstock for month n (kg/kg

- mole). Clarifies equation terms

P 98.163(b)(2) Fdstk

n = Volume of the liquid fuel and feedstock

used in month n (gallons of fuel and feedstock).
CC

n = Average carbon content of the liquid fuel and feedstock, from the results of one or more analyses for month n (kg carbon per gallon of fuel and feedstock). Fdstk

n =Volume of the liquid fuel or feedstock used in month n (gallons of fuel or feedstock).
CC

n = Average carbon content of the liquid fuel or feedstock, for month n (kg carbon per gallon of fuel or feedstock). Clarifies equation terms

P 98.163(b)(3) Fdstk

n = Mass of solid fuel and feedstock used in

month n (kg of fuel and feedstock).
CC

n = Averag e carbon content of the solid fuel and feedstock, from the results of one or more analyses for month n (kg carbon per kg of fuel and feedstock). Fdstk

n = Mass of solid fuel or feedstock used in month n (kg of fuel or feedstock).
CC

n = Average carbon content of the solid fuel or feedstock, for month n (kg carbon per kg of fuel or feedstock). Clarifies equation terms

P 98.164(b)(3) (3) Determine the carbon content of fuel oil, naphtha,

and other liquid fuels and feedstocks at least

mo nthly, except annually for standard liquid hydrocarbon fuels and feedstocks having consistent composition, or upon delivery for liquid fuels delivered by bulk transport (e.g., by truck or rail). (3) Determine the carbon content of fuel oil, naphtha,
and ot her liquid fuels and feedstocks at least monthly, except annually for standard liquid hydrocarbon fuels and feedstocks having consistent composition, or upon delivery for liquid fuels and feedstocks delivered by bulk transport (e.g., by truck or rail). See preamble text for explanation

P 98.164(b)(4) (4) Determine the carbon content of coal, coke, and

other solid fuels and feedstocks at least monthly, except annually for standard solid hydrocarbon fuels and feedstocks having consistent composition, or

u pon delivery for solid fuels delivered by bulk transport (e.g., by truck or rail). (4) Determine the carbon content of coal, coke, and other solid fuels and feedstocks at least monthly, except annually for standard solid hydrocarbon fuels
and feedstocks ha ving consistent composition, or upon delivery for solid fuels and feedstocks delivered by bulk transport (e.g., by truck or rail). See preamble text for explanation

### 18

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

P 98.164(b)(5) (5) You must use the following applicable methods

to determine the carbon content for all fuels and feedstocks, and molecular weight of gaseous fuels and feedstocks. Alternatively, you may use the results of continuous chromatographic analysis of the fuel and feedstock, provided that the gas chromatograph (GC) is operated, maint ained, and calibrated according to the manufacturer's instructions; and the methods used for operation, maintenance, and calibration of the GC are documented in the written monitoring plan for the unit under §98.3(g)(5). (5) You must use the following app licable methods
to determine the carbon content for all fuels and feedstocks, and molecular weight of gaseous fuels and feedstocks. Alternatively, you may use the results of chromatographic analysis of the fuel and feedstock, provided that the chromatograp h is operated, maintained, and calibrated according to the manufacturer's instructions; and the methods used for operation, maintenance, and calibration of the chromatograph are documented in the written monitoring plan for the unit under §98.3(g)(5). See preamble text for explanation

P 98.164(c) (c) For units using the calculation methodologies

described in this section, the records required under §98.3(g) must include both the company records and a detailed explanation of how company records are
used to estimate the following: (1) Fuel and feedstock consumption, when solid fuel
and feedstock is combusted and a CEMS is not used
to measure GHG emissions. (2) Fossil fuel consumption, when, pursuant to §98.33(e), the owner or operator of a unit that uses
C EMS to quantify CO 2 emissions and that combusts both fossil and biogenic fuels separately reports the biogenic portion of the total annual CO 2 emissions. (3) Sorbent usage, if the methodology in §98.33(d) is
used to calculate CO 2 emissions from sorbent. (c ) [Reserved] See preamble text for explanation

P 98.164(d) (d) The owner or operator must document the

procedures used to ensure the accuracy of the estimates of fuel and feedstock usage and sorbent usage (as applicable) in paragraph (b) of this section, including, but not limited to, calibration of weighing equipment, fuel and feedstock 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 estima tes must be provided. (d) [Reserved] See preamble text for explanation

### 19

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

P 98.166(a)(2)

- (a)(3) (2) Annual quantity of hydrogen produced (metric

tons) for each process unit and for all units
combined. (3) Annual quantity of ammonia produced (metric tons), if applicable, for each process unit and for all
units combined. (2) Annual quantity of hydrogen produced (metric tons) for each process unit. (3) Annual quantity of ammonia produced (metric tons), if applicable for each process unit. See preamble text for explanation

P 98.167(c ) (None) (c) For units using the calculation methodologies described 98.163(b), the records required under §98.3(g) must include both the company records and a detailed explanation of how company records are
used to estimate the following: (1) Fuel and feedstock consumption, when solid fuel
and feedstock is combusted and a CEMS is not used
to measure GHG emissions. (2) Fossil fuel consumption, when, pursuant to §98.33(e), the owner or operator of a unit that uses CEMS to quantify CO 2 emissions and that combusts both fossil and biogenic fuels separately reports the biogenic portion of the total annual CO 2 emissions. (3) Sorbent usage, if the methodology in §98.33(d) is
used to calculate CO 2 emissions from sorbent. See preamble text for explanation

P 98.167(d) (None) (d) The owner or operator must document the procedures used to ensure the accuracy of the estimates of fuel and feedstock usage and sorbent usage (as applicable) in 98.163(b), including, but not limited to, calibrat ion of weighing equipment, fuel and feedstock 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 provided. See preamble text for explanation

Q 98.170 Introductory paragraph 98.170 Definition of the source category.

The iron and steel production source category includes facilities with any of the following processes: taconite iron ore processing, integrated iron and steel manufacturing, cokemaking not colocated with an integrated iron and steel manufacturing process, and electric arc furnace (EAF) steelmaking not colocated with an integrated 98.170 Definition of the source category

. The iron and steel production source category includes facilities with any of the following processes: taconite iron ore processing, integrated iron and steel manufacturing, cokemaking not
coloca ted with an integrated iron and steel manufacturing process, direct reduction furnaces not collocated with an integrated iron and steel See preamble text for explanation

### 20

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change iron and steel manufacturing process. Integrated iron and steel manufacturing means the production of steel from iron ore or iron ore pellets. At a minimum, an integrated iron and steel manufacturing process has a basic oxygen furnace for refining molten iron into steel. Each cokemaking process and EAF process located at a facility with an integrated iron and steel manufacturing process is part of the integrated iron and steel manuf acturing facility. manufacturing process, and electric arc furnace (EAF) steelmaking not colocated with an integrated
iron and steel manufa cturing process. Integrated iron and steel manufacturing means the production of steel from iron ore or iron ore pellets. At a minimum, an integrated iron and steel manufacturing process has a basic oxygen furnace for refining molten iron
into steel. Each cokemaking process and EAF process located at a facility with an integrated iron and steel manufacturing process is part of the integrated iron and steel manufacturing facility. Q 98.173(b)(1)( i) (C sf

) = Carbon content of the solid fuel, from the fuel analysis (percent by weight, expressed as a decimal fraction, e.g., 95% = 0.95). (C 0 ) = Carbon content of the greenball (taconite) pellets, from the carbon analysis results (percent by weight, expressed as a decimal fraction)

. (C p ) = Carbon content of the fired pellets, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C sf ) = Carbon content of the solid fuel, from the fuel analysis (expressed as a decimal fraction). (C 0 ) = Carbon content of the greenball (taconite) pellets, from the carbon analysis results (expressed as a decimal fraction). (C p ) = Carbon content of the fired pellets, from the carbon analysis results (expressed as a decimal fraction). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (expressed as a decimal fraction). Clarifies equation te rms

Q 98.173(b)(1)( i) (F

s ) = Annual mass of the solid fuel combusted

(metric tons). (F

s ) = Annual mass of the solid fuel used (metric tons). Clarifies equation term

Q 98.173(b)(1)( i) (F g ) = Annual volume of the gaseous fuel combusted

(scf). (F g ) = Annual volume of the gaseous fuel used (scf). Clarifies equation term

Q 98.173(b)(1)( i) (F l ) = Annual volume of the liquid fuel combusted

(gallons). (F l ) = Annual volume of the liquid fuel used (gallons). Clarifies equation term

Q 98.173(b)(1)( ii), (C Iron ) = Carbon content of the molten iron, from the

carbon analysis results (percent by weight, expressed as a decimal fraction). (C Scrap ) = Carbon content of the ferrous scrap, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C Flux ) = Carbon content of the flux materials, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C Carbon ) = Carbon content of the carbonaceous (C Iron ) = Carbon content of the molten iron, from the carbon analysis results (expressed as a de cimal fraction). (C Scrap ) = Carbon content of the ferrous scrap, from the carbon analysis results (expressed as a decimal fraction). (C Flux ) = Carbon content of the flux materials, from the carbon analysis results (expressed as a decimal fraction). (C Carbo n ) = Carbon content of the carbonaceous Clarifies equation terms

### 21

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change materials, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C Steel ) = Carbon content of the steel, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C Slag ) = Carbon content of the slag, from the carbon analysis (percent by weight, expressed as a decima l fraction). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (percent by weight, expressed as a decimal fraction). materials, from the carbon analysis results (expressed as a decimal fraction). (C Steel ) = Carbon content of the steel, from the carbon analysis results (expressed as a decimal fraction). (C Slag ) = Carbon content of t he slag, from the carbon analysis (expressed as a decimal fraction). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (expressed as a decimal fraction).

Q 98.173(b)(1)( iii) (C Coal ) = Carbon content of the coal, from the carbon

analysis results (percent by weight, expressed as a decimal fraction). (C Coke ) = Carbon content of the coke, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C R ) = Carbon co ntent of the air pollution control residue, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C Coal ) = Carbon content of the coal, from the carbon analysis results (expressed as a decimal fraction). (C Coke ) = Carbon co ntent of the coke, from the carbon analysis results (expressed as a decimal fraction). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (expressed as a decimal fraction). Clarifies equation terms

Q 98.173(b)(1)( iv) (C Feed ) = Carbon content of the mixed sinter feed

materials that form the bed entering the sintering machine, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C Sinter ) = Carbon content of the sinter pellets, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C Feed ) = Carbon content of the mixed sinter feed materials that form the bed entering the sintering machine, from the carbon analysis results (expressed as a decimal fraction). (C Sinter ) = Carbon content of the sinter pellets, from the carbon analysis results (expressed as a decima l fraction). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (expressed as a decimal fraction). Clarifies equation terms

Q 98.173(b)(1)( iv) (F g ) = Annual volume of the gaseous fuel combusted

(scf). (F g ) = Annua l volume of the gaseous fuel used (scf). Clarifies equation term

Q 98.173(b)(1)( v) (v) For EAFs, estimate CO 2 emissions using

Equation Q

- 5 of this section.

CO 2 =44/12*[(Iron)*(C Iron )+(Scrap)*(C Scrap )+(Flux)*(
C f )+(Electrode)*(C Electrode )+(Carbon)*(C

c )

- (Steel)*(C Steel )

- (Slag)*(C Slag )

- (R)*(C R ) (v) For EAFs, estimate CO 2 emissions using Equation Q

- 5 of this section.

CO 2 =44/12*[(Iron)*(C Iron )+(Scrap)*(C Scr ap )+(Flux)*(
C Flux )+(Electrode)*(C Electrode )+(Carbon)*(C Carbon )

- (Steel)*(C Steel )+(F g )*(C gf

)*MW/MVC*0.001

- (Slag)*(C Slag )

- (R)*(C R )] See preamb le text for explanation

### 22

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

Where:

CO 2 = Annual CO 2 mass emissions from the EAF (metric tons). 44/12 = Ratio of molecular weights, CO 2 to carbon. (Iron) = Annual mass of direct reduced iron (if any) charged to the furnace (metric tons). ( C Iron ) = Carbon content of the direct reduced iron, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (Scrap) = Annual mass of ferrous scrap charged to the furnace (metric tons). (C Scrap ) = Carbon content of the ferrous scrap, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (Flux) = Annual mass of flux materials (e.g., limestone, dolomite) charged to the furnace (metric tons). (C Flux ) = Carbon content of the flux materials, from
the carbon analysis results (percent by weight, expressed as a decimal fraction). (Electrode) = Annual mass of carbon electrode consumed (metric tons). (C Electrode ) = Carbon content of the carbon electrode, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (Carbon) = Annual mass of carbonaceous materials (e.g., coal, coke) charged to the furnace (metric tons). (C Carbon ) = Carbon content of the carbonaceous materials, from the carbon analysis results (percent by weight, expr essed as a decimal fraction). (Steel) = Annual mass of molten raw steel produced by the furnace (metric tons). (C Steel ) = Carbon content of the steel, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (Slag) = Annual ma ss of slag produced by the furnace (metric tons). Where:

CO 2 = Annual CO 2 mass emissions from the EAF (metric tons). 44/12 = Ratio of molecular weights, CO 2 to carbon. (Iron) = Annual mass of direct reduced iron (if any) charged to the furnace (metric tons). (C Iron ) = Carbon content of the direct reduced iron, from the carbon analysis results (expressed as a decimal fraction). (Scrap) = Annual mass of ferrous scrap charged to the furnace (metric tons). (C Scrap ) = Carbon content of the ferrous scrap, from the carbon analysis results (expressed as a decimal fraction). (Flux) = Annual mass of flux materials (e.g., limestone, dolomite) charged to the furnace (metric tons). (C Flux ) = Carbon content of the flux materials, from the carbon analysis results (expressed as a decimal fraction). (Electrode) = Annual mass of carbon electrode consumed (metric tons). (C Electrode ) = Carbon content of the carbon electrode, from the carbon analysi s results (expressed as a decimal fraction). (Carbon) = Annual mass of carbonaceous materials (e.g., coal, coke) charged to the furnace (metric tons). (C Carbon ) = Carbon content of the carbonaceous materials, from the carbon analysis results (expressed

as a decimal fraction). (Steel) = Annual mass of molten raw steel produced by the furnace (metric tons). (C Steel ) = Carbon content of the steel, from the carbon analysis results (expressed as a decimal fraction). (F g ) = Annual volume of the gaseous fuel used (scf at 60 degrees F and one atmosphere).

### 23

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change (C Slag ) = Carbon content of the slag, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (R) = Annual mass of air pollution control residue collected (metric tons). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C gf ) = Average carbon content of the gaseous fuel, from the fuel analysis results (kg C per kg of fuel). (MW) = Molecular weight of the gaseous fuel (kg/kg

- mole). (MVC) = Molar volume conversion factor (836.6 scf per kg

- mole at standard conditions of 60 degrees F and one atmosphere). (0.001) = Conversion factor from kg to metric tons. (Slag) = Annual mass of slag produced by the furnace (metric tons). (C Slag ) = Carbon content of the slag, from the carbon analysis r esults (expressed as a decimal fraction). (R) = Annual mass of air pollution control residue collected (metric tons). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (expressed as a decimal fraction). Q 98.173(b)(1)( vi) (vi) For decarburization vessels, estimate CO 2

emissions using Equation Q

- 6 of this section.

CO 2 =44/12*(Steel)*[(C Steelin )

- (C Steelout )]

- (R)*(C R )
Where:
CO 2 = Annual CO 2 mass emissions from the
decarburization vessel (metric tons). 44/12 = Ratio of molecular weights, CO 2 to carbon. (Steel) = Annual mass of molten steel charged to the vessel (metric tons). (C Steelin ) = Carbon content of the molten steel before decarburization, from the carbon analysis results (pe rcent by weight, expressed as a decimal fraction). (C Steelout ) = Carbon content of the molten steel after decarburization, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (R) = Annual mass of air pollution control res idue collected (metric tons). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (vi) For decarburization vessels, estimate CO 2 emissions using Equation Q

- 6 of this section.

CO 2 =44/12*{(Steel)*[(C Steelin )

- (C Steelout )]

- (R)*(C R )}
Where:
CO 2 = Annual CO 2 mass emissions from the decarburization vessel (metric tons). 44/12 = Ratio of molecular weights, CO 2 to carbon. (Steel) = Annual mass of molten steel charged to the vessel (metric tons). (C Steelin ) = Carbon content of the molten steel before decarburization, from the carbon analysis results (expressed as a decimal fraction). (C Steelout ) = Carbon content of the molten steel after decarburization, from the carbon a nalysis results (expressed as a decimal fraction). (R) = Annual mass of air pollution control residue collected (metric tons). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (expressed as a decimal fraction). C larifies the order of operations in the equation.

### 24

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change Q 98.173(b)(1)( vii) (F g ) = Annual volume of the gaseous fuel combusted

(scf). (F g ) = Annual volume of the gaseous fuel used (scf). Clarifies equation term

Q 98.173(b)(1)( vii) (C Ore ) = Carbon content of the iron ore or iron ore

pellets, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C Carbon ) = Carbon content of the carbonaceous materials, from the carbon analysis results (percent by weight, expressed as a decimal f raction). (C Other ) = Average carbon content of the other materials charged to the furnace, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C Iron ) = Carbon content of the iron, from the carbon analysis results (percen t by weight, expressed as a decimal fraction). (C NM ) = Carbon content of the non

- metallic materials, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C R ) = Carbon content of the air pollution control residue, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C Ore ) = Carbon content of the iron ore or iron ore pellets, from the carbon analysis results (expressed as a decimal fraction). (C Carbon ) = Carbon content of the carbonaceous

m aterials, from the carbon analysis results (expressed as a decimal fraction). (C Other ) = Average carbon content of the other materials charged to the furnace, from the carbon analysis results (expressed as a decimal fraction). (C Iron ) = Carbon content of t he iron, from the carbon analysis results (expressed as a decimal fraction). (C NM ) = Carbon content of the non

- metallic materials, from the carbon analysis results (expressed as a decimal fraction). (C R ) = Carbon content of the air pollution control
residu e, from the carbon analysis results (expressed as a decimal fraction). Clarifies equation terms

Q 98.173(c ) (c) You must determine emissions of CO 2 from the

coke pushing process in mt CO 2 e by multiplying the metric tons of coal charged to the coke ovens during the reporting period by 0.008. (c) You must determine emissions of CO 2 from the coke pushing process in mt CO 2 e by multiplying the metric tons of coal charged to the by

- product recovery and non

- recovery coke ovens during the reporting period by 0.008. Clarifies requirement.

Q 98.173(d) (d)If GHG emissions from a taconite indurating

furnace, basic oxygen furnace, non

- recovery coke oven battery, sinter process, EAF, decarburization vessel, or direct reduction furnace are vented through
the same st ack as any combustion unit or process equipment that reports CO 2 emissions using a CEMS that complies with the Tier 4 Calculation Methodology in subpart C of this part (General Stationary Fuel Combustion Sources), then the calculation methodology in paragr aph (b) of this section shall not be used to calculate process emissions. The owner or operator shall report under this subpart the combined stack emissions according (d)If GHG emissions from a taconite indurating furnace, basic oxygen furnace, non

- recovery coke oven battery, sinter process, EAF, decarburization vessel, or direct reduction furnace are vented through a stack equipped with a CEMS that complies with
the Ti er 4 methodology in subpart C of this part, or through the same stack as any combustion unit or process equipment that reports CO 2 emissions using a CEMS that complies with the Tier 4 Calculation Methodology in subpart C of this part (General Stationary Fu el Combustion Sources), then the calculation methodology in paragraph (b) of this section shall not be used to calculate process See preamble text for explanation

### 25

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change to the Tier 4 Calculation Methodology in §98.33(a)(4) and all associated requirements for Tier 4 in subpart C of this part (General Stationary Fuel Combustion Sources). emissions. The owner or operator shall report under this subpart the combined stack emissions according
to the Tier 4 Calculati on Methodology in §98.33(a)(4) and comply with all associated requirements for Tier 4 in subpart C of this part (General Stationary Fuel Combustion Sources). Q 98.174(b)(1) (1) Except as provided in paragraph (b)(4) of th is

section, determine the mass of each process input and output other than fuels using the same plant instruments or procedures that are used for accounting purposes (such as weigh hoppers, belt weigh feeders, weighed purchased quantities in shipments or c ontainers, combination of bulk density and volume measurements, etc.), record the totals for each process input and output for each calendar month, and sum the monthly mass to determine the annual mass for each process input and output.
Determine the mass rate of fuels using the procedures for combustion units in §98.34. (1) Except as provided in paragraph (b)(4) of this section, determine the mass of each process input and output other than fuels using the same plant instruments or procedures that are used for accounting purposes (such as weigh hoppers, belt weigh feeders, weighed purchased quantities in shipments or containers, combination of bulk density and volume measurements, etc.), record the totals for each process input and output for each calendar month, and sum the monthly mass to determine the annual mass for each process input and output. Determine the mass rate of fuels using the procedures for combustion units in §98.34. No determination of the mass of steel output from
decarburization vessels is required. See preamble text for explanation

Q 98.174(c )(2) (2)For the furnace exhaust from basic oxygen

furnaces, EAFs, decarburization vessels, and direct reduction furnaces, sample the furnace exhaust for at least three complete production cycles that start when the furnace is being charged and end after steel or iron and slag have been tapped. For EAFs that produce both carbon steel and stainless or specialty (low carbon) steel, develop an emission factor for the production of both types of steel. (2)(i) For the exhaust from basic oxygen furnaces, EAFs, decarburization vessels, and direct reduction furnaces, sample the furnace exhaust for at least three complete production cycles that start when the furnace is being charged and end after steel or i ron and slag have been tapped. For EAFs that produce both carbon steel and stainless or specialty (low carbon) steel, develop an emission factor for the production of both types of steel. (ii) For the exhaust from continuously charged EAFs, sample the exha ust for a period spanning at least three three hours. For EAFs that produce both carbon steel and stainless or specialty (low carbon) steel, develop an emission factor for the production of both types of steel. See preamble text for explanation

Q 98.175(a ) (a) For each missing data for the carbon content of

inputs and outputs for facilities that estimate emissions using the carbon mass balance procedure (a) Except as provided in §98.174(b)(4), 100 percent data availability is required for the carbon content of inputs and outputs for facilities that es timate See preamble text for explanation

### 26

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change in §98.173(b)(1) or for facilities that estimate emissions using the site

- specific emission factor

proce dure in §98.173(b)(2); 100 percent data availability is required. You must repeat the test for average carbon contents of inputs and outputs according to the procedures in §98.174(b)(2). Similarly, you must repeat the test to determine the
site

- specific em ission factor if data on the CO 2 emission rate, process production rate or process feed rate are missing. emissions using the carbon mass balance procedure in §98.173(b)(1) or facilities that estimate emissions using the site

- specific emission factor procedure in §98.173(b)(2).

Q 98.176(e) (e) If you use the carbon mass balance method in

§98.173(b)(1) to determine CO 2 emissions, you must report the following information for each process: (e) If you use the carbon mass balance method in §98.173(b)(1) to determine CO 2 emissions, you

must, exce pt as provided in §98.174(b)(4), report the following information for each process: See preamble text for explanation

Q 98.177(b) (b) When the carbon mass balance method is used to

estimate emissions for a process, the monthly mass of each process input a nd output that are used to
determine the annual mass. (b) When the carbon mass balance method is used to estimate emissions for a process, the monthly mass of each process input and output that are used to determine the annual mass, except that no
determin ation of the mass of steel output from decarburization vessels is required. Separate measurements of the mass of liquid steel input to the decarburization vessel and decarburized liquid steel output from the decarburization vessel are not required, because these masses are very nearly equal.

S 98.190 (a) (a) Lime manufacturing plants (LMPs) engage in the

manufacture of a lime product (e.g., calcium oxide, high

- calcium quicklime, calcium hydroxide, hydrated lime, dolomitic quicklime, dolomitic hydrate, or o ther lime products) by calcination of limestone, dolomite, shells or other calcareous substances as defined in 40 CFR 63.7081(a)(1). (a) Lime manufacturing plants (LMPs) engage in the manufacture of a lime product by calcination of limestone, dolomite, she lls or other calcareous substances as defined in 40 CFR 63.7081(a)(1). Clarifies the applicability.

S 98.193(a) (a) If all lime kilns meet the conditions specified in

§98.33(b)(4)(ii) or (b)(4)(iii), you must calculate and report under this subpart the c ombined process and
combustion CO 2 emissions by operating and maintaining a CEMS to measure CO 2 emissions according to the Tier 4 Calculation Methodology specified in §98.33(a)(4) and all associated requirements for Tier 4 in subpart C of this part (Genera l Stationary Fuel Combustion Sources). (a) If all lime kilns meet the conditions specified in §98.33(b)(4)(ii) or (b)(4)(iii), you must calculate and report under this subpart the combined process and
combustion CO 2 emissions from all lime kilns by operating and maintaining a CEMS to measure CO 2 emissions according to the Tier 4 Calculation Methodology specified in §98.33(a)(4) and all associated requirements for Tier 4 in subpart C of this part (General Stationary F uel Combustion Sources). Clarifies language.

S 98.193(b)(1) (1) Calculate and report under this subpart the

combined process and combustion CO 2 emissions by (1) Calculate and report under this subpart the combined process and combustion CO 2 emi ssions Clarifies language.

### 27

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change operating and maintaining a CEMS to measure CO 2 emissions from all lime kilns according to the Tie r 4 Calculation Methodology specified in §98.33(a)(4) and all associated requirements for Tier 4 in subpart C of this part (General Stationary Fuel Combustion Sources). from all lime kilns by operating and maintaining a
CEMS to measure CO 2 emissions from all lime kilns according to the Tier 4 Calculation Methodology specified in §98.33(a)(4) and all associated requirements for Tier 4 in subpart C of this part (Gene ral Stationary Fuel Combustion Sources).

S 98.193(b)(2) (2) Calculate and report process and combustion CO 2

emissions separately using the procedures specified in paragraphs (b)(2)(i) through (b)(2)(v) of this
section. (2) Calculate and report process and combustion CO 2 emissions from all lime kilns separately using the procedures specified in paragraphs (b)(2)(i) through (b)(2)(v) of this section. Clarifies language.

S 98.193(b)(2)( ii) (ii) You must calculate a monthly emission factor for

each type of calcined byproduct/waste sold (including lime kiln dust) using Equation S

– 2 of this
section: (ii) You must calculate a monthly emission factor for each type of calcined byproduct or waste sold (including lime kiln dust) us ing Equation S

– 2 of this
section: Clarifies language.

S 98.193(b)(2)( ii) EF LKD,I,N = Emission factor for calcined lime

byproduct/waste type i sold, for month n (metric tons
CO 2 /ton lime product. EF LKD,I,N = Emission factor for calcined lime byproduct or waste type i sold, for month n (metric

tons CO 2 /ton lime product. Clarifies a calculation term.

S 98.193(b)(2)( ii) CaO LKD,i,n = Calcium oxide content for calcined lime

byproduct/ waste type i sold, for mont h n (metric tons CaO / metric ton lime). CaO LKD,i,n = Calcium oxide content for calcined lime byproduct or waste type i sold, for month n (metric tons CaO / metric ton lime). Clarifies a calculation term.

S 98.193(b)(2)( ii) MgO LKD,i,n = Magnesium oxide content for calcined

lime byproduct/waste type i sold, for month n (metric tons MgO / metric ton lime). MgO LKD,i,n = Magnesium oxide content for calcined lime byproduct or waste type i sold, for month n (metric tons MgO / metric ton lime). Clarifies a calcu lation term.

S 98.193(b)(2)( iii) (iii) You must calculate the annual CO 2 emissions

from each type of calcined byproduct/waste that is not sold (including lime kiln dust and scrubber sludge) using Equation S

– 3 of this section: (iii) You must calculate the annual CO 2 emissions from each type of calcined byproduct or waste that is not sold (including lime kiln dust and scrubber sludge) using Equation S

– 3 of this section: Clarifies language.

S 98.193(b)(2)( iii) E waste,i = Annual CO 2 emissions for calcined lime

byproduct/waste type i that is not sold (metric tons
CO 2 ) E waste,i = Annual CO 2 emissions for calcined lime byproduct or waste type i that is not sold (metric tons
CO 2 ) Clarifies a calculation term.

S 98.193(b)(2)( iii) CaO wast e,i = Calcium oxide content for calcined lime

byproduct/ waste type i that is not sold (metric tons CaO / metric ton lime). CaO waste,i = Calcium oxide content for calcined lime byproduct or waste type i that is not sold (metric tons CaO / metric ton lime). Clarifies a calculation term.

S 98.193(b)(2)( iii) MgO Waste,i = Magnesium oxide content for calcined

lime byproduct/ waste type i that is not sold (metric tons MgO / metric ton lime). MgO Waste,i = Magnesium oxide content for calcined lime byproduct or waste type i that is not sold (metric tons MgO / metric ton lime). Clarifies a calculation term.

S 98.193(b)(2)( iii) M Waste,i = Annual weight or mass of calcined

byproducts/wastes for lime type i that is not sold M Waste,i = Annual weight or mass of calcined byproducts or wastes for lime type i that is not sold Clarifies a calculation term.

### 28

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change (tons). (tons).

S 98.193b(2)(iv ) (iv) You must calculate annual CO 2 process

emissions for all kilns using Equation S

– 4 of this
section: (iv) Y ou must calculate annual CO 2 process emissions for all lime kilns using Equation S

– 4 of
this section: Clarifies language.

S 98.193b(2)(iv ) E CO 2 = Annual CO 2 process emissions from lime

production from all kilns (metric tons/year). E CO2 = Annual CO 2 process emissions from lime production from all lime kilns (metric tons/year). Clarifies a calculation term and corrects subscripts.

S 98.193b(2)(iv ) EF LKD,i,n = Emission factor of calcined

byproducts/wastes sold for lime type i in calendar month n, (m etric tons CO 2 /ton byproduct/waste) from Equation S

– 2 of this section. EF LKD,i,n = Emission factor of calcined byproducts or wastes sold for lime type i in calendar month n, (metric tons CO 2 /ton byproduct or waste) from Equation S

– 2 of this section. Clarif ies a calculation term.

S 98.193b(2)(iv ) M LKD,i,n = Monthly weight or mass of calcined

byproducts/waste sold (such as lime kiln dust, LKD) for lime type i in calendar month n (tons). M LKD,i,n = Monthly weight or mass of calcined byproducts or waste sold (such as lime kiln dust, LKD) for lime type i in calendar month n (tons). Clarifies a calculation term.

S 98.193b(2)(iv ) E waste,i = Annual CO 2 emissions for calcined lime

byproduct/waste type i that is not sold (metric tons
CO 2 ) from Equation S

– 3 of this section. E waste,i = Annual CO 2 emissions for calcined lime byproduct or waste type i that is not sold (metric tons
CO 2 ) from Equation S

– 3 of this section. Clarifies a calculation term.

S 98.193b(2)(iv ) b = Number of calcined byproducts/wastes that are

sold. b = Number of calcined byproducts or wastes that are
sold. Clarifies a calculation term.

S 98.193b(2)(iv ) z = Number of calcined byproducts/wastes that are

not sold. z = Number of calcined byproducts or wastes that are
not sold. Clarifies a calculation term.

S 98.194(a) (a) You must determine the total quantity of each

type of lime product that is produced and each calcined byproduct/waste (such as lime kiln dust) that is sold. The quantities of each should be directly
measured monthly with the same plant instruments used for accounting purposes, including but not limited to, calibrated weigh feeders, rail or truck scales, and barge measurements. The direct measurements of each lime product shall be reconciled annually with the d ifference in the beginning of and end of year inventories for these products, when measurements represent lime sold. (a) You must determine the total quantity of each type of lime product that is produced and each calcined byproduct or waste (such as lime kiln dust) that is sold. The quantities of each should be directly measured monthly with the same plant instruments used for accounting purposes, including but not limited to, calibrated weigh feeders, rail or truck scales, and barge measurements. The dire ct measurements of each lime product shall be reconciled annually with the difference in the beginning of and end of year inventories for these products, when measurements represent lime sold. Clarifies language.

S 98.194(b) (b) You must determine the annual quantity of each

calcined byproduct/waste generated that is not sold by either direct measurement using the same (b) You must determine the annual quantity of each calcined byproduct or waste generated that is not sold by either direct measurement using the same Clarifies language.

### 29

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change instruments identified in paragraph (a) of this section or by using a calcined byproduct/waste generation

rat e. instruments identified in paragraph (a) of this section or by using a calcined byproduct or waste gener ation

rate.
S 98.194(c) (c) You must determine the chemical composition

(percent total CaO and percent total MgO) of each type of lime product that is produced and each type of calcined byproduct/waste sold according to paragraph (c)(1 ) or (2) of this section. You must determine the chemical composition of each type of lime product that is produced and each type of calcined byproduct/waste sold on a monthly basis. You must determine the chemical composition for each type of calcined byp roduct/waste that is not
sold on an annual basis. (c) You must determine the chemical composition (percent total CaO and percent total MgO) of each type of lime product that is produced and each type of calcined byproduct or waste sold according to paragraph (c)(1) or (2) of this section. You must determine the chemical composition of each type of lime product that is produced and each type of calcined byproduct or waste sold on a monthly basis. You must determine the chemical composition for each ty pe of calcined byproduct or waste that is not
sold on an annual basis. Clarifies language.

S 98.195(a) (a) For each missing value of the quantity of lime

produced (by lime type), and quantity of calcined byproduct/waste produced and sold, the substitute
d ata value shall be the best available estimate based on all available process data or data used for accounting purposes. (a) For each missing value of the quantity of lime produced (by lime type), and quantity of calcined byproduct or waste produced and so ld, the substitute
data value shall be the best available estimate based on all available process data or data used for accounting purposes. Clarifies language.

S 98.196(a)(1) (1) Method used to determine the quantity of lime

that is produced and sold. (1) Method used to determine the quantity of lime that is produced and quantity of lime that is sold. Clarifies language.

S 98.196(a)(2) (2) Method used to determine the quantity of

calcined lime byproduct/waste sold. (2) Method used to determine the quan tity of calcined lime byproduct or waste sold. Clarifies language.

S 98.196(a)(4) (4) Beginning and end of year inventories for

calcined lime byproducts/wastes sold, by type. (4) Beginning and end of year inventories for calcined lime byproducts or wastes sold, by type. Clarifies language.

S 98.196(a)(5) (5) Annual amount of calcined lime byproduct/waste

sold, by type (tons). (5) Annual amount of calcined lime byproduct or waste sold, by type (tons). Clarifies language.

S 98.196(a)(7) (7) Annual amount of calcined lime byproduct/waste

that is not sold, by type (tons). (7) Annual amount of calcined lime byproduct or waste that is not sold, by type (tons). Clarifies language.

S 98.196(b)(1) (1) Annual CO 2 process emissions from all kilns

combined (metric tons). (1) Annual CO 2 process emissions from all lime kilns combined (metric tons). Clarifies language.

S 98.196(b)(2) (2) Monthly emission factors for each lime type

produced. (2) Monthly emission factors (metric ton CO 2 /ton lime product) for each lime product type produced. Clarifies language.

S 98.196(b)(3) (3) Monthly emission factors for each calcined

byproduct/waste by lime type that is sold. (3) Monthly emission factors for each calcined byproduct or waste by lime type that is sold. Clarifies language.

S 98.196(b)(4) (4) Standard method used (ASTM or NLA testing

method) to determine chemical compositions of each (4) Standard method used (ASTM or NLA testing method) to determine ch emical compositions of each Clarifies language.

### 30

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change lime type produced and each calcined lime byproduct/waste type. lime type produced and each calcined lime byproduct
or waste type.
S 98.196(b)(5) (5) Monthly results of chemical composition analysis

of each type of lime product produced and calcined byproduct/waste sold. (5) Monthly results of chemical composition analysis of each type of lime product produced and calcined byproduct or waste sold. Clarifies language.

S 98.196(b)(6) (6) Annual results of chemical composition analysis

of each type of lime byproduct/waste that is not sold. (6) Annual results of chemical composition analysis of each type of lime byproduct or waste that is not
sold. Clarifies language.

S 98.196(b)(9) (9) Method used to determine the quantity of

calcined lime byproduct/waste sold. (9) Method used to determine the quantity of calcined lime byproduct or waste sold. Clarifies language.

S 98.196(b)(10) (10) Monthly amount of calcined lime

byproduct/waste sold, by type (tons). (10) Monthly amount of calcined lime byproduct or waste sold, by type ( tons). Clarifies language.

S 98.196(b)(11) (11) Annual amount of calcined lime

byproduct/waste that is not sold, by type (tons). (11) Annual amount of calcined lime byproduct or waste that is not sold, by type (tons). Clarifies language.

S 98.196(b)(14) (14) Beginning and end of year inventories for

calcined lime byproducts/wastes sold. (14) Beginning and end of year inventories for calcined lime byproducts or wastes sold. Clarifies language.

V 98.222(a) (a) You must report N 2 O process emissions from

each nitric acid production train as required by this subpart. (a) You must report N 2 O process emissions from each nitric acid train as required by this subpart. Clarifies language.

V 98.223(b) (b) You must conduct an annual perfor mance test for

each nitric acid train according to paragraphs (b)(1) through (3) of this section. (b) You must conduct an annual performance test for each nitric acid train according to paragraphs (b)(1) through (b)(3) of this section. Clarifies language.

V 98.223(b)(1) (1) You must conduct the performance test at the

absorber tail gas vent, referred to as the test point, for each nitric acid train according to §98.224(b) through (f). If multiple nitric acid production units
exhaust to a common abatement t echnology and/or emission point, you must sample each process in the ducts before the emissions are combined, sample each process when only one process is operating, or sample the combined emissions when multiple processes are operating and base the site

- s pecific emission factor on the combined production rate of the multiple nitric acid production units. (1) You must conduct the performance test at the absorber tail gas vent, referred to as the test point, for each nitric acid train according to §98.224(b) through (f). If multiple nitric acid trains exhaust to a common abatement technology and/or emission point, you must sample each process in the ducts before the emissions are combined, sample each process when only one process is operating, or sample the combined emissions when multiple processes are operating and base the site

- specific emission factor on the combined production rate of the multiple nitric acid trains. Clarifies terminology of the production units

V 98.223(b)(3) (3) You must measure the production rate during the

performance test and calculate the production rate for the test period in metric tons (100 percent acid basis) (3) You must measure the production rate during the performance test and calculate the production rate for the test period in tons (100 percent acid basis) per Clarifies units of measurement.

### 31

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change per hour. hour.

V 98.223(d) (d) If nitric acid train ―t‖ exhausts to any N 2 O

abatement technology ―N‖ after the test point, you

must determine the destruct ion efficiency for each

N 2 O abatement technology ―N‖ according to paragraphs (d)(1), (d)(2), or (d)(3) of this section. (d) If nitric acid train ―t‖ exhausts to any N 2 O abatement technology ―N‖, you must determine the destruction efficiency for each N 2 O ab atement technology ―N‖ according to paragraphs (d)(1), (d)(2), or (d)(3) of this section. Clarifies requirement.

V 98.223(e) (e) If nitric acid train ―t‖ exhausts to any N 2 O

abatement technology ―N‖ after the test point, you
must determine the annual amount of nitric acid produced on train ―t‖ while N 2 O abatement technology ―N‖ is operating according to §98.224(f). Then you must calculate the abatement utilization
factor for each N 2 O abatement technology ―N‖ for each nitric acid train ―t‖ according to Equation V

– 2
of this section. (e) If nitric acid train ―t‖ exhausts to any N 2 O abatement technology ―N‖, you must determine the annual amount of nitric acid produced on nitric ac id
train ―t‖ while N 2 O abatement technology ―N‖ is operating according to §98.224(f). Then you must
calculate the abatement utilization factor for each

N 2 O abatement technology ―N‖ for each nitric acid train ―t‖ according to Equation V

– 2 of this section. C larifies requirement

V 98.223(e) P a,t,N P t,N Corrects equation term

V 98.223(g)(1) E N 2 O t = Annual N 2 O mass emissions from nitric

acid production unit ―t‖ according to this Equation

V

– 3a (metric tons) E N 2 O t = Annual N 2 O mass emissions from nitric acid train ―t‖ according to this Equation V

– 3a (metric tons). Clarifies terminology of the production units

V 98.223(g)(1) P t = Annual nitric acid production from the train ―t‖

(ton acid produced, 100 percent acid basis). P t = Annual nitric acid production from nitric acid train ―t‖ (ton acid produced, 100 percent acid basis). Clarifies an equation term.

V 98.223(g)(1) DF = Destruction efficiency of N 2 O abatement

technology N that is used on nitric acid train ―t‖ (percent of N 2 O removed from vent stream). DF = Destruction efficiency of N 2 O abatement technology N that is used on nitric acid train ―t‖ (decimal fraction of N 2 O removed from vent stream). Corrects a calculation term.

V 98.223(g)(1) AF = Abatement utilization fact or of N 2 O abatement

technology ―N‖ for nitric acid train ―t‖ (percent of time that the abatement technology is operating). AF = Abatement utilization factor of N 2 O abatement technology ―N‖ for nitric acid train ―t‖ (decimal fraction of annual production du ring which abatement technology is operating). Clarifies an equation term.

V 98.223(g)(2) (2) If multiple N 2 O abatement technologies are

located in series after your test point, you must use the emissions factor (determined in Equation V

– 1 of this section), the destruction efficiency (determined in paragraph (d) of this section), the annual nitric acid production (determined in paragraph (f) of this section), and the abatement utilization factor (determined in paragraph (e) of this section), according to Equation V

– 3b of this section: (2) If multiple N 2 O abatement technologies are located in series after your test point, you must use the emissions factor (determined in Equation V

– 1 of this section), the destruction efficiency (determined in paragraph (d) of this section), the annual nitric acid production (determined in paragraph (i) of this section), and the abate ment utilization factor (determined in paragraph (e) of this section), according to Equation V

– 3b of this section: Corrects a paragraph reference

V 98.223(g)(2) E N 2 O t = Annual N 2 O mass emissions from nitric acid E N 2 O t = Annual N 2 O mass emissions from nitric acid Clarifies terminology of the production units

### 32

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change production unit ―t‖ according to this Equation V

– 3b (metric tons). train ―t‖ according to this Equation V

– 3b (metric tons).

V 98.223(g)(2) EF N 2 O ,t = N 2 O emissions factor for unit ―t‖ (lb

N 2 O /ton nitric acid produced). EF N 2 O ,t = N 2 O emissions factor for nitric acid train ―t‖ (lb N 2 O /ton nitric acid produced). Clarifies terminology of the production units

V 98.223(g)(2) P t = Annual nitric acid produced from unit ―t‖ (ton

acid produced, 100 percent acid basis). P t = Annual nitric acid produced from nitric acid train ―t‖ (ton acid produced, 100 percent acid basis). Clarifies terminology of the production units

V 98.223(g)(2) DF 1 = Destruction efficiency of N 2 O abatement

technology 1 (percent of N 2 O removed from vent stream). DF 1 = Destruction efficiency of N 2 O abatement technology 1 (decimal fraction of N 2 O removed from vent stream). Corrects a calculation term.

V 98.223(g)(2) AF 1 = Abatement utilization factor of N 2 O abatement

technology 1 (percent of time that abatement technology 1 is operating). AF 1 = Abatement utilization factor of N 2 O abatement technology 1 (decimal fraction of time that abatement technology 1 is operating). Corrects a calculation term.

V 98.223(g)(2) DF 2 = Destruction efficiency of N 2 O abatement

technology 2 (percent of N 2 O removed from vent stream). DF 2 = Destruction efficiency of N 2 O abatement technology 2 (decimal fraction of N 2 O removed from vent stream). Corrects a calculation term.

V 98.223(g)(2) AF 2 = Abatement utilization factor of N 2 O abatement

technology 2 (percent of time that abatement technology 2 is operating). AF 2 = Abatement utilization factor of N 2 O abatement technology 2 (decimal fraction of time that abatement technology 2 is operating). Corrects a calculation term.

V 98.223(g)(2) DF N = Destruction efficiency of N 2 O abatement technology N (percent of N 2 O removed from vent stream). DF N = Destructi on efficiency of N 2 O abatement technology N (decimal fraction of N 2 O removed from vent stream). Corrects a calculation term.

V 98.223(g)(2) AF N = Abatement utilization factor of N 2 O

abatement technology N (percent of time that abatement technology N is operating). AF N = Abatement utilization factor of N 2 O abatement technology N (decimal fraction of time that abatement technology N is operating). Corrects a calculation term.

V 98.223(g)(3) (3) If multiple N 2 O abatement technologies are

located in parallel after your test point, you must use the emissions factor (determined in Equation V

– 1 of this section), the destruction efficiency (determined in paragraph (d) of this section), the annual nitric acid production (determined in paragraph (f) of this section), and the abatement utilization factor (determined in paragraph (e) of this section), according to Equation V

– 3c of this section: (3) If multiple N 2 O abatement technologies are located in parallel after your test point, you must use the emissions factor (determined in Equation V

– 1 of this section), the destruction efficiency (determined in paragraph (d) of this section), the annual nitric acid production (determined in paragraph (i) of this section), and the abatement utilization factor (determined in paragraph (e) of this section), according to Equation V

– 3c of this section: Corrects a paragraph reference

V 98.223(g)(3) E N 2 O t = Annual N 2 O mass emissions from nitric acid

production unit ―t‖ according to this Equation V

– 3c (metric tons). E N 2 O t = Annual N 2 O mass emissions from nitric acid train ―t‖ according to this Equation V

– 3c (metric tons). Clarifies terminology of the production units

V 98.223(g)(3) EF N 2 O ,t = N 2 O emissions factor for unit ―t‖ (lb

N 2 O /ton nitric acid produced). EF N 2 O ,t = N 2 O emissions factor for nitric acid train ―t‖ (lb N 2 O /ton nitric acid produced). Clarifies terminology of the production units

### 33

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

V 98.223(g)(3) P t = Annual nitric acid produced from unit ―t‖ (ton

acid produced, 100 percent acid basis). P t = Annual nitric acid produced from nitric acid train ―t‖ (ton acid produced, 100 percent acid basis). Clarifies terminology of the production units

V 98.223(g)(3) DF N = Destruction efficiency of N 2 O abatement technology ―N‖ (percent of N 2 O removed from vent stream). DF N = Destruction efficiency of N 2 O abatement technology ―N‖ (decimal fraction of N 2 O removed from vent stream). Corrects a calculation term.

V 98.223(g)(3) AF N = Abatement utilization factor of N 2 O

abatement technology ―N‖ (percent of time that abatement technology ―N‖ is operating). AF N = Abatement utilization factor of N 2 O abatement technology ―N‖ (decimal fraction of time

that abatement techn ology ―N‖ is operating). Corrects a calculation term.

V 98.223(g)(3) FC N = Fraction control factor of N 2 O abatement

technology ―N‖ (percent of total emissions from unit ―t‖ that are sent to abatement technology ―N‖). FC N = Fraction control factor of N 2 O abatement technology ―N‖ (decimal fraction of total emissions
from nitric acid train ―t‖ that are sent to abatement technology ―N‖). Corrects a calculation term.

V 98.223(g)(4) E N 2 O t = Annual N 2 O mass emissions from nitric acid

production unit ―t‖ accord ing to this Equation V

– 3d (metric tons). E N 2 O t = Annual N 2 O mass emissions from nitric acid train ―t‖ according to this Equation V

– 3d (metric tons). Corrects a calculation term.

V 98.223(i) (i) You must determine the total annual amount of

nitric acid produced on nitric acid train ―t‖ for each nitric acid train (tons acid produced, 100 percent acid basis), according to §98.224(f). (i) You must determine the total annual amount of nitric acid produced on each nitric acid train ―t‖ (tons acid produced, 10 0 percent acid basis), according to §98.224(f). Clarifies terminology of the production units

V 98.224(c) (c) You must determine the production rate(s) (100

percent basis) from each nitric acid train during the performance test according to paragraphs (c) (1) or (c)(2) of this section. (c) You must determine the production rate(s) (100 percent acid basis) from each nitric acid train during the performance test according to paragraphs (c)(1) or (c)(2) of this section. Clarifies units for a calculation term.

V 98.224(e) (e) You must determine the total monthly amount of

nitric acid produced. You must also determine the monthly amount of nitric acid produced while N 2 O abatement technology (located after the test point) is operating from each nitric acid train. These monthly amounts are determined according to the methods in paragraphs (c)(1) or (2) of this section. (e) You must determine the total monthly amount of nitric acid produced. You must also determine the monthly amount of nitric acid produced while N 2 O abatement technology is operating from each nitric acid train. These monthly amounts are determined according to the methods in paragraphs (c)(1) or (2)
of this section. Clarifies requirements.

V 98.224(f) (f) You must determine the annual amount of nit ric

acid produced. You must also determine the annual amount of nitric acid produced while N 2 O abatement technology (located after the test point) is operating
for each train. These annual amounts are determined by summing the respective monthly nitric acid quantities determined in paragraph (e) of this section. (f) You must determine the annual am ount of nitric acid produced. You must also determine the annual amount of nitric acid produced while N 2 O abatement technology is operating for each nitric acid train. These annual amounts are determined by summing the respective monthly nitric acid quanti ties determined in paragraph (e) of this section. Clarifies requirements.

V 98.226(a) (a) Train identification number. (a) Nitric Acid train identification number. Clarifies requirements.

### 34

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

V 98.226(n) (n) If you requested Administrator approval for an

alternative method of determining N 2 O emissions under §98.223(a)(2), each annual report must also contain the information specified in paragraphs (n)(1) through (4) of this section. (n)(1) through (n)(4) o f this section for each nitric acid production facility. (n) If you requested Administrator approval for an alternative method of determining N 2 O emissions under §98.223(a)(2), each annual report must also contain the information specified in paragraphs (n)(1) through (n)(4) of this section for each nitric acid production facility. Corrects typographical error

V 98.226(o) (None) (o) [Reserved] Cor rects typographical error

V 98.226(p) (p) Fraction control factor for each abatement

technology (percent of total emissions from the production unit that are sent to the abatement technology) if equation V

– 3c is used. (p) Fraction control factor for each abatement technology (percent of total emissions from the nitric acid train that are sent to each abatement technology) if Equation V

– 3c is used. Clarifies terminology of the production units

X 98.242(b)(2) (2) If you comply with §98.243(c), report CO 2 , C H 4 ,

and N 2 O combustion emissions under subpart C of this part (General Stationary Fuel Combustion Sources) by following the requirements of subpart C only for the combustion of supplemental fuel. Determine the applicable Tier in subpart C of this part (Ge neral Stationary Fuel Combustion Sources) based on the maximum rated heat input capacity of the stationary combustion source. (2) If you comply with §98.243(c), report CO 2 , CH 4 , and N 2 O combustion emissions under subpart C of this part (General Stationary Fuel Combustion Sources) by following the requirements of subpart
C for all fuels, except emissions from burning petrochemical process off

- gas in any combustion unit are not to be reported under subpart C of this
part. Determine the applicable Tier in sub part C of this part (General Stationary Fuel Combustion Sources) based on the maximum rated heat input capacity of the stationary combustion source. See preamble text for explanation

X 98.243(b) (b) Continuous emission monitoring system (CEMS). Route all process vent emissions and emissions from combustion of process off

- gas to one
or more stacks and determine CO 2 emissions from each stack (except flare stacks) according to the Tier
4 Calculation Methodology requirements in subpart C of this part. For each stack (except flare stacks)
that includes emissions from combustion of petrochemical process off

- gas, calculate CH 4 and N20 emissions in accordance with subpart C of this part (use the Tier 3 met hodology, emission factors
for ―Petroleum‖ in Table C

– 2 of subpart C of this part, and either the default high heat value for fuel gas in Table C

– 1 of subpart C of this part or a calculated HHV, as allowed in Equation C

– 8 of subpart C of this part). For ea ch flare, calculate CO 2 , (b) Continuous emission monitoring system (CEMS). Route all process vent emissions and
emissions from stationary combustion units that burn
any amount of process off

- gas to one or more stacks and determine GHG emissions as specified in paragraphs (b)(1) through (3) of this section. (1)Determine CO 2 emissions from each stack (except flare stacks) according to the Tier 4 Calculat ion Methodology requirements in subpart C of this part. (2)For each stack (except flare stacks) that includes emissions from combustion of petrochemical process
off

- gas, calculate CH 4 and N 2 O emissions in accordance with subpart C of this part (use Equati on C

- 10 and the "fuel gas" emission factors in Table C

– 2 of subpart C of this part )

. (3)For each flare, calculate CO 2 , CH 4 , and N 2 O See preamble text for explanation

### 35

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

CH 4 , and N 2 O emissions using the methodology specified in §98.253(b)(1) through (b)(3). emissions using the methodology specified in §98.253(b)(1) through (b)(3).

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

least once per month and determine the carbon content of each sample according to the procedures of §98.244(b)(4). If multiple valid carbon content measurements are made during the monthly

measurement period, average them arithmetically. However, if a particular liquid or solid feedstock is delivered in lots, and if multiple deliveries of the same feedstock are received from the same supply source in a given calendar month, only one representative sampl e is required. Alternatively, you may use the results of analyses conducted by a fuel or feedstock supplier, provided the sampling and analysis is conducted at least once per month using any of the procedures specified in §98.244(b)(4). (3) Collect a sampl e of each feedstock and product at least once per month and determine the carbon content of each sample according to the procedures of §98.244(b)(4). If multiple valid carbon content measurements are made during the monthly measurement period, average them arithmetically. However, if a particular liquid or solid feedstock is delivered in lots, and if multiple deliveries of the same feedstock are received from the same supply source in a given calendar month, only one representative sample is required. Alter natively, you may use the results of analyses conducted by a feedstock supplier, or product customer, provided the sampling and analysis is conducted at least once per month using any of the procedures specified in §98.244(b)(4). See preamble text for explanation

X 98.243(c)(4) (4) If you determine that the monthly average

concentration of a specific compound in a feedstock or product is greater than 99.5 percent by volume (or mass for liquids and solids), then as an alternative to the sampling and ana lysis specified in paragraph (c)(3) of this section, you may calculate the carbon content assuming 100 percent of that feedstock or product is the specific compound during periods of normal operation. This alternative may not be used for products during pe riods of operation when off

specification product is produced. You must maintain records of any determination made in accordance with this paragraph (c)(4) along with all supporting data, calculations, and other information.
You must reevaluate determinati ons made under this paragraph (c)(4) after any process change that affects the feedstock or product composition. You must keep records of the process change and the corresponding composition determinations. If the feedstock or product composition changes s o that the average monthly concentration falls below 99.5 (4) If you determine that the monthly average concentration of a specific compound in a feedstock or product is greater than 99.5 percent by volume or mass, then as an alternative to the sampling and analysis specified in paragraph (c)(3) of this section, you may determine carbon content in accordance with paragraphs (c)(4)(i) through (iii) of this section. (i) Calculate the carbon content assuming 100 percent of that feedstock or product is the specific compound. (ii) You must maintain records of any determination made in accordance with this paragraph (c)(4) along with all supporting data, calculations, and other
information. (i ii) Reevaluate determinations made under this paragraph (c)(4) after any process change that affects the feedstock or product composition. Keep records of the process change and the corresponding composition determinations. If the feedstock or product comp osition changes so that the average monthly concentration falls below 99.5 percent, you See preamble text for explanation

### 36

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change percent, you are no longer permitted to use this
alternative method. are no longer permitted to use this alternative
method.

X 98.243(c)(5)(i ) C g = Annual net contribution to calculated emissions

from c arbon (C ) in gaseous materials (kilograms/year, kg/yr) (F gf ) i,n = Volume of gaseous feedstock i introduced in month "n" (standard cubic feet, scf ). (MW f ) i = Molecular weight of gaseous feedstock i (kg/kg

- mole). (P gp ) i,n = volume of gaseous product i pro duced in month "n" (scf). (MW p ) i,n = Molecular wieght of gaseous product i (kg/kg

- mole). C g = Annual net contribution to calculated emissions from carbon (C ) in gaseous materials, including streams containing CO 2 recovered for sale or use in another process( kg/yr) (F gf ) = Volume or mass of gaseous feedstock i introduced in month "n" (scf or kg). If you measure mass, the term (MW f

) i /MVC is replaced with "1". (MW f ) i,n = Molecular weight of gaseous feedstock i in month "n" (kg/kg

- mole). (P gp ) i,n = Volume or mass of gaseous product i produced in month "n" (scf or kg). If you measure mass, the term (MW p ) i /MVC is replaced with "1". (MW p ) i,n = Molecular wieght of gaseous product i in month "n" (kg/kg

- mole). See preamble text for explanation

X 98.243(d)(3)( i) (i) For all gaseous fuels that contain ethylene process

off

- gas, use the emission factors for "Petroleum" in
Table C

– 2 of subpart C of this part (General
Stationar y Fuel Combustion Sources). (i) For all gaseous fuels that contain ethylene process
off

- gas, use the emission factors for "Fuel Gas" in
Table C

– 2 of subpart C of this part (General Stationary Fuel Combustion Sources). See preamble text for explanation

X 98.244(b)(4) (4) ...Analyses conducted in accordance with

methods specified in paragraphs (b)(4)(i) through (b)(4)(xv) of this section may be performed by the owner or operator, by an independent laboratory, or by the supplier of a feedstock. (4) ...Anal yses conducted in accordance with methods specified in paragraphs (b)(4)(i) through (b)(4)(xv) of this section may be performed by the owner or operator, by an independent laboratory, by the supplier of a feedstock, or by a product customer. Harmonizing ch ange with 40 CFR 98.243(c)(3).

X 98.244(b)(4)( xiii) (xiii) The results of chromatographic analysis of a

feedstock or product, provided that the gas chromatograph is operated, maintained, and calibrated according to the manufacturer's
instructions. (xiii) The results of chromatographic analysis of a feedstock or product, provided that the chromatograph is operated, maintained, and calibrated according to the manufacturer's
instructions. See preamble text for explanation

X 98.244(b)(4)( xiv) (xiv) The carbon content results of mass

spectrometer analysis of a feedstock or product, provided that the mass spectrometer is operated, maintained, and calibrated according to the
manufacturer's instructions. (xiv) The results of mass spectrometer analysis of a
feedsto ck or product, provided that the mass spectrometer is operated, maintained, and calibrated according to the manufacturer's instructions. See preamble text for explanation

X 98.244(b)(4)( xv)(A) (A) An industry standard practice for carbon black

feedstock o ils and carbon black products. (A) An industry standard practice, or a method published by a consensus

- based standards organization if such a method exists, for carbon black feedstock oils and carbon black products. See preamble text for explanation

### 37

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

Consensus

- based standards organizations include, but are not limited to, the following: ASTM International (100 Barr Harbor Drive, P.O. Box CB700, West Conshohocken, Pennsylvania 19428

- B2959, (800) 262

- 1373, http://www.astm.org), the American National Standards Institute (ANSI, 1819 L Street, NW ., 6th floor, Washington, DC 20036, (202) 293

- 8020, http://www.ansi.org ), the American Gas Association (AGA, 400 North Capitol Street, NW., 4th Floor, Washington, DC 20001, (202) 824

- 7000, http://www.aga.org ), the American Society of Mechanical Engineers (ASME, Three Park Avenue, New York, NY 10016

- 5990, (800) 843

- 2763, http://www.asme.org ), the American Petroleum Institute (API, 1220 L Street, NW., Washington, DC
20005

- 4070, (202) 682

- 8000, http://www.api.org ), and the North American Energy Standards B oard (NAESB, 801 Travis Street, Suite 1675, Houston, TX 77002, (713) 356

- 0060, http://www.naesb.org). The method(s) used shall be documented in the Monitoring Plan required under § 98.3(g)(5).

X 98.244(c) (None) (c) If you comply with §98.243(b) or (d), conduct monitoring and QA/QC for flares in accordance with §98.254. See preamble text for explanation

X 98.245 Introductory paragraph For missing feedstock flow rates, product flow rates,

and carbon contents, use the sa me procedures as for missing flow rates and carbon contents for fuels as specified in §98.35. For missing feedstock and product flow rates, use the same procedures as for missing fuel usage as specified in §98.35(b)(2). For missing feedstock and product carbon contents and missing molecular weights for gaseous feedstocks and products, use the

sam e procedures as for missing carbon contents and missing molecular weights for fuels as specified in §98.35(b)(1). For missing flare data, follow the procedures in §98.255(b) and (c). See preamble text for explanation

X 98.246(a)(6) (6) Name of each metho d listed in §98.244 used to

determine a measured parameter (or description of manufacturer's recommended method). (6) For each feedstock and product, provide the information specified in paragraphs (a)(6)(i) through (a)(6)(iii) of this section. (i) Name of each method used to determine carbon content or molecular weight in accordance with 98.244(b)(4); See preamble text for explanation

### 38

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change (ii) Description of each type of device (e.g., flow meter, weighing device) used to determine flow or mass in accordance 98.244(b)(1) through (3). (iii) Identification of each method (i.e., method number, title, or other description) used to determine flow or mass in accordance with 98.244(b)(1) through (3).

X 98.246(a)(8) (8) Identification of each combustion unit that

burned both process off

- gas and supplemental fuel. (8) Identification of each combustion unit that burned both process off

- gas and supplemental fuel, including combustion units that are not part of the petrochemical process unit. See preamble text for explanation

X 98.246(a)(9) (9) If you comply with the alternative to sampling

and analysis specified in §98.243(c)(4), the amount of time during which off

- specification product was produced, the volume or mass of off

- specification product produced, and if applicable, the date of any process change that reduced the composition to less than 99.5 percent. (9) If you comply with the alternative to sampling and analysis specified in §98.243(c)(4), the number of days during which off

- specification product was

pr oduced, and if applicable, the date of any process change that reduced the composition to less than 99.5
percent. See preamble text for explanation

X 98.246(a)(11) (11) If you determine carbon content or composition

of a feedstock or product using a method under §98.244(b)(4)(xv)(B), report the information listed in paragraphs (a)(11)(i) through (a)(11)(iv) of this
section. (11) If you determine carbon content or composition of a feedstock or product using a method under §98.244(b)(4)(xv)(B), report t he information listed in paragraphs (a)(11)(i) through (a)(11)(iii) of this
section. Corrects cross

- reference.

X 98.246(b)(2) (2) For CEMS used on stacks for stationary

combustion units, report the relevant information required under §98.36 for the Tier 4 calculation methodology. Section 98.36(b)(9)(iii) does not apply for the purposes of this subpart. (2) For CEMS used on stacks that include emissions
from stationary combustion units that burn any
amount of off

- gas from the petrochemical process,
report t he relevant information required under §98.36(c)(2) and (e)(2)(vi) for the Tier 4 calculation methodology. Sections §98.36(c)(2)( ii) and (c)(2)(ix) do not apply for the purposes of this subpart. Clarifies CEMS reporting requirement to align more closely w ith procedures in e

- GGRT and corrects

cross

- reference.

X 98.246(b)(3) (3) For CEMS used on stacks that are not used for stationary combustion units, report the information required under §98.36(e)(2)(vi). (3) For CEMS used on stacks that do not include emissions from stationary combustion units, report the information required under §98.36 (b)(6), (b)(7),
and §98.36(e)(2)(vi). Clarifies CEMS reporting requirement to align more closely with procedures in e

- GG RT.

### 39

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

X 98.246(b)(4) (4) The CO 2 emissions from each stack and the

combined CO 2 emissions from all stacks (except flare stacks) that handle process vent emissions and emissions from stationary combustion units that burn process off

- gas for the petrochemical process unit. For each stationary combustion unit (or group of
combustion uni ts monitored with a single CO 2 CEMS) that burns petrochemical process off

- gas, provide an estimate based on engineering judgment
of the fraction of the total emissions that is
attributable to combustion of off

- gas from the petrochemical process unit. (4) F or each CEMS monitoring location that meets the conditions in paragraph (b)(2) or (3) of this section, provide an estimate based on engineering judgment of the fraction of the total CO 2 emissions that is attributable to the petrochemical process unit. See preamble text for explanation

X 98.246(b)(5) (5) For stationary combustion units that burn process

off

- gas from the petrochemical process unit, report
the information related to CH 4 and N 2 O emissions as specified in paragraphs (b)(5)(i) through (b)(5)(iv) of
this section. (i) The CH 4 and N 2 O emissions from each stack that
is monitored with a CO 2 CEMS, expressed in metric tons of each gas and in metric tons of CO 2 e. For each stack provide an estimate based on engineering judgment of the fraction of the total emissions that is
attributable to combustion of off

- gas from the petrochemical process unit. (ii) The combined CH 4 and N 2 O emissions from all stationary combustion units, expressed in met ric tons of each gas and in metric tons of CO 2 e. (iii) The quantity of each type of fuel used in Equation C

– 8 in §98.33(c) for each stationary combustion unit or group of units (as applicable) during the reporting year, expressed in short tons for
solid f uels, gallons for liquid fuels, and scf for gaseous fuels. (iv) The HHV (either default or annual average from (5) For each C EMS monitoring location that meets the conditions in paragraph (b)(2) of this section, report the CH 4 and N 2 O emissions expressed in metric tons of each gas. For each CEMS monitoring
location

, provide an estimate based on engineering judgment of the fracti on of the total CH 4 and N 2 O
emissions that is attributable to combustion of off

gas from the petrochemical process unit. (i)[Reserved] (ii)[Reserved] (iii)[Reserved] (iv)[Reserved] See preamble text for explanation

### 40

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change measured data) used in Equation C

– 8 in §98.33(c) for each stationary combustion unit or group of combustion units (as applicable).

X 98.246(b)(6) (6) ID or other appropria te descriptor of each stationary combustion unit that burns process off

gas. (6) [Reserved] See preamble text for explanation

X 98.246(c)(4) (4) Name and annual quantity of each feedstock (4) Name and annual quantity of each feedstock (metric tons). Clarifies units of measure for reporting requirement

X 98.247(b) (b) If you comply with the mass balance

methodology in §98.243(c), then you must retain records of the information listed in paragraphs (b)(1) through (b)(3) of this section. (1) Results of feedstock or product composition
determinations conducted in accordance with §98.243(c)(4). (2) Start and end times and calculated carbon contents for time periods when off

- specification product is produced, if you comply with the alternative methodology i n §98.243(c)(4) for determining carbon content of feedstock or product. (b) If you comply with the mass balance methodology in §98.243(c), then you must retain records of the information listed in paragraphs (b)(1) through (b)(4) of this section. (1) Results of feedstock or product composition
determinations conducted in accordance with §98.243(c)(4). (2) Start and end times for time periods when off

specification product is produced, if you comply with the alternative methodology in §98.243(c)(4)
for determining carbon content of product. Corrects a reference and reduces recordkeeping requirements when the alternative methodology in 98.234 (c )(4) is used.

X 98.248 Product , as used in §98.243, means each of the

following carbon

- containing outputs from a process: the petrochemical, recovered byproducts, and liquid organic wastes that are not incinerated onsite. Product does not include process vent emissions, fugitive emissions, or wastewater. Product, as used in §98.243, means each of the following carbon

- containing outputs from a process: the petrochemical, recovered byproducts, and liquid organic wastes that are not combusted onsite. Product does not include process vent emissions, fugitive emissions, or wastewater. The definition of product has b een revised to provide consistency with other subparts of this rule.

Y 98.252(a) (a) .... For CH 4 and N 2 O emissions from combustion

of fuel gas, use the applicable procedures in 98.33 (c ) for the same tier methodology that was used for calculating CO 2 emissions. (Use the default CH 4 and

N 2 O emission factors for "Petroleum (All fuel types
in Table C

- 1)" in Table C

- 2 of this part. For Tier 3... (a) .... For CH 4 and N 2 O emissions from combustion of fuel gas, use the applicable procedures in 98.33(c )
for t he same tier methodology that was used for calculating CO 2 emissions. (Use the default CH 4 and

N 2 O emission factors for "Fuel Gas" in Table C

- 2 of this part. For Tier 3.... See preamble text for explanation

Y 98.252(i) (i) CO 2 emissions from non

- merchant hydrogen

production process units (not including hydrogen produced from catalytic reforming units) under this subpart. You must follow the calculation methodologies, monitoring and QA/QC methods, missing data procedures, reporting requirements, and
record keeping requirements of subpart P of this part. (i) CO 2 emissions from non

- merchant hydrogen production process units (not including hydrogen produced from catalytic reforming units) following the calculation methodologies, monitoring and QA/QC methods, mi ssing data procedures, reporting requirements, and recordkeeping requirements of subpart P of this part. Clarifies requirement

### 41

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

Y 98.253(b)(2) EmF CH 4 = Default CH 4 emission factor for
"PetroleumProducts" from Table C

- 2 of Subpart C of this part (General Staionary Fuel Combusion Sources) (kg CH 4 / MMBtu) EmF CH 4 = Default CH 4 emission factor for "Fuel
Gas" from Table C

- 2 of Subpart C of this part (General Staionary Fuel Combusion Sources) (kg
CH 4 / MMBtu) See preamble text for explanation

Y 98.253(b)(3) EmF N 2 O = Default N 2 O emission factor for
"PetroleumProducts" from Table C

- 2 of subpart C of this part (General Stationary Fuel Combustion Sources) (kg N 2 O /MMBtu). EmF N 2 O = Default N 2 O emission factor for "Fuel
Gas" from Table C

- 2 of subpart C of this part (General Stationary Fuel Combustion Sources) (kg

N 2 O /MMBtu). See preamble text for explanation

Y 98.253(f)(2) (2) Flow measurement. If you have a continuous

flow monitor on the sour gas feed to the sulfur recovery plant, you must use the measured flow rates when the monitor is operational to calculate the sour gas flow rate. If you do not have a continuous flow monitor on the sour gas feed to the sulfur recovery plant, you must use engineering calculations, company records, or similar estimates of volumetric sour gas flow. (2) Flow measurement. If you have a continuous
flow moni tor on the sour gas feed to the sulfur recovery plant or the sour gas feed sent for off

- site sulfur recovery, you must use the measured flow rates when the monitor is operational to calculate the sour gas flow rate. If you do not have a continuous
flow mon itor on the sour gas feed to the sulfur recovery plant or the sour gas feed sent for off

- site sulfur recovery, you must use engineering calculations, company records, or similar estimates of volumetric sour gas flow. Clarifies requirement

Y 98.253(f)(3) ( 3) Carbon content. If you have a continuous gas

composition monitor capable of measuring carbon content on the sour gas feed to the sulfur recovery plant or if you monitor gas composition for carbon content on a routine basis, you must use the
measured car

bon content value. Alternatively, you may develop a site

- specific carbon content factor using limited measurement data or engineering
estimates or use the default factor of 0.20. (3) Carbon content. If you have a continuous gas composition monitor capable of measuring carbon content on the sour gas feed to the sulfur recovery plant or the sour gas feed sent for off

- site for sulfur recovery, or if you monitor gas composition for carbon content on a routine basis, you must use the
measured carbon content valu e. Alternatively, you may develop a site

- specific carbon content factor using limited measurement data or engineering
estimates or use the default factor of 0.20. Clarifies requirement

Y 98.253(f)(4) (4) Calculate the CO 2 emissions from each sulfur

recovery plant using Equation Y

– 12 of this section.
Where:

F SG = Volumetric flow rate of sour gas feed (including sour water stripper gas) to the sulfur recovery plant (scf/year).

MF C = Mole fraction of carbon in the sour gas to the sulfur recovery plant (kg

- mole C/kg

- mole gas);
default = 0.20. (4) Calculate the CO 2 emissions from each on

- site sulfur recovery plant and for sour gas sent off

- site for sulfur recovery using Equation Y

– 12 of this section.
Where:

F SG = Volumetric flow rate of sour gas (including sour water stripper gas)fed to the sulfur recovery plant or the sour gas feed sent for off

- site for sulfur recovery (scf/year).

MF C = Mole fraction of carbon in the sour gas fed to the sulfur recovery plant or the sour gas feed sent for See preamble text for explanation

### 42

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

off

- site for sulfur recovery (kg

- mole C/kg

- mole gas);
default = 0.20.

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

(a) through (i) of this section that can reasonably be expected to contain gr eater than 2 percent by volume
CO 2 or greater than 0.5 percent by volume of CH 4 or greater than 0.01 percent by volume (100 parts per million) of N 2 O , calculate GHG emissions using the Equation Y

– 19 of this section. You must use Equation Y

– 19 of this secti on to calculate CH 4 emissions for catalytic reforming unit depressurization and purge vents when methane is used as the purge gas or if you elected this method as an alternative to the methods in paragraphs (f), (h), or (k) of this section. (j) For each pr ocess vent not covered in paragraphs (a) through (i) of this section that can reasonably be expected to contain greater than 2 percent by volume
CO 2 or greater than 0.5 percent by volume of CH 4 or greater than 0.01 percent by volume (100 parts per million) of N 2 O , calculate GHG emissions using the Equation Y

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

– 19 of this section to calculate CH 4 emissions for catalytic reforming unit depressurizatio n and purge vents when methane is used as the purge gas, CH 4 emissions if you elected to use the method in (i)(1) of this section, and CO 2 and/or CH 4 emissions, as applicable, if you elected
this method as an alternative to the methods in paragraphs (f), ( h), or (k) of this section. See preamble text for explanation

Y 98.253(k) (k) For uncontrolled blowdown systems, you must

calculate CH 4 emissions either using the methods for process vents in paragraph (j) of this section regardless of the CH 4 concentration or using Equation
Y20 of this section. Blowdown systems where the uncondensed gas stream is routed to a flare or similar
control device is considered to be controlled and is not required to estimate emissions under this paragraph (k). (k) Fo r uncontrolled blowdown systems, you must
calculate CH 4 emissions either using the methods for process vents in paragraph (j) of this section regardless of the CH 4 concentration or using Equation

Y

- 20 of this section. Blowdown systems where the
uncondensed gas stream is routed to a flare or similar
control device is considered to be controlled and is not required to estimate emissions under this paragraph (k). Corrects typographical error in reference to equation

Y

- 20

Y 98.253(m) (m) For storage tanks, exc ept as provided in

paragraph (m)(4) of this section, calculate CH 4 emissions using the applicable methods in paragraphs (m)(1) through (m)(3) of this section. (m) For storage tanks, except as provided in paragraph (m)(3) of this section, calculate CH 4 emissions using the applicable methods in paragraphs (m)(1) and (m)(2) of this section. Corrects cross

- reference

Y 98.256(f)(6) (6) If you use a CEMS, the relevant information

required under §98.36 for the Tier 4 Calculation Methodology, the CO 2 annual e missions as measured by the CEMS (unadjusted to remove CO 2 combustion emissions associated with additional units, if present) and the process CO 2 emissions as calculated according to §98.253(c)(1)(ii). Report the
CO 2 annual emissions associated with source s other
than those from the coke burn

- off in the applicable (6) If you use a CEMS, the relevant information required under §98.36 for the Tier 4 Calculation Methodology, the CO 2 annual emi ssions as measured by the CEMS (unadjusted to remove CO 2 combustion emissions associated with additional units, if present) and the process CO 2 emissions as calculated according to §98.253(c)(1)(ii). Report the
CO 2 annual emissions associated with sources other
than those from the coke burn

- off in accordance with Clarifies reporting requirements

### 43

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change subpart (e.g., subpart C of this part in the case of a CO boiler). the applicable subpart (e.g., subpart C of this part in the case of a CO boiler).

Y 98.256(h) (h) For sulfur recovery plants and for emissions from

sour gas sent off

- site for sulfur recovery, the owner and operator shall report: (h) For on

- site sulfur recovery plants and for emissions from sour gas sent off

- site for sulfur recovery, the owner and operator shall report: See preamble text for explanation

Y 98.256(h) (2) (2) Maximum rated throughput of each independent

sulfur recovery plant, in metric tons sulfur produced/stream day, a description of the type of sulfur recovery plant, and an indication of the
method used to calculate CO 2 annual emissions for
the sulfur recovery plant (e.g., CO 2 CEMS, Equation

Y

– 12, or process vent method in §98.253(j)). (2) For each on

- site sulfur recovery plant, the maximum rated throughput (metric tons sulfur produced/stream day), a description of the type of sulfur recovery plant, an d an indication of the
method used to calculate CO 2 annual emissions for the sulfur recovery plant (e.g., CO 2 CEMS, Equation

Y

– 12, or process vent method in §98.253(j)). See preamble text for explanation

Y 98.256(h)(3) (3) The calculated CO 2 annual emissions for each

sulfur recovery plant, expressed in metric tons. The
calculated annual CO 2 emissions from sour gas sent
off

- site for sulfur recovery, expressed in metric tons. (3) The calculated CO 2 annual emissions for each

on

- site sulfur recov ery plant, expressed in metric
tons. The calculated annual CO 2 emissions from sour gas sent off

- site for sulfur recovery, expressed in
metric tons. See preamble text for explanation

Y 98.256(h)(4) (4) If you use Equation Y

– 12 of this subpart, the

annual v olumetric flow to the sulfur recovery plant (in scf/year), the molar volume conversion factor (in scf/kg

- mole), and the annual average mole fraction of carbon in the sour gas (in kg

- mole C/kg

- mole gas). (4) If you use Equation Y

– 12 of this subpart, the

ann ual volumetric flow to the on

- site and off

- site sulfur recovery plant (in scf/year), the molar volume conversion factor (in scf/kg

- mole), and the annual average mole fraction of carbon in the sour gas (in kg

- mole C/kg

- mole gas). See preamble text for expla nation

Y 98.256(h)(5) (5) If you recycle tail gas to the front of the sulfur

recovery plant, indicate whether the recycled flow
rate and carbon content are included in the measured data under §98.253(f)(2) and (3). Indicate whether a
correction for CO 2 emissions in the tail gas was used in Equation Y

– 12. If so, then report the value of the correction, the annual volume of recycled tail gas (in scf/year) and the annual average mole fraction of carbon in the tail gas (in kg

- mole C/kg

- mole gas).
Indicate w hether you used the default (95%) or a unit specific correction, and if used, report the approach
used. (5) If you recycle tail gas to the front of an on

- site sulfur recovery plant, indicate whether the recycled
flow rate and carbon content are included in the measured data under §98.253(f)(2) and (3). Indicate
whether a correction for CO 2 emissions in the tail gas was used in Equation Y

– 12. If so, then report the value of the correction, the annual volume of recycled tail gas (in scf/year) and the annual a verage mole fraction of carbon in the tail gas (in kg

- mole C/kg

- mole gas). Indicate whether you used the default (95%) or a unit specific correction, and if a unit specific correction is used, report the approach
used. See preamble text for explanation

Y 98.256(h)(6) (6) If you use a CEMS, the relevant information

required under §98.36 for the Tier 4 Calculation Methodology, the CO 2 annual emissions as measured (6) If you use a CEMS, the relevant information required under §98.36 for the Tier 4 Calculation Methodology, the CO 2 annual emiss ions as measured Clarifies reporting requirements

### 44

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change by the CEMS and the annual process CO 2 emissions calculated according to §98.253(f)(1). Report t he
CO 2 annual emissions associated with fuel
combustion subpart C of this part (General Stationary Fuel Combustion Sources). by the CEMS and the annual process CO 2 emissions calculated according to §98.253(f)(1). Report the
CO 2 annual emissions associated with fuel
combustion in accordance with subpart C of this part (General Stationary Fuel Combustion Sources)

. Y 98.256(j) (10) (None) (10)If you use Equation Y

- 19 of this subpart, the relevant information required under paragraph (l)(5)
of this section. See preamble text for explanation

Y 98.256(k)(4) (4) For each set of coking drums that are the same

dimensions: The number of coking drums in the set, the height and diameter of the coke drums (in feet), the cumulative number of vessel openings for all delayed coking drums in the set, the typical venting pressure (in psig), void fraction (in cf gas/cf of vessel), and the mole fraction of methane in coking gas (in kg

- mole CF 4 /kg

- mole gas, wet basis). (4) For each set of coking drums that are the same dimensions: The number of coking drums in the set, the height and diameter o f the coke drums (in feet), the cumulative number of vessel openings for all delayed coking drums in the set, the typical venting pressure (in psig), void fraction (in cf gas/cf of vessel), and the mole fraction of methane in coking gas (in kg

- mole CH 4 /kg

- mole gas, wet basis). Corrects typographical error (CF4 to CH 4 )

Y 98.256(k)(6) (None) (6) If you use Equation Y

- 19 of this subpart, the relevant information required under paragraph (l)(5)
of this section for each set of coke drums or vessels
of the same size. See preamble text for explanation

Y 98.256(o)(4)( vi) (vi) If you did not use Equation Y

– 23, the tank

specific methane composition data and the gas generation rate data used to estimate the cumulative
CH 4 emissions for storage tanks used to process

u nstabilized crude oil. (vi) If you did not use Equation Y

– 23, the tank

specific methane composition data and the annual gas generation volume (scf/yr) used to estimate the
cumulative CH 4 emissions for storage tanks used to process unstabilized crude oil. Clarifies reporting requirements

Y 98.256(o)(5), (6), (7) (5) The method used to calculate the reported storage

tank emissions for storage tanks processing
unstabilized crude oil. (6) The quantity of unstabilized crude oil received during the calendar yea r (in MMbbl), the average pressure differential (in psi), and the mole fraction of
CH 4 in vent gas from the unstabilized crude oil storage tank, and the basis for the mole fraction. (7) The tank

- specific methane composition data and the gas generation rate data, if you did not use Equation Y

– 23. (5) [Reserved] [6) [Reserved] (7) [Reserved] Removes duplicate reporting requirements.

Z 98.263(b)(1)( ii) (ii) If your process measurement provides the CO 2

emissions directly as an output...

CO 2 n,i = Carbon dioxide emissions of a grab sample (ii) If your process measurement provides the CO 2 content directly as an output...

CO 2 n,i = Carbon dioxide content of a grab sample See preamble text for explanation

### 45

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change batch of phosphate rock by origin i obtained during month n (percent by weight, expressed as a decimal fraction). batch of phosphate rock by origin i obtained during month n (percent by weight, expressed as a decimal fraction).

Z 98.264(a) (a) You must obtain a monthly grab sample of

phosphate rock di rectly from the rock being fed to the process line before it enters the mill using one of the following methods. You may conduct the representative bulk sampling using a method published by a consensus standards organization, or you may use industry consen sus standard practice methods, including but not limited to the Phosphate Mining States Methods Used and Adopted by the Association of Fertilizer and Phosphate Chemists (AFPC) (P.O. Box 1645, Bartow, Florida 33831, (863) 534

– 9755, http://afpc.net, paul.mca fee@mosaicco.com) . If phosphate rock is obtained from more than one origin in a month, you must obtain a sample from each origin of rock or obtain a composite representative sample. (a) You must obtain a monthly grab sample of phosphate rock directly from the rock being fed to the process line before it enters the mill using one of the following methods. You may conduct the representative bulk sampling using a method published by a consensus standards organization, or you may use industry consensus standard practice methods, including but not limited to the Phosphate Mining States Methods Used and Adopted by the Association of Fertilizer and Phosphate Chemists (AFPC). If phosphate rock is obtained from more than one origin in a month, you must obtain a sampl e from each origin of rock or obtain a composite representative sample. Delete s outdated contact information

Z 98.264(b) (b) You must determine the carbon dioxide or

inorganic carbon content of each monthly grab sample of phosphate rock (consumed in the production of phosphoric acid). You may use a method published by a consensus standards organization, or you may use indust ry consensus standard practice methods, including but not limited to the Phosphate Mining States Methods Used and Adopted by AFPC (P.O. Box 1645, Bartow, Florida 33831, (863) 534

– 9755, http://afpc.net, paul.mcafee@mosaicco.com)

. (b) You must determine the carbon dioxide or inorganic carbon content of each monthly grab sample of phosphate rock (consumed in the production of phosphoric acid). You may use a method published by a consensus standards organization, or you may use industry consensus standard pract ice methods, including but not limited to the Phosphate Mining States Methods Used and Adopted by AFPC. Delete s outdated contact information

Z 98.265(a) (a) For each missing value of the inorganic carbon

content of phosphate rock or carbon dioxide (by
ori gin), you must use the appropriate default factor provided in Table Z

– 1 this subpart. Alternatively, you must determine a substitute data value by calculating the arithmetic average of the quality

assured values of inorganic carbon contents of phosphate ro ck of origin i from samples immediately preceding and immediately following the missing 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, a substitute data value for the missing parameter must be used in the
calc ulations as specified in paragraphs (a) and (b) of
this section. (a) For each missing value of the inorganic carbon

content or CO 2 content of phosphate rock (by origin), Correction; clarifies the general requirement for missing data, removes a duplicate paragraph,
clar ifies the data element of inorganic carbon content may also be represented by CO 2 content, and corrects the equation reference.

### 46

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change data incident. You must document and keep records of the procedures used for all such estimates. (a) For each missing value of the inorganic carbon content of phosphate rock (by origin), you must use the appropriate default factor provided in Table Z

– 1 of this subpart. Alternatively, the you must determine substitute data value by calculating the arithmetic average of the quality

- assured values of inorganic
carbon conten ts of phosphate rock of origin i (see Equation Z

– 1 of this subpart) from samples immediately preceding and immediately following the missing data incident. If no quality

- assured data on inorganic carbon contents of phosphate rock of origin i are available prior to the missing data incident, the substitute data value shall be the first quality

- assured value for inorganic carbon contents for phosphate rock of origin i obtained after the missing data period. you must use the appropriate default factor provided
in Table Z

– 1 of this subpart. A lternatively, you must determine a substitute data value by calculating the arithmetic average of the quality

- assured values of inorganic carbon contents or CO 2 contents of phosphate rock of origin i (see Equation Z

– 1a or Z

1b of this subpart) from sample s immediately preceding and immediately following the missing data incident. If no quality

- assured data on inorganic
carbon contents or CO 2 contents of phosphate rock of origin i are available prior to the missing data incident, the substitute data value s hall be the first quality

- assured value for inorganic carbon contents

or CO 2 contents for phosphate rock of origin i obtained after the missing data period.

Z 98.266(a) (a) Annual phosphoric acid production by origin (as

listed in Table Z

– 1 to this subpart) of the phosphate rock (to ns). (a) Annual phosphoric acid production, by origin of the phosphate rock (tons). Removes a reference to Table Z

- 1. The reporting element could have a place of origin other than those
listed in Table Z

- 1

Z 98.266(b) (b) Annual phosphoric acid permitted production

capacity (tons) (b) Annual phosphoric acid production capacity (tons) See preamble text for explanation

Z 98.266(d) (d) Annual phosphate rock consumption from

monthly measurement records by origin, (as listed in
Table Z

– 1 to this subpart) (tons ). (d) Annual phosphate rock consumption from monthly measurement records by origin (tons). Clarifies reporting requirements

Z 98.266(f)(5) (5) Monthly inorganic carbon content of phosphate

rock for each wet

- process phosphoric acid process line for which Equation Z

– 1a is used (percent by weight, expressed as a decimal fraction), or CO 2 (percent by weight, expressed as a decimal fraction)
for w hich Equation Z

– 1b is used. (5) Monthly inorganic carbon content of phosphate
rock for each wet

- process phosphoric acid process line for which Equation Z

– 1a is used (percent by weight, expressed as a decimal fraction), or CO 2 content (percent by weight, ex pressed as a decimal fraction) for which Equation Z

– 1b is used. Clarifies reporting requirements

Z 98.266(f)(6) (6) Monthly mass of phosphate rock consumed by

origin, (as listed in Table Z

– 1 of this subpart) in production for each wet

- process phosphoric a cid process line (tons). (6) Monthly mass of phosphate rock consumed, by origin, in production for each wet

- process phosphoric acid process line (tons). Clarifies reporting requirements

Z 98.266(f)(8) (8) Number of times missing data procedures were

used to estimate phosphate rock consumption (months) and inorganic carbon contents of the (8) Number of times missing data procedures were used to estimate phosphate rock consumption (months), inorganic carbon contents of the phosphate Adds reporting requirement for missing data procedures

### 47

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change phosphate rock (months). rock (months), and CO 2 contents of the phosphate rock (months).

Z 98.267(a) (a) Monthly mass of phosphate rock consumed by

origin (as listed in Ta ble Z

– 1 of this subpart) (tons). (a) Monthly mass of phosphate rock consumed by origin (tons). Removes a reference to Table Z

- 1. The reporting element could have a place of origin other than those
listed in Table Z

- 1

Z 98.26(c ) (c) Documentation of the procedures used to ensure

the accuracy of monthly phosphate rock consumption by origin, (as listed in Table Z

– 1 of this subpart). (c) Documentation of the procedures used to ensure the accuracy of monthly phosphate rock consumption by origin. Removes a ref erence to Table Z

- 1. The reporting element could have a place of origin other than those
listed in Table Z

- 1

AA 98.273(a)(3) (3) Calculate biogenic CO 2 emissions and emissions
of CH 4 and N 2 O from biomass using measured quantities of spent liquor solids fired, site

- specific HHV, and default or site

- specific emissions factors, according to Equation AA

– 1 of this section:

*** (Variable from Equation AA

- 1:) (EF) = Default or site

- specific emissio n factor for
CO 2 , CH 4 , or N 2 O , from Table AA

– 1 of this subpart (kg CO 2 , CH 4 , or N 2 O per mmBtu). (3) Calculate biogenic CO 2 emissions and emissions
of CH 4 and N 2 O from biomass using measured quantities of spent liquor solids fired, site

- specific HHV, and de fault emissions factors, according to Equation AA

– 1 of this section:

*** (Variable from Equation AA

- 1:) (EF) = Default emission factor for CO 2 , CH 4 , or N 2 O , from Table AA

– 1 of this subpart (kg CO 2 , CH 4 ,

or N 2 O per mmBtu). See preamble text for explanation

AA 98.276(e) (e) The default or site

- specific emission factor for
CO 2 , CH 4 , or N 2 O , used in Equation AA

– 1 of this subpart (kg CO 2 , CH 4 , or N 2 O per mmBtu). (e) The default emission factor for CO 2 , CH 4 , or N 2 O , used in Equation AA

– 1 of this subpart (kg
CO 2 , CH 4 , or N 2 O per mmBtu). Harmonize with change made to 98.273(a)(3)

AA 98.276(k) (k) Annual production of pulp and/or paper products produced (metric tons). (k) Annual production of pulp and/or paper products produced (metric tons) as follows: (1) Report the total annual production of unbleached virgin pulp produced onsite during the reporting year
in air

- dried metric tons per year. This total annual production value is the sum of all kraft, semichemical, soda, and sulfite pulp produced onsite, prior to b leaching, through all virgin pulping lines. (i) Do not include secondary fiber repulped for paper production in the virgin pulp production total. (ii) You must report a positive (non

- zero) value for pulp production unless your pulp mill did not operate
du ring the reporting year. (2) Report the total annual production of paper products exiting the paper machine(s), prior to application of any off

- machine coatings, in air

- dried See preamble text for explanation

### 48

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change metric tons per year. If you operate multiple paper machines, report the sum (to tal) of the air

- dried metric tons of paper produced during the reporting year for all paper machines at the mill.

AA Tables AA

- 1
& AA

- 2 See Tables AA

- 1 and AA

- 2 in the current rule file. See Appendix A for changes to Tabl e AA

- 1 and AA

2 See preamble text for explanation

BB 98.282(a) (a) CO 2 and CH 4 process emissions from all silicon carbide process units or furnaces combined. (a) CO 2 process emissions from all silicon carbide process units or furnaces combined. See preamble text for explanation

BB 98.283 Introductory paragraph 98.283 Calculating GHG Emissions

.

You must calculate and report the annual process
CO 2 emissions from each silicon carbide process unit or production furnace using the procedures in either paragraph (a) or (b) of this section. You must
determine CH 4 process emissions in accordance with the procedures specified in paragraph (d) of this

sect ion. 98.283 Calculating GHG Emissions

. You must calculate and report the combined annual

process CO 2 emissions from all silicon carbide process units and production furnaces using the procedures in either paragraph (a) or (b) of this
section. See preamble text for explanation

BB 98.283(a) (a) Calculate and report under this subpart the

process CO 2 emissions by operating and maintaining CEMS according to the Tier 4 Calculation Methodology specified in §98.33(a)(4) and all associated requirements for Tier 4 in subpart C of this part (General Stationary Fuel Combustion Sources). (a) Calculate and report under this subpart the combined annual process CO 2 emissions by operating and maintaining CEMS according to the Tier 4 Calculation Methodology specified in §9 8.33(a)(4) and all associated requirements for Tier 4 in subpart C of this part (General Stationary Fuel Combustion Sources). Harmonizing change with 98.283 introductory paragraph.

BB 98.283(b) (b) Calculate and report under this subpart the

process CO 2 emissions using the procedures in paragraphs (b)(1) and (b)(2) of this section. (b) Calculate and report under this subpart the combined annual process CO 2 emissions using the procedures in paragraphs (b)(1) and (b)(2) of this
section. Harmonizing change with 98.283 introductory paragraph.

BB 98.283(b)(2) (2) Use Equation BB

– 2 of this section to calculate
annual CO 2 process emissions from all silicone carbide production: (2) Calculate annual CO 2 process emissions from the silicon carbide production facility according to Equation BB

- 2 of this section: Corrects misspelling and clarifies requirement

BB 98.283(b)(2) T

n = Petroleum coke consumption in month n(tons) T

n = Petroleum coke consumption in calendar month n(tons) Clarifies equation term

BB 98.283(d) (d) You must calculate annual process CH 4 emissions from all silicon carbide production combined using Equation BB

– 3 of this section: Eq. BB

- 3 (d) [Reserved] See preamble text for explanation

BB 98.286(b) (b) If a CEMS is not used to measure process CO 2 emissions, you must report the information listed in (b) If a CEMS is not used to measure process CO 2 emissions, you must report the information in Correction for consistency with 40 CFR 98.282.

### 49

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change this paragraph (b) for all furnaces combined: pa ragraph (b)(1) through (b)(8) of this section for all silicon carbide process units or production furnaces
combined:

DD 98.304(c)(1) (1) Ensure that cylinders returned to the gas supplier are consistently weighed on a scale that is certified to be accurate and precise to within 2 pounds of the scale's capacity and is periodically recalibrated per the manufacturer's specifications. Either measure residual gas (the amount of gas remaining in returned cylinder s) or have the gas supplier measure it. If the gas supplier weighs the residual gas, obtain from the gas supplier a detailed monthly accounting, within ± 2 pounds, of residual gas amounts in the cylinders returned to the gas supplier. (1) Ensure that cylin ders returned to the gas supplier are consistently weighed on a scale that is certified to be accurate and precise to within 2 pounds of true weight and is periodically recalibrated per the manufacturer's specifications. Either measure residual gas (the am ount of gas remaining in returned cylinders) or have the gas supplier measure it. If the gas supplier weighs the residual gas, obtain from the gas supplier a detailed monthly accounting, within ± 2 pounds, of residual gas amounts in the cylinders
returned to the gas supplier. See preamble text for explanation

DD 98.304(c)(2) (2) Ensure that cylinders weighed for the beginning and end of year inventory measurements are weighed
on a scale that is certified to be accurate to within 2 pounds of the scale's cap acity and is periodically recalibrated per the manufacturer's specifications. All scales used to measure quantities that are to be reported under §98.306 must be calibrated using calibration procedures specified by the scale
manufacturer. Calibration must be performed prior to the first reporting year. After the initial calibration, recalibration must be performed at the minimum frequency specified by the manufacturer. (2) Ensure that cylinders weighed for the beginning and end of year inventory measurement s are weighed on a scale that is certified to be accurate and precise to within 2 pounds of true weight and is periodically recalibrated per the manufacturer's specifications. All scales used to measure quantities that are to be reported under §98.306 must be calibrated using calibration procedures specified by the scale manufacturer. Calibration must be performed prior to the first reporting year. After the initial calibration, recalibration must be performed at the minimum frequency specified by the manuf acturer. See preamble text for explanation

FF 98.320(b)(1) (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). (1) Each ventilation system shaft or vent hole, including both those points where mine ventilation air is emitted and those where it is sold, used onsite, or otherwise destroyed (including by ventilation air methane (VAM) oxidizers). See preamble text for explanati on

FF 98.320(b)(2) (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 w here gas is sold, used onsite, or otherwise destroyed (including by flaring). (2) Each degasification system well or gob gas vent hole, including degasification systems deployed before, during, or after mining operations are
conducted in a mine area. This includes both those wells and vent holes where coal bed gas is emitted, and those where the gas is sold, used onsite, or otherwise destroyed (including by flaring). See preamble text for explanation

### 50

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

FF 98.322(b) (b) You must report CH 4 destruction from sy stems where gas is sold, used onsite, or otherwise destroyed (including by flaring). (b) You must report CH 4 destruction from systems where gas is sold, used onsite, or otherwise destroyed (including by VAM oxidation and by flaring). See preamble text for explanation

FF 98.322(d) (d) You must report under this subpart the CO 2 emissions from coal mine gas CH 4 destruction occurring at the facility, where the gas is not a fuel input for energy generation or use ( e.g., flaring). (d) You must report under this subpart the CO 2 emissions from coal mine gas CH 4 destruction occurring at the facility, where the gas is not a fuel input for energy generation or use ( e.g., flaring and VAM oxidation). See preamble text for explanation

FF 98.323(a) V = Volumetric flow rate for the quarter (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‖. V = Volumetric flow rate for the quarter (acfm) based on sampling or a flow rate meter. If a flow rate meter is used and the meter automatically corrects to standard temperature and pressure, then use scfm and replace ―520°R/T × P/1 atm‖ with ―1‖. Clarifies an equation term

FF 98.323(a) 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

- (f H2O )

n when V
is measured on a wet basis and C is measured on a dry basis.= 1 /[1

- (f H2O )] when V is measured on a dry
basis and C is measured on a wet basis. 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

- (f H2O ) w hen V
is measured on a wet basis and C is measured on a dry basis.= 1/[1

- (f H2O )] when V is measured on a dry
basis and C is measured on a wet basis. Corrects subscript errors

FF 98.323(a) (f H 2 O ) = Moisture content of the methane emitted during the measure ment period, volumetric basis (cubic feet water per cubic feet emitted gas). (f H2O ) = Moisture content of the methane emitted during the measurement period, volumetric basis (cubic feet water per cubic feet emitted gas). Corrects subscript errors

FF 98.323(a) 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. P = Absolute pressure at which flow is measured (atm) for the quarter. Th e annual average barometric pressure from the nearest NOAA weather service station may be used as a default. See preamble text for explanation

FF 98.323(a)(2) (2) Values of V, C, T, P, and (fH2O), if applicable... (2) Values of V, C, T, P, and (f H2O ), if applicable... Corrects subscript errors

FF 98.323(b) Equation FF

3 T T i Corrects subscript errors

FF 98.323(b) V i = 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 V i = 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 (acfm). If a flow rate Clarification of equation term

### 51

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change meter is used and the meter automatically corrects for temperatur e and pressure, replace ―520°R/Ti×
Pi/1 atm‖ with ―1‖. meter is used and the meter automatically corrects to standard temperature and pressure, then use scfm and replace ―520°R/Ti× Pi/1 atm‖ with ―1‖.

FF 98.323(b) fH 2 O f H2O Corrects subscript errors

FF 98.323(b) P i = Pressure at which flow is measured (atm). P i = Absolute pressure at which flow is measured (atm). Clarifies an equation term

FF 98.323(b)(1) (1) Values of V, C, T, P, and (fH2O), if applicable
must be based on measurements taken at least once each quar ter 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
contin u ous measurements are taken, then use the average value over the time peri od of continuous monitoring. (1) Values of V, C, T, P, and (f H2O ), if applicable
must be based on measurements taken at least once each quarter with no fewer than 6 weeks between
measurements. If measurements are taken more frequently than once per quarter , then use the average value for all measurements taken. If continuous measurements are taken, then use the average value over the time period of continuous monitoring. Corrects subscript errors and typographical error.

FF 98.323(b)(2) CH 4 D ( CH 4 D ) i.j Corrects subscript errors

FF 98.323(c) (c) If gas from degasification system wells or ventilation shafts is sold, used onsite, or otherwise destroyed (including by flaring), you must calculate the quarterly CH 4 destroyed for each destruction
device and ea ch point of offsite transport to a destruction device, using Equation FF

– 5 of this
section. You must measure CH 4 content and flow rate according to the provisions in §98.324, and
calculate the methane routed to the destruction device ( CH 4 ) using either Equ ation FF

– 1 or Equation

FF

– 3 of this section, as applicable. (c) If gas from a degasification system or ventilation system is sold, used onsite, or otherwise destroyed (including by flaring or VAM oxidation), you must calculate the quarterly CH 4 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 CH 4 content and flow rate according to the provisions in §98.324, and
calculate the methane routed to the destruction device ( CH 4 ) using either Equation FF

– 1 or Equation

FF

– 4 of this section, as applicable. Clarifies terminology and equation reference

### 52

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

FF 98.323 (c ) Equation FF

6 Corrects equation term

FF 98.324(b) (b) For CH 4 liberated from ventilation systems,
determine whether CH 4 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 fr om 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: (b) For CH 4 liberated from ventilation systems,
determine whether CH 4 will be monitored from each ventilation shaft and vent hole, from a centralized monitoring point, or from a combination of the two options. Operators are allowed flexibility for aggregating emissio ns from more than one ventilation point, as long as emissions from all are addressed, and the methodology for calculating total emissions documented. Monitor by one of the following options: Clarifies rule text.

FF 98.324(c)(2) (2) Collect weekly (once ea ch 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 degasi fication 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 emis sions 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 (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 con centration, 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 monitoring sit e. 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), th e bottle number of samples collected, and the location of the measurement or Clarifies rule text.

### 53

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

collection. collection.

FF 98.324(d)(2)( iii) C CH 4 C CH 4 Corrects subscript errors

FF 98.326(a) (a) Quarterly CH 4 liberated from each ventilation monitoring point ( CH 4 Vm ), (metric tons CH 4 ). (a) Quarterly CH 4 liberated from each ventilation monitoring point, (metric tons CH 4 ). Clarifies rule text

FF 98.326(f) (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 of this subpart. (f) Quarterly volumetri c flow rate for each ventilation monitoring point and units of measure (scfm or acfm), date and location of each measurement, and method of measurement (quarterly sampling or continuous monitoring), used in Equation FF

– 1 of this subpart. Harmonizes report ing requirement with equations.

FF 98.326(h) (h) Weekly volumetric flow rate used to calculate
CH 4 liberated from degasification systems (cfm) and method of measurement (sampling or continuous monitoring), used in Equation FF

– 3 of this subpart. (h) Weekly volumetric flow rate used to calculate
CH 4 liberated from degasification systems and units of measure (acfm or scfm), and method of measurement (sampling or continuous monitoring), used in Equation FF

– 3 of this subpart. Harmonizes reporting requirement with equations

FF 98.326(i) (i) Quarterly CEMS CH 4 concentration (%) used to
calculate CH 4 liberated from degasification systems (average from daily data), or quarterly CH 4 concentration data based on results from weekly sampling data) (C). (i ) Quarterly CH 4 concentration (%) used to calculate
CH 4 liberated from degasification systems and if the data is based on CEMS or weekly sampling. Includes the basis of the concentration data in the
report.

FF 98.326(j) (j) Weekly volumetric flow rate used to calculate
CH 4 destruction for each destruction device and each point of offsite transport (cfm). (j) Weekly volumetric flow rate used to calculate
CH 4 destruction for each destruction device and each point of offsite transport, and units of measure (acfm or scfm). Harmonizes reporting requirement with equations.

FF 98.326(o) (o) Temperatures (°R), pressure (atm), and moisture content used in Equation FF

– 1 and FF

– 3 of this subpart, and the gaseous organic concentrati on correction factor, if Equation FF

– 9 was required. (o) Temperatures (°R), pressure (atm), moisture content, and the moisture correction factor (if applicable) used in Equation FF

– 1 and FF

– 3 of this subpart; and the gaseous organic concentration
correctio n factor, if Equation FF

– 9 was required. See preamble text for explanation

FF 98.326(r) (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. (r) Identification information and description for each well and shaft, including paragraphs (r)(1) through (r)(3) of this section: (1) Indication of whether the well or shaf t is monitored individually, or as part of a centralized monitoring point. Note which method (sampling or See preamble text for explanation

### 54

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change continuous monitoring) was used. (2) Start date and close date of each well or shaft. (3) Number of days the well or shaft was in operation during t he reporting year.

FF 98.326(t) No current requirement (t) Quarterly CH 4 routed to each destruction device or offsite transfer point used in Equation FF

- 5 of this subpart (metric tons). See preamble text for explanation

FF 98.326(u) No current requirement (u) Mine Safety and Health Administration (MSHA)
identification for this coal mine See preamble text for explanation

HH 98.343(a)(1) Equation HH

1 DOC = Degradable organic carbon from Table HH

- 1

of this subpart or measurement data, if available [fraction (metric tons C/metric ton waste)]. DOC = Degradable organic carbon from Table HH

- 1 of this subpart [fraction (metric tons C/metric ton waste)]. See preamble text for explanation

HH Equation HH

1, 98.345 F = Fractio n by volume of CH 4 in landfill gas from

measurement data on a dry basis, if available (fraction); default is 0.5. F = Fraction by volume of CH 4 in landfill gas from measurement data for the current reporting year, if available (fraction, dry basis, correct ed to 0 percent oxygen); otherwise, use the default of 0.5. See preamble text for explanation

HH 98.343(b)(1) Equation HH

4 (C)

n (C CH 4 )

n Corrects equation term

HH 98.343(b)(1) Equation HH

4 N = Total number of measurement periods in a year.

Use daily averaging periods for a continuous monitoring system and N=365 (or N = 366 for leap years). For weekly sampling, as provided in paragraph (b)(2) of this section, use N=52. N = Total number of measurement periods in a year. Use daily averaging periods for a continuous monitoring system and N=365 (or N = 366 for leap years). For monthly sampling, as provided in paragraph (b)(2) of this section, use N= 1 2. See preamble text for explanation

HH HH

- 4 0.0423 = Density of CH 4 lb/cfm at 520°R or 60 degrees Fahrenheit and 1 atm. 0.0423 = Density of CH 4 lb/cf at 520°R or 60 degrees Fahrenheit and 1 atm. Corrects typographical error

HH 98.343(b)(2)( i) (i) Continuously monitor gas flow rate and determine

the cumulative volume of l andfill gas each week and the cumulative volume of landfill gas each year that
is collected and routed to a destruction device (before any treatment equipment). Under this option, the gas flow meter is not required to automatically correct for temperature , pressure, or, if necessary, moisture content. 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 (b)(2)(iii) of this section. (i) Continuously monitor gas flow rate and determine the cumulative volume of landfill gas each month and the cumulative volume of landfill gas each year
that is collected and routed to a destruction device (before any treatment equipment). Under this option, the gas flow meter is not required to automatically correct for temperature, pressure, or, if necessary, moisture content. If the gas flow meter is not equipped with automatic correction for temperature, pressure, or, if necessary, moist ure content, you must determine these parameters as specified in paragraph (b)(2)(iii) of this section. Harmonizing change to accommodate monthly sampling of CH 4 concentration

### 55

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

HH 98.343(b)(2)( ii) (ii) Determine the CH 4 concentration in the landfill

gas th at is collected and routed to a destruction device (before any treatment equipment) 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 at least three days between

measurements. (ii) Determine the CH 4 concentration in the landfill gas that is collected and routed to a destruction device (before any treatment equipment) in a location near or representative of the location of the gas flow meter at least once each calendar month; if only one measurement is made each calendar month, there must be at least fourteen days between

measurements. Harmonizing change to accommodate monthly sampling of CH 4 concentration

HH 98.343(b)(2)( iii)(A) (A) Determine the temperature and pressure in the

landfill gas that is collected and routed to a destruction device (before any treatment equipment) 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 at least three days between

measurements. (A) Determine the temperature and pressure in the landfill gas that is collected and routed to a destruction device (before any treatment equipme nt) in a location near or representative of the location of the gas flow meter at least once each calendar month; if only one measurement is made each calendar month, there must be at least fourteen days between

measurements. Harmonizing change to accommo date monthly sampling of CH 4 concentration

HH 98.343(b)(2)( iii)(B) (B) If the CH 4 concentration is determined on a dry

basis and flow is determined on a wet basis or CH 4 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 moisture content in the landfill gas that
is collected and routed to a destruction device (before any treatment equipment) in a location near or representative of the locati on of the 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 CH 4 concentration is determined on a dry
basis and flow is determined on a wet basis or CH 4 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 moisture content in the landfill gas that
is collected and routed to a des truction device (before any treatment equipment) in a location near or representative of the location of the gas flow meter at least once each calendar month; if only one measurement is made each calendar month, there must be at least fourteen days between

measurements. Harmonizing change to accommodate monthly sampling of CH 4 concentration

HH 98.343(c )(1) (Eq. HH

- 5) OX = Oxidation fraction. Use the default value of

0.1 (10%). OX = Oxidation fraction. Use the appropriate
oxidation fraction default value from Table HH

- 4 of this subpart. See preamble text for explanation

HH 98.343(c )(3)(i) (Eq. HH

- 6) See preamble text for explanation

HH 98.343(c (None) N = Number of landfill gas measurement locations Harmonizing with change s to Equation HH

- 6 for

### 56

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

)(3)(i) (Eq. HH

- 6) (associated with a destruction device or gas sent off

site). If a single monitoring location is used to
monitor volumetric flow and CH 4 concentration of the recovered gas sent to one or multiple destruction devices, then N=1. multiple measurement locations and/or multiple
destruction devices

HH 98.343(c )(3)(i) (Eq. HH

- 6) R = Quantity of recovered CH 4 from Equation HH

- 4

of this section (metric tons). R

n = Quantity of recovered CH 4 from Equation HH

- 4
of this section for the n th measurement location (metric tons). Harmonizing with change s to Equation HH

- 6 for multiple measurement locations and/or multiple
destruction devices

HH 98.343(c )(3)(i) (Eq. HH

- 6) OX = OX = Oxidation fraction. Use the default

value of 0.1 (10%). OX = Oxidation fraction. Use the appropriate
oxidation fraction default value from Table HH

- 4 of this subpart. See preamble text for explanation

HH 98.343(c )(3)(i) (Eq. HH

- 6) 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. DE

n = Destruction efficiency (lesser of manufacturer's specified destruction efficiency and
0 .99) for the nth measurement location. If the gas is transported off

- site for destruction, use DE = 1. If the
volumetric flow and CH 4 concentration of the recovered gas is measured at a single location providing landfill gas to multiple destruction devices (including some gas destroyed on

- site and some gas
sent off

- site for destruction), calculate DE

n as the arithmetic average of the DE values determined for
each destruction device associated with that
measurement location. Harmonizing with change s to Equat ion HH

- 6 for multiple measurement locations and/or multiple
destruction devices

HH 98.343(c )(3)(i) (Eq. HH

- 6) f Dest = Fraction of hours the destruction device was operating (annual operating hours / 8760 hours per year). If the gas is destroyed in a back

- up flare (or similar device) or if the gas is transported off

- site for destruction, use f Dest = 1. f Dest,n = Fraction of hours the destruction device

associated with the n th measurement location was operating during active gas flow calculated as the annual operating hours for the destruction device divided by the annual hours flow was sent to the
destruction devi ce as measured at the n th

measurement location

. If the gas is destroyed in a
back

- up flare (or similar device) or if the gas is transported off

- site for destruction, use f Dest = 1. If the
volumetric flow and CH 4 concentration of the recovered gas is measure d at a single location providing landfill gas to multiple destruction devices (including some gas destroyed on

- site and some gas
sent off

- site for destruction), calculate f Dest,n as the arithmetic average of the f Dest values determined for Harmonizing with change s to Equation HH

- 6 for multiple measurement locations and/or multiple
destruction devices and clarifies equation term to more accurately reflect operating hours of the gas collection system.

### 57

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

each destruction device associated with that

measurement

HH 98.343(c )(3)(ii) (Eq. HH

- 7) See preamble for discussion

HH 98.343(c )(3)(ii) (Eq. HH

- 8) See preamble for discussion

HH 98.343(c )(3)(ii) (Eq. HH

- 8) (None) N = Number of landfill gas measurement locations (associated with a destruction device or gas sent off

site). If a single monitoring location is used to
monitor volumetric flow and CH 4 concentration of the recovered gas sent to one or multiple destruction devices, then N=1. Harmonizing with change s to Equation HH

- 8 for multiple measurement locations and/or multiple
destruction devices

HH 98.343(c )(3)(ii) (Eq. HH

- 8) R = Quantity of recovered CH 4 from Equation HH

- 4

of this section (metric tons CH 4 ). R

n = Quantity of recovered CH 4 from Equation HH

- 4
of this section for the n th measurement location (metric tons CH 4 ). Harmonizing with change s to Equation HH

- 8 for multiple measurement locations and/or multiple
destruction devices

HH 98.343(c )(3)(ii) (Eq. HH

- 8) f Rec = Fraction of hours the recovery system was operating (annual operating hours/8760 hours per year). f Rec,n = Fraction of hours the recovery system
associated with the n th measurement location was operating (annual operating hours/8760 hours per

year or annual operating hours / 8 784 per year for a leap year ). Harmonizing with change s to Equation HH

- 8 for multiple measurement locations and/or multiple
destruction devices

H H 98.343(c )(3)( i i) (Eq. HH

- 8 ) OX = Oxidation fraction. Use the default value of

0.1 (10%). OX = Oxidation fraction. Use appropriate oxidation
fraction default value from Table HH

- 4 of this subpart. See preamble text for explanation

HH 98.343(c )(3)(ii) (Eq. HH

- 8) 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. DE

n = Destruction efficiency (lesser of manufacturer's specified destruction effi ciency and 0.99) for the n th measurement location. If the gas is transported off

- site for destruction, use DE = 1. If the
volumetric flow and CH 4 concentration of the Harmonizing with chan ge s to Equation HH

- 8 for multiple measurement locations and/or multiple
destruction devices

### 58

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change recovered gas is measured at a single location providing landfill gas to multiple destruc tion devices (including some gas destroyed on

- site and some gas
sent off

- site for destruction), calculate DE

n as the arithmetic average of the DE values determined for
each destruction device associated with that
measurement location.

HH 98.343(c)(3)(i i) (Eq. HH

- 8) F Dest, = Fraction of hours the destruction device was operating (device operating hours/8760 hours per year). If the gas is destroyed in a back

- up flare (or similar device) or if the gas is transported off

- site for destruction, use f Dest = 1. f Dest,n = Fraction o f hours the destruction device

associated with the n th measurement location was operating during active gas flow calculated as the annual operating hours for the destruction device divided by the annual hours flow was sent to the
destruction device as measured at the n th

measurement location

. If the gas is destroyed in a
back

- up flare (or similar device) or if the gas is transported off

- site for destruction, use f Dest = 1. If the
volumetric flow and CH 4 concentration of the recovered gas is measured at a single location providing landfill gas to multiple destruction devices (including some gas destroyed on

- site and some gas
sent off

- site for destruction), calculate f Dest,n as the arithmetic average of the f Dest values determined for
each destruction devic e associated with that

measurement location. Harmonizing with change s to Equation HH

- 8 for multiple measurement locations and/or multiple destruction devices and clarifies equation term to more accurately reflect operating hours of gas collection system

HH 98.344(e) (e) The owner or operator shall document the procedures used to ensure the accuracy of the estimates of disposal quantities and, if applicable, gas flow rate, gas composition, temperature, pressure, and moisture content measurements. These

pro cedures 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. (e) For landfills electing to measure the fraction by
volume of CH 4 in landfill gas (F), follow the requirements in paragraphs (e)(1) and (e)(2) of this
section. (1) Use a gas composition monitor capable of measuring the concentration of CH 4 on a dry basis that is properly operated, calibrated, and maintained according to the requirements specified in paragraph (b) of this section. You must either use a gas composi tion monitor that is also capable of measuring the O 2 concentration correcting for excess (infiltration) air or you must operate, maintain, and Harmonizing change to accommodate the correction to 0 percent oxygen for CH 4 content of landfill gas

### 59

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change calibrate a second monitor capable of measuring the
O 2 concentration on a dry basis according to the
manufacture r's specifications. (2) Use Equation HH

- 10 of this section to correct the
measured CH 4 concentration to 0 % oxygen. If multiple CH 4 concentration measurements are made during the reporting year, determine F separately for each measurement made during the re porting year,
and use the results to determine the arithmetic average value of F for use in Equation HH

– 1 of this
part.

F = (C CH 4 /100%)x[20.9c/(20.9

- %O2)] (Eq. HH

10)

Where: F = Fraction by volume of CH 4 in landfill gas (fraction, dry basis, correc ted to 0 percent oxygen).
C CH 4 = Measured CH 4 concentration in landfill gas (volume percent, dry basis).
20.9

c = Defined O 2 correction basis, (volume percent, dry basis).
20.9 = O 2 concentration in air (volume percent, dry basis).
%O 2 = Measured O 2 concent ration in landfill gas (volume percent, dry basis).

HH 98.344(f) (None) (f) The owner or operator shall document the procedures used to ensure the accuracy of the estimates of disposal quantities and, if applicable, 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 me ters, 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. Harmonizing change. Moves paragraph to accommodate new paragraph (e)

HH 98.345(c) (c) For missing daily waste disposal quantity data for disposal in reporting years, the substitute value (c) For missing daily waste disposal quantity data for disposal in the reporting year, the substitute value See preamble text for explanation

### 60

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change shall be the average daily waste disposal quantity for that day of the week as measured on the week before and week after the missing daily data. shall be the average daily waste disposal quantity for that day of the week as measured on the week before and week after the missing d aily data.

HH 98.346(d)(1) (1) Degradable organic carbon (DOC), methane correction factor (MCF), and fraction of DOC dissimilated (DOCF) values used in the calculations.
If an MCF value other than the default of 1 is used, provide an indication of whether active aeration of the waste in the landfill was conducted during the reporting year, 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. (1) Degradable organic carbon (DOC) and fraction of DOC dissimilated (DOC F ) values used in the
calculat ions. See preamble text for explanation

HH 98.346(e) (e) Fraction of CH 4 in landfill gas (F), and an
indication of whether the fraction of CH 4 was determined based on measured values or the default
value (e) Fraction of CH 4 in landfill gas (F), an indication
of whether the fraction of CH 4 was determined based on measured values or the default value, and the methane correction factor (MCF) used in the
calculations. If an MCF other than the default of 1 is used, provide an ind ication of whether active
aeration of the waste in the landfill was conducted during the reporting year, a description of the aeration system, including aeration blower capacity, the fraction of the landfill containing waste affected by 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. See preamble for discussion

### 61

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

HH 98.346(h) (h) For landfills without gas collection systems, the annual methane emissions (i.e., the methane generation, adjusted for oxidation, calculated using Equation HH

– 5 of this subpart), reported in metric tons CH4, and an indication of whether passive vents and/or passive flares (vents or flares that are not considered part of the gas collec tion system as defined in §98.6) are present at this landfill. (h) For landfills without gas collection systems, the annual methane emissions (i.e., the methane generation, adjusted for oxidation, calculated using Equation HH

– 5 of this subpart), reported i n metric
tons CH 4 , the oxidation fraction used in the calculation, and an indication of whether passive vents and/or passive flares (vents or flares that are not considered part of the gas collection system as defined in §98.6) are present at this landfill

. Harmonizes reporting requirements with calculation
method.

HH 98.346(i)(5) (5) An indication of whether destruction occurs at the landfill facility o r offsite . If destruction occurs at the landfill facility, also report an indication of
whether a back

- up destruction device is present at the landfill, the annual operating hours for the primary destruction device, the annual operating
hours for the back

- up destruction device (if present), and the destruction efficiency used (percent). (5) An indicat ion of whether destruction occurs at the landfill facility, off

- site, or both. If destruction occurs at the landfill facility, also report for each
measurement location an indication of whether a
back

- up destruction device is present at the landfill,
the a nnual operating hours for the primary destruction device, the annual operating hours for the
back

- up destruction device (if present), and the destruction efficiency used (percent). Clarification to provide landfills that use both off

- site
and on

- site destruction a clear and accurate reporting option.

HH 98.346(i)(8) (8) Methane generation corrected for oxidation calculated using Equation HH

- 5 of this subpart, reported in metric tons CH4

. (8) Methane generation corrected for oxidation calculated using Equation HH

- 5 of this subpart, reported in metric tons CH4, and the oxidation
fraction used in the calculation Harmonizes reporting requirements with calculation
method.

HH 98.346(i)(10) (8) Methane generation corrected for oxidation calculated using Equation HH

- 7 of this subpart, reported in metric tons CH4

. (8) Methane generation corrected for oxidation calculated using Equation HH

- 7 of this subpart, reported in metric tons CH4, and the oxidation
fraction used in the calculation Harmonizes reporting requirements with calculation
method.

HH 98.346(i)(11) (8) Methane generation corrected for oxidation calculated using Equation HH

- 6 of this subpart, reported in metric tons CH4

. (8) Methane generation corrected for oxidation calculated using Equation HH

- 6 of this subpart, reported in metric tons CH4, and the oxidation
fraction used in the calculation Harmonizes reporting requirements with calculation
method.

HH 98.346(i)(12) (8) Methane generation corrected for oxidation calculated using Equa tion HH

- 8 of this subpart, reported in metric tons CH4

. (8) Methane generation corrected for oxidation calculated using Equation HH

- 8 of this subpart, reported in metric tons CH4, and the oxidation
fraction used in the calculation Harmonizes reporting requ irements with calculation
method.

### 62

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

HH 98.348 (None) Landfill capacity means the maximum amount of solid waste a landfill can accept. For the purposes of this subpart, for landfills that have a permit, the landfill capacity can be determined in terms of 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 from volume to mass to determine its capacity, the calculation must
include a site

- spec ific density. Add definition to clarify meaning of term as used in
the rule.

HH 98.348 (None) Leachate recirculation means the practice of taking
the leachate collected from the landfill and reapplying it to the landfill by any of one of a variety
of me thods, including pre

- wetting of the waste, direct discharge into the working face, spraying, infiltration ponds, vertical injection wells, horizontal gravity distribution systems, and pressure distribution systems. Add definition to clarify meaning of term as used in
the rule.

HH Table HH

- 2 Table HH

- 2 See Appendix A for changes to Table HH

- 2 Effect changes that were intended to be made in the October 28, 2010 (75 FR 66474) amendments and
revise the last line of this table to read "2009 and all
later years".

HH Table HH

- 4 None See Appendix A for Table HH

- 4 See preamble text for explanation

II 98.353(d)(2)

- Eq. II

- 6 f Dest_1 = Fraction of hours the primary destruction device was operating (device operating hours/hours in the year). If the biogas is transported off

- site for destruction, use f Dest = 1. f Dest_1 = Fraction of hours the primary destruction device was operating cal culated as the annual hours when the destruction device was operating divided by the annual operating hours of the biogas recovery system. If the biogas is transported off

- site for destruction, use f Dest = 1. Clarifies an equation term to more accurately r eflect operating hours of biogas recovery system.

II 98.353(d)(2)

- Eq. II

- 6 f Dest_2 = Fraction of hours the back

- up destruction device was operating (device operating hours/hours in the year). f Dest_2 = Fraction of hours the back

- up destruction device was operating calculated as the annual hours when the destruction device was operating divided by the annual operating hours of the biogas recovery
system. Clarifies equation term to more accurately refle ct operating hours of biogas recovery system.

LL 98.386(a)(1) (1) For each product listed in Table MM

- 1 of subpart MM of this part that enters the coal

- to

- liquid facility to be further processed or otherwise used on site, report the annual quantity in metric tons or barrels by (1) [Reserved.] See preamble text for explanation

### 63

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change each quantity measurement standard metho d or other industry standard practice used. For natural gas liquids, quantity shall reflect the individual components of the product.

LL 98.386(a)(4) (4) Each standard method or other industry standard

pra ctice used to measure each quantity reported in paragraph (a)(1) of this section. (4) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(2) of this section. Harmonizing change with 40 CFR 98.386(a)(1).

LL 98.386(a)(5) (5) For each product (leaving the coal

- to

- liquid facility) listed in Table MM

- 1 of subpart MM of this part, report the annual quantity in metric tons or barrels by each quantity measurement standard method or other industry s tandard practice used. For natural gas liquids, quantity shall reflect the individual components of the product. Those products that enter the facility, but are not reported in (a)(1), shall not be reported under this paragraph. (5) [Reserved.] See preambl e text for explanation

LL 98.386(a)(8) (8) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(5) of this section. (8) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(6) of this section. Harmonizing change with 40 CFR 98.386(a)(5).

LL 98.386(a)(9)( v) (v) The calculated CO 2 emissions factor. (v) The calculated CO 2 emissions factor in metric

tons CO 2 per barrel or per metric ton of product. Clarifies units of reporting requirement

LL 98.386(a)(11) (v) (v) The calculated CO 2 emissions factor. (v) The calculated CO 2 emissions factor in metric

tons CO 2 per barrel or per metric ton of product. Clarifies units of reporting requirement

LL 98.386(a)(13) (13)For each specific type of biomass that enters the
coal

- to

- liquid facility to be co

- processed with fossil
fuel

- based feedstock to produce a product reported in paragraph (a)(6) of this section, report the annual quantity in metric tons or barrels by each quantity measurement standard method or other industry standard practice used. (13) [Reserved.] See preamble text for explanation

LL 98.386(a)(15) (15) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(3) of this section. (15) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(14 ) of this section. Harmonizing change with 40 CFR 98.386(a)(13) and
corrects ref

erence

LL 98.386(a)(18) (18) Annual CO 2 emissions in metric tons that would result from the complete combustion or oxidation of each type of biomass feedstock co

- processed with
fossil fuel

- based feedstocks reported in paragraph (a)(3) of this section, cal culated according to §98.393(c). (18) Annual CO 2 emissions in metric tons that would result from the complete combustion or oxidation of each type of biomass feedstock co

- processed with
fossil fuel

- based feedstocks reported in paragraph (a)(14) of this sec tion, calculated according to §98.393(c). Harmonizing change with 40 CFR 98.386(a)(13) and
corrects reference

### 64

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

LL 98.386(b)(1) (1) For each product listed in Table MM

- 1 of subpart MM of this part, report the annual quantity in metric tons or barrels by each quantity measurement standard method or other industry standard practice used. For natural gas liquids, quantity shall reflect the individual components of the product. 1) [Reserved.] See preamble text for explanation

LL 98.386(b)(4) (4) Each standar d method or other industry standard practice used to measure each quantity reported in paragraph (b)(1) of this section. (4) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (b)(2) of this section

. Harmonizing change with 40 CFR 98.386 (b)(1)

LL 98.386(b)(5)( v) (v) The calculated CO 2 emissions factor in metric

tons. (v) The calculated CO 2 emissions factor in metric

tons CO 2 per barrel or per metric ton of product. Clarifies units of reporting requirement

LL 98.386( c)(1) (1) For each product listed in Table MM

- 1 of subpart MM of this part, report the annual quantity in metric tons or barrels by each quantity measurement standard method or other industry standard practice used. For natural gas liquids, quantity shall reflect the individual components of the product. (1) [Reserved.] See preamble text for explanation

LL 98.386( c)(4) (4) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (c)(1) of this section (4) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (c)(2) of this section Harmonizing change with 40 CFR 98.386 (c)(1)

LL 98.386( c)(5)(v) (v) The calculated CO 2 emission s factor in metric

tons. (v) The calculated CO 2 emissions factor in metric

tons CO 2 per barrel or per metric ton of product. Clarifies units of reporting requirement

LL 98.386(d)(2) (2) For a product that enters the facility to be further
refined or otherwise used on site that is a blended feedstock, producers must meet the reporting requirements of paragraphs (a)(1) and (a)(2) of this section by reflecting the individual components of
the blended feedstock. (2) For a product that enters the facility to be further
refined or otherwise used on site that is a blended feedstock, producers must meet the reporting requirements of paragraph (a)(2) of this section by reflecting the individual components of the blended
feedstock. Harmonizing change with 40 CFR 98.386(a)(1).

LL 98.386(d)(3) (3) For a product that is produced, imported, or exported that is a blended product, producers, importers, and exporters must meet the reporting requirements of paragraphs (a)(5), (a)(6), (b)(1), (b)(2), (c)(1), and (c)(2) of this section, as applicable, by reflecting the individual components of the blended product. (3) For a product that is produced, imported, or exported that is a blended product, producers, importers, and exporters must meet the reporting requirements of paragraphs (a)(6), (b)(2), and (c)(2) of this section, as applicable, by reflecting the individual components of the blended product. Harmonizing change with 40 CFR 98.386(a)(1), (b)(1), and (c )(1)

MM 98.393(a)(1) Product i = Annual volume of product " i" produced, imported, or exported by the reporting party (barrels). For refiners, this volume only includes products ex refinery gate, and excludes products that Product i = Annual volume of product "i" produced, imported, or exported by the reporting party (barrels). For refiners, this volume only includes products ex refinery gate, and excludes products that Updated reference to h armonize with changes to 98.396(a)(1)

### 65

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change entered the refinery but are not r e ported under 98.396(a)(1). For natural gas liquids, volum es shall reflect the individual components of the product as
listed in Table MM

- 1 to subpart MM. entered the refinery but are not r e ported under 98.396(a)(2). For natural gas liquids, volumes shall reflect the individual components of the product as
listed in Table MM

- 1 to subpart MM.

MM 98.393(a)(2) Product i = Annual mass of product "i" produced, imported, or exported by the reporting party (metric tons). For refiners, this mass only includes products ex refinery gate. Product i = Annual mass of product "i" produced, imported, or exported by the reporting party (metric tons). For refiners, this mass only includes products ex refinery gate, and excludes products that entered the refinery but are not reported under §98.396(a)(2). S ee preamble text for explanation

MM 98.393(h)(1) (1) A reporter using Calculation Methodology 1 to determine the emission factor of a petroleum product
shall calculate the CO 2 emissions associated with that product using Equation MM

– 8 of this section in

p lace of Equation MM

– 1 of this section. (1) A report er using Calculation Method 1 to determine the emission factor of a petroleum product
shall calculate the CO 2 emissions associated with that product using Equation MM

– 8 of this section in place of Equation MM

– 1 of this section. Harmonizing change with 98.393(f)(1).

MM 98.393(h)(2) A refinery using Calculation Methodology 1 of this subpart to determine the emission factor of a non

crude petroleum feedstock shall calculate the CO 2 emissions associated with that feedstock using Equation MM

– 9 of this section in place of Equation

MM

– 2 of this section. (2) A refinery using Calculation Method 1 of this subpart to determine the emission factor of a non

crude petroleum feedstock shall calculate the CO 2 emissions associated with that feedstock using Equation MM

– 9 of this section in place of Equation

MM

– 2 of this section. Harmonizing change with 98.393(f)(1).

MM 98.394(a)(1) (1) The quantity of petroleum products, natural gas liquids, and biomass, as well as the quantity of crude oil measured on site at a refinery, shall be
determined as follows: (1) The quantity of petroleum products, natural gas liquids, and bio mass, shall be determined as follows: See preamble text for explanation

MM 98.394(a)(3) (3) The quantity of crude oil not measured on site at a refinery shall be determined according to one of the following methods. You may use an appropriate
standard met hod published by a consensus

- based standards organization or you may use an industry standard practice. (3) The annual quantity of crude oil received shall be determined according to one of the following methods. You may use an appropriate standard
method published by a consensus

- based standards organization or you may use an industry standard practice. See preamble text for explanation

### 66

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

MM 98.394(b) (None) (3) For units and processes that operate continuously with infrequent outages, it may not be possible to complete the calibration of a flow meter or other measurement device without disrupting normal process operation. In such cases, the owner or operator may postpone the calibration until the next scheduled maintenance outage. The best available
informat ion from company records may be used in the interim. Such postponements shall be documented in the monitoring plan that is required under §98.3(g)(5). See preamble text for explanation

MM 98.394(c) (c) Procedures for Calculation Methodology 2 of this subpart. (c) Proced ures for Calculation Method 2 of this subpart. Harmonizing change with 98.393(f)(2).

MM 98.394(d) (d) Measurement of API gravity and sulfur content
of crude oil (4) [Reserved] See preamble text for explanation

MM 98.395(a)

(a) Determination of quantity . Whenever the quality assurance procedures in §98.394(a) cannot be followed to measure the quantity of one or more petroleum products, natural gas liquids, types of biomass, feedstocks, or crude oil batches during any period (e.g. , if a meter malfunctions), the following missing data procedures shall be used: (a) Determination of quantity . Whenever the quality assurance procedures in §98.394(a) cannot be followed to measure the quantity of one or more petroleum products, natural ga s liquids, types of biomass, feedstocks, or crude oil during any period (e.g., if a meter malfunctions), the following missing data procedures shall be used: See preamble text for explanation

MM 98.395(b) (b) Determination of emission factor. Whenever any of the procedures in §98.394(c) cannot be followed to develop an emission factor for any reason, Calculation Methodology 1 of this subpart must be used in place of Calculation Methodology 2 of this subpart for the entire reporting year. (b) Determination of emission factor. Whenever any of the procedures in §98.394(c) cannot be followed to develop an emission factor for any reason, Calculation Method 1 of this subpart must be used in place of Calculation Method 2 of this subpart for the entire reporting ye ar. Clarifies method

MM 98.395(c ) (c) Determination of API gravity and sulfur content
of crude oil . For missing data on sulfur content or (c ) [Reserved] See preamble text for explanation

### 67

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change API gravity, the substitute data value shall be the arithmetic average of the quality

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

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

- assured values for API gravity and sulfur content obtained from the batch after the missing data period.

MM 98.396(a)(1) (1) For each petroleum product or natural gas liquid
listed in table MM

– 1 of this subpart that enters the refinery to be further refined or otherwise used on site, report the annual quantity in metric tons or barrels by each quantity measurement standard method or other industry standard practice used. For natural gas liquids, quantity shall reflect the
indivi dual components of the product. (1) [Reserved] See preamble text for explanation

MM 98.396(a)(4) (4) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(1) of this section. (4) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(2) of this section. Harmonizing change with 40 CFR 98.396(a)(1).

MM 98.396(a)(5) (5) For each petroleum product and natural gas liquid (ex refinery gate) listed in Table MM

– 1 of this subpart, report the annual quantity in metric tons or barrels by each quantity measurement standard method or other industry standard practice used. For natural gas liquids, quantity shall reflect the individual components of t he product. Petroleum products and natural gas liquids that enter the refinery, but are not reported in (a)(1), shall not be reported under this paragraph. (5) [Reserved] See preamble text for explanation

MM 98.396(a)(8) (8) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(5) of this section. (8) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(6) of this section. Harmonizing chan ge with 40 CFR 98.396(a)(5).

MM 98.396(a)(9) (9) For every feedstock reported in paragraph (a)(2)
of this section for which Calculation Method ology 2 of this subpart was used to determine an emissions factor, report: (9) For every feedstock reported in paragraph (a)(2)
of this section for which Calculation Method 2 of this subpart was used to determine an emissions factor, report: Corrects terminology

MM 98.396(a)(9)(i (iii) The carbon share test results in percentmass (iii) The carbon share test results in percent mass Corrects typographical error

### 68

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

ii)

MM 98.396(a)(9)( v) (v) The calculated CO 2 emissions factor in metric

tons. (v) The calculated CO 2 emissions factor in metric

tons CO 2 per barrel or per metric ton of product. Clarifies units of reporting requirement

MM 98.396(a)(10) (10) For every non

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

- solid feedstoc k reported in paragraph (a)(2) of this section f or which Calculation
Method 2 of this subpart was used to determine an emissions factor, report: Clarifies method

MM 98.396(a)(11) (11) For every petroleum product and natural gas liquid reported in paragraph (a)(6) of this section for
which C alculation Method ology 2 of this subpart was used to determine an emissions factor, report: (11) For every petroleum product and natural gas liqu id reported in paragraph (a)(6) of this section for
which C alculation Method 2 of this subpart was used to determine an emissions factor, report: Clarifies method

MM 98.396(11)(iii ) (iii) The carbo n share test results in percent mass. (iii) The carbo n share test results in percent mass. Corrects typo

MM 98.396(a)(13) (13) For each specific type of biomass that enters the refinery to be co

- processed with petroleum feedstocks to produce a petroleum product reported in paragraph (a)(6) of this section, report the annual quantity in metric tons or barrels by each quantity measurement standard method or other industry standard practice used. (13) [Reserved] See preamble text for explanation

MM 98.396(a)(15) (15) Each standard method or other industry stan dard practice used to measure each quantity reported in paragraph (a)(13) of this section. (15) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(14) of this section. Harmonizing change with 40 CFR 98.396(a)(13)

MM 98.396(a)(18) (18) The CO 2 emissions in metric tons that would result from the complete combustion or oxidation of each type of biomass feedstock co

- processed with petroleum feedstocks reported in paragraph (a)(13) of this section, calculated according to §98.393(c). (18) The CO 2 e missions in metric tons that would result from the complete combustion or oxidation of each type of biomass feedstock co

- processed with petroleum feedstocks reported in paragraph (a)(14) of this section, calculated according to §98.393(c). Harmonizing chan ge with 40 CFR 98.396(a)(13)

MM 98.396(a)(20) (20) All of the following information for all crude oil feedstocks used at the refinery: (i) Batch volume in barrels. (ii) Weighted average API gravity representing the batch at the point of entry at the refin ery. (iii) Weighted average sulfur content representing the batch at the point of entry at the refinery. (iv) Country of origin, of the batch, if known and data in paragraphs (a)(20)(v) and (a)(20)(vi) of this
section are unknown. (20) For all crude oi l that enters the refinery, report the annual quantity in barrels. See preamble text for explanation

### 69

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change (v) EIA crude stream code and crude stream name of the batch, if known. (vi) Generic name for the crude stream and the appropriate EIA two

- letter country or state and production area code of the batch, if known and no appropriate EIA crude stream code exists.

MM 98.396(a)(21) (21) The quantity of bulk NGLs in metric tons or barrels received for processing during the reporting

year. (21) The quantity of bulk NGLs in metric tons or barrels received for processing during the reporting year. Report only quantities of bulk NGLs not reported in (a)(2) of this section. See preamble text for explanation

MM 98.396(a)(22) (22) Volume of crud e oil in barrels that you injected into a crude oil supply or reservoir. A volume of crude oil that entered the refinery, but was not reported in paragraphs (a)(2) or (a)(20), shall not be reported under this paragraph. (22) Volume of crude oil in barrels that you injected into a crude oil supply or reservoir. See preamble text for explanation

MM 98.396(a)(23) (23) Special provisions for 2010. For reporting year 2010 only, a refiner that knows the information under a specific tier of the batch definition i n 40 CFR 98.398, but does not have the necessary data collection and management in place to readily report this information, can use the next most appropriate tier of the batch definition for reporting batch information under paragraph 98.396(a)(20). (23) [Reserved] Special provisions for 2010 are no longer necessary.

MM 98.396(b)(1) (1) For each petroleum product and natural gas liquid
listed in Table MM

– 1 of this subpart, report the annual quantity in metric tons or barrels by each quantity measurement standard method or other industry standard practice used. For natural gas liquids, quantity shall reflect the individual components of the product. (1) [Reserved] See preamble text for explanation

MM 98.396(b)(2) (2) For each petroleum product and natural gas liquid
listed in Table MM

– 1 of this subpart, report the annual quantity in metric tons or barrels. For natural gas liquids, quantity shall reflect the individual components of the product as listed in Table MM

– 1 of this subpart. (2) For each petroleum product and natural gas liquid
listed in Table MM

– 1 of this subpart, report the annual quantity in metric tons or barrels. For natural gas liquids, quantity shall reflect the individual components of the product

. Clarifies reporting requirements. Reporti ng is not limited to those components listed in Table MM

- 1.

### 70

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

MM 98.396(b)(4) (4) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (b)(1) of this section. (4) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (b)(2) of this section. Harmonizing change with 40 CFR 98.396 (b)(1)

MM 98.396(b)(5) (5) For each product reported in paragraph (b)(2) of this section for which Calculation Methodology 2 of this subpart used was used to determine an emissions factor, report: (5) For each product reported in paragraph (b)(2) of
this section for which Calculation Method 2 of this subpart used was used to determine an emissions factor, report: Clarifies me thod

MM 98.396(b)(6) (6) For each non

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

- solid product reported in paragraph (b)(2) of this section for whi ch Calculation Method 2 of this subpart was used to determine an emissions factor, report: Clarifies method

MM 98.396( c)(1) (1) For each petroleum product and natural gas liquid
listed in Table MM

– 1 of this subpart, report the annual quantity in metric tons or barrels by each quantity measurement standard method or other industry standard practice used. For natural gas liquids, quantity shall reflect the individual components of the product. (1)[Reserved] See preamble text f or explanation

MM 98.396( c)(4) (4) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (c)(1) of this section. (4) Each standard method or other industry standard practice used to measure each quan tity reported in paragraph (c)(2) of this section. Harmonizing change with 40 CFR 98.396 (c)(1)

MM 98.396(c)(5) (5) For each product reported in paragraph (c)(2) of this section for which Calculation Methodology 2 of this subpart was used to determine an emissions factor, report: (5) For each product reported in paragraph (c)(2) of
this sectio n for which Calculation Method 2 of this subpart was used to determine an emissions factor,
report: Clarifies method

MM 98.396(c)(6) (6) For each non

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

- solid product reported in paragraph (c)(2) of this section f

or which Calculation Metho d 2 of this subpart used was used to determine an emissions factor, report: Clarifies method

MM 98.396(d)(2) (2) For a product that enters the refinery to be further
refined or otherwise used on site that is a blended

non

- crude feedstock, refiners must meet the reporting requirements of paragraphs (a)(1) and (a)(2) of this section by reflecting the individual components of the blended non

- crude feedstock. (2) For a product that enters the refinery to be further
refined or otherwise used on site that is a blended

non

- crude feedstock, refiners must meet the reporting requirements of paragraphs (a)(2) of this section by reflecting the individual components of
the blended non

- crude feedstock. Harmonizing change with 40 CFR 98.396 (a)(1)

MM 98.396(d)(3) (3) F or a product that is produced, imported, or (3) For a product that is produced, imported, or Harmonizing change with 40 CFR 98.396 (a)(1),

### 71

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change exported that is a blended product, refiners, importers, and exporters must meet the reporting requirements of paragraphs (a)(5), (a)(6), (b)(1), (b)(2), (c)(1), and (c)(2) of this section, as applicable, by refl ecting the individual components of the blended product. exported that is a blended product, refiners, importers, and exporters must meet the reporting requirements of paragraphs (a)(6), (b)(2), and (c)(2)

o f this section, as applicable, by reflecting the individual components of the blended product. (b)(1), and (c )(1)

MM 98.397(b) (b) Reporters shall maintain records to support quantities that are reported under this subpart, including records documenting any estimations of missing data and the number of calendar days in the reporting year for which substitute data procedures were followed. For all reported quantities of petroleum products, natural gas liqui ds, and biomass, as well as crude oil quantities measured on site at a refinery, reporters shall maintain metering, gauging, and other records normally maintained in the course of business to document product and feedstock flows including the date of initi al calibration and the frequency of recalibration for the measurement equipment used. (b) Reporters shall maintain records to support quantities that are reported under this subpart, including records documenting any estimations of missing data and the num ber of calendar days in the reporting year for which substitute data procedures were followed. For all reported quantities of petroleum products, natural gas liquids, and biomass, reporters shall maintain metering, gauging, and other records normally maint ained in the course of business to document product and feedstock flows including the date of initial calibration and the frequency of recalibration for the measurement equipment used. Harmonizing change with 40 CFR 98.396(a)(20).

MM 98.397(d) (d) Reporters shall maintain laboratory reports,
calculations and worksheets used in the measurement of density and carbon share for any petroleum product or natural gas liquid for which CO2 emissions were calculated using Calculation Methodology 2. (d) Report ers shall maintain laboratory reports,
calculations and worksheets used in the measurement of density and carbon share for any petroleum product or natural gas liquid for which CO2
emissions were calcula ted using Calculation Method
2. Clarifies method

MM 98.398 (None) Bulk NGLs for purposes of reporting under this subpart means mixtures of NGLs that are sold or delivered as undifferentiated product. See preamble text for explanation

MM 98.398 (None) Natural Gas Liquids (NGLs) for the purposes of reporting under this subpart means hydrocarbons that are separated from natural gas as liquids through the process of absorption, condensation, adsorption, or other methods, and are sold or delivered as
differ entiated product. Generally, such liquids consist of ethane, propane, butanes, or pentanes plus. See preamble text for explanation

### 72

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

MM 98.398 Batch means either a volume of crude oil that enters a refinery or the components of such volume (e.g.,
the volume s of different crude streams that are blended together and then delivered to a refinery). The batch volume is the first appropriate tier in the following list: (1) Up to an annual volume of a type of crude oil identified by an EIA crude stream code, if the EIA
crude stream code is known. (2) Up to an annual volume of a type of crude oil identified by a generic name for the crude stream and an appropriate EIA two

- letter country or state and production area code, if the generic name and EIA

two

- letter code ar e known but no appropriate EIA
crude stream code exists. (3) Up to a calendar month of crude oil volume from a single known foreign country of origin if the crude
stream name is unknown. (4) Up to a calendar month of crude oil volume from
the United States if the crude stream name and production area are unknown. (5) Up to a calendar month of crude oil volume if the country of origin is unknown. (None)

MM Table MM

- 1 Table MM

- 1 See Appendix A for changes to Table MM

- 1 See preamble text for explanation

NN 98.400(a) (a) Natural gas liquids fractionators are installations that fractionate natural gas liquids (NGLs) into their consitutent liquid products (ethane, propane, normal butane, isobutane or pentanes plus) for supply to
downstream facilities. (a) Natur al gas liquids fractionators are installations that fractionate natural gas liquids (NGLs) into their constituent liquid products or mixtures of products (ethane, propane, normal butane, isobutane or pentanes plus) for supply to downstream facilities. Clar ifies rule text.

NN 98.400(b) (b) Local Distribution Companies (LDCs) are companies that own or operate distribution pipelines, not interstate pipelines or intrastate pipelines, that physically deliver natural gas to end users and that are regulated as separate operating companies by State public utility commissions or that operate as independent municipally

- owned distribution
systems. (b) Local Distribution Companies (LDCs) are companies that own or operate distribution pipelines, not interstate pipelin es or intrastate pipelines, that physically deliver natural gas to end users and that are within a single state that are regulated as separate operating companies by State public utility commissions or that operate as independent municipally

- owned distribu tion systems. LDCs do not include pipelines (both interstate and intrastate) delivering natural gas directly to major industrial See preamble text for explanation

### 73

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change users and farm taps upstream of the local distribution company inlet.

NN 98.403(a)(2) Fuel h = Total annual volume of product ―h‖ supplied (bbl or Mscf per year) Fuel h = Total annual volume of product ―h‖ supplied (volume per year, in Mscf for natural gas and bbl for NGLs). Clarifies equation term.

NN 98.403(b) (1) (1) For natural gas that is received for redelivery to downstream gas transmission pipelines and other local distribution companies, use eEquation NN

– 3 of
this section and the default values for the CO 2 emission factors found in Table NN

– 2 of this subpart.*** (1) For natural gas that is received for redelivery to downstream gas transmission pipelines and other local distribution companies, use Equation NN

– 3 of
this section and the default values for the CO2
emission factors found in Table NN

– 2 of this subpart.***. Corrects typographic al error

NN 98.403(b)(2)( i) (2)(i) For natural gas delivered to each meter

registering a supply equal to or greater than 460,000 Mscf per year, use Equation NN

– 4 of this section
and the default values for the CO 2 emission factors
found in Table NN

– 2 of this subpart. (2)(i) For natural gas delivered to end

- users registering a supply equal to or greater than 460,000 Mscf per year, use Equation NN

– 4 of this section
and the default values for the CO 2 emission factors
found in Table NN

– 2 of this subpart. See preamble text for explanation

NN 98.403(b)(2)( ii) CO 2 k = Annual CO 2 mass emissions that would

result from the combustion or oxidation of natural gas received by end

- users that receive a supply equal to or greater than 460,000 Mscf per year (metric tons). CO 2 k = Annual CO 2 mass emissions that would
result from the combust ion or oxidation of natural gas delivered to each end

- user that receive s a supply equal to or greater than 460,000 Mscf per year (metric tons). Clarifies rule text.

NN 98.403(b)(2)( ii) Fuel = Total annual volume of natural gas supplied

(Mscf per year). Fuel = Total annual volume of natural gas supplied
to this end

- user, if known, otherwise, the annual volume supplied to this meter (Mscf per year). Clarifies the definition of the equation term ―Fuel‖ in Equation NN

- 4‖ . The input for the total annual
volu me of natural gas must be the total annual volume of natural gas supplied to the end

- user, if
known.

NN 98.403(b)(3) (3) For natural gas received by the LDC at the city gate that is injected into on

- system storage, and/or liquefied and stored, use Equatio n NN

– 5 of this
section and the default value for the CO 2 emission
factors found in Table NN

– 2 of this subpart. Alternatively, a reporter

- specific CO 2 emission factor may be used, provided it is developed using methods outlined in §98.404.
CO 2 l = [Fuel 1 - Fuel 2 ]*EF (Eq. NN

- 5)
Where:
CO 2 l = Annual CO 2 mass emissions that would result
from the combustion or oxidation of the net natural gas that is liquefied and/or stored and not used for (3) For the net change in natural gas stored on system by the LDC during the reporting year, use Equation NN

- 5a of this section. For natural gas that is received by means other than through the city gate, and is not otherwise accounted for by Equation NN

- 1

or NN

- 2 of this section, use Equation NN

- 5b of this
section. (i) For natural gas received by the LDC that is injected into on

- system storage, and/or liquefied and stored, and for gas removed from storage and used for deliveries, use Equation NN

– 5a of this section
and the default value for the CO 2 emission factors
found in Table NN

– 2 of this subpart. Alternatively, a Harmonize with changes to equations

- see preamble rationale for a complete explanation of the changes.

### 74

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change deliveries by the LDC within the reported year (metric tons).
Fuel1 = T otal annual volume of natural gas received by the LDC at the city gate and stored on

- system or liquefied and stored in the reporting year (Mscf per year).
Fuel 2 = Total annual volume of natural gas that is used for deliveries in the reporting year that was not otherwise accounted for in Equation NN

– 1 or NN

– 2 of this section (Mscf per year). This primarily includes natural gas previously stored on

- system or liquefied and stored that is removed from storage and
used for deliveries to customers or other LDCs b y the LDC within the reporting year. This also includes natural gas that bypassed the city gate and was delivered directly to LDC systems from producers or natural gas processing plants from local production.
EF = Fuel

- specific CO 2 emission factor (MT
CO 2 /Mscf). reporter

- specific CO 2 emission factor may be used, provided it is developed using methods outlined in §98.404.
CO 2 l = [Fuel 1 - Fuel 2 ]*EF (Eq. NN

- 5a)
Where:
CO 2 l = Annual CO 2 mass emissions that would result from the combustion or oxidation of the net change in natural gas stored on system by the LDC within the reporting year (metric tons).
Fuel 1 = Total annual volume of natural gas ad ded to
storage on

- system or liquefied and stored in the reporting year (Mscf per year).
Fuel 2 = Total annual volume of natural gas that is removed from storage or vaporized and removed from storage and used for deliveries to customers or other LDCs by the LDC within the reporting year (Mscf per year). EF = Annual average CO 2 emission factor for natural gas placed into/removed from storage(MT
CO 2 /Mscf).

N N 98.403(b)(3)( ii) (None) (ii)(ii) For natural gas received by the LDC that bypassed the city gate, use Equation NN

- 5b of this section. This includes natural gas received directly by LDC systems from producers or natural gas processing plants from local pr oduction, received as a liquid and vaporized for delivery, or received from any other source that bypassed the city gate. Use the
default value for the CO 2 emission factors found in
Table NN

– 2 of this subpart. Alternatively, a reporter

specific CO 2 emissio n factor may be used, provided it is developed using methods outlined in §98.404.
CO 2 n = Fuel

z * EF

z Where:
CO 2 n = Annual CO 2 mass emissions that would
result from the combustion or oxidation of natural gas received that bypassed the city gate and is not otherwise accounted for by Equation NN

- 1 or NN

- 2 of this section (metric tons).
Fuel

z = Total annual volume of natural gas rec eived Harmonize with changes to equations

- see preamble rationale for a complete description of the changes.

### 75

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change that was not otherwise accounted for by Equation

NN

- 1 or NN

- 2 of this section (natural gas from producers and natural gas processing plants from local production, or natural gas that was received as a liquid, vaporized and delivered, and any other

so urce that bypassed the city gate) (Mscf per year).

EF

z = Fuel

- specific CO 2 emission factor (MT
CO 2 /Mscf).

NN 98.403(b)(4) (4) Calculate the total CO 2 emissions that would result from the complete combustion or oxidation of the annual supply of natural gas to end

- users using Equation NN

– 6 of this section.
CO 2 = Sum( CO 2 i )

- Sum( CO 2 j )

- Sum( CO 2 k )

- Sum( CO 2 l )
Where:
CO 2 = Annual CO 2 mass emissions that would re sult from the combustion or oxidation of natural gas
delivered to LDC customers not covered in paragraph (b)(2) of this section (metric tons).
CO 2 i =Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas
delivered to tr ansmission pipelines or other LDCs as calculated in paragraph (b)(1) of this section (metric tons).
CO 2 j = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas delivered to transmission pipelines or other LDCs as
calc ulated in paragraph (b)(1) of this section (metric tons).
CO 2 k = Annual CO 2 mass emissions that would
result from the combustion or oxidation of natural gas received by end

- users that receive a supply equal to or greater than 460,000 Mscf per year as
calcu lated in paragraph (b)(2) of this section (metric tons).
CO 2 l = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas received by the LDC and liquefied and/or stored but not used for deliveries within the reported year as (4) Calculate the total CO 2 emissions that would result from the complete combustion or oxidation of the annual supply of natural gas to end

- users that receive a supply less than 460,000 Mscf per year using Equation NN

– 6 of this section.
CO 2 = CO 2 i + CO 2 n - CO 2 j - ∑ CO 2 k - CO 2 l (Eq. NN

- 6)
Wh ere CO 2 = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas
delivered to LDC end

- users not covered in paragraph (b)(2) of this section (metric tons).
CO 2 i = Annual CO 2 mass emissions that would result
from the comb ustion or oxidation of natural gas received at the city gate as calculated in paragraph (a)(1) or (a)(2) of this section (metric tons).
CO 2 j = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas
delivered to transmis sion pipelines or other LDCs as calculated in paragraph (b)(1) of this section (metric tons).
CO 2 k = Annual CO 2 mass emissions that would
result from the combustion or oxidation of natural gas delivered to each end

- user that receive s a supply equal to or g reater than 460,000 Mscf per year as calculated in paragraph (b)(2) of this section (metric tons).
CO 2 l = Annual CO 2 mass emissions that would result from the combustion or oxidation of the net change in natural gas stored by the LDC within the reported

ye ar as calculated in paragraph (b)(3)(i) of this section (metric tons). Harmonize with changes to equations

- see preamble rationale for a complete explanation

### 76

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change calculated in paragraph (b)(3) of this section (metric tons). CO 2 n = Annual CO 2 mass emissions that would
result from the combustion or oxidation of natural gas that was received by the LDC directly from sources bypassing the city gate, and is no t otherwise accounted for in Equation NN

- 1 or NN

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

NN 98.403( c)(2) (2) Calculate the total CO 2 equivalent emissions that
would result from the combustion or oxidation of fractionated NGLs supplied less the quantity received by other fractionators using Equation NN

- 8
of this section. (2) Calculate the total CO 2 equivalent emissions that
would result from the combustion or oxidation of fractionated NGLs supplied less the quantity received from other fractionators using Equation

NN

- 8 of this section. Clarifies rule language

NN 98.403( c)(2) CO 2 = Annual CO 2 mass emissions that would result
from the combustion or oxidation of fractionated
NGLs delivered to customers or on behalf of customers (metric tons). CO 2 = Annual CO 2 mass emissions that would result
from the combustion or oxidation of fractionated
NGLs delivered to customers or on behalf of customers less the quantity received from other fractionators (metric tons). Clarifies calculation result

NN 98.404(a)(5) (5) For an LDC using Equation NN

– 1 or NN

– 2 of this subpart, the point(s) of measurement for the natural gas volume supplied shall be the LDC city gate meter(s). (5) For an LDC using Equation NN

– 1 or NN

– 2 of this subpart, the point(s) of measurement for th e natural gas volume received shall be the LDC city gate meter(s). Clarifies rule language

NN 98.404(a)(7) (7) An LDC using Equation NN

– 4 of this subpart shall measure natural gas at the customer meters. The reporter shall consider the volume delivered through a single particluar meter at a single particular
location as the volume delivered to an individual
end

- user. (7) An LDC using Equation NN

– 4 of this subpart shall measure natural gas at the end

- user’s meter(s).

Where an end

- user is known to have mor e than one meter located at their facility, the reporter shall measure the natural gas at each meter and sum the
annual volume delivered to all meters located at the
end

- user’s facility to determine the total volume
delivered to the end

- user. Otherwise, t he reporter
shall consider the total annual volume delivered through each single meter at a single particular
location to be the the volume delivered to an
individual end

- user. Clarifies rule text.

NN 98.404(a)(8) (8) An LDC using Equation NN

– 5 of this s ubpart shall measure natural gas as follows: (i) Fuel 1 shall be measured at the on

- system storage injection meters and/or at the meters measuring natural gas to be liquefied. (8) An LDC using Equation NN

– 5a and/or NN

- 5b of this subpart shall measure natural gas as follows: (i) Fuel 1 shall be measured at the on

- system storage injection meters and/or at the meters measuring natural gas to be liquefied. Harmonize with changes to equations

- see preamble rationale for a complete explanation

### 77

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change (ii) Fuel 2 shall be measured at the meters used for measuring on

- system storage w ithdrawals and/or LNG vaporization injection. If Fuel 2 is from a source other than storage, the appropriate meter shall be used to measure the quantity. (ii) Fuel 2 shall be measured at the meters used for measuring on

- system storage withdrawals and/or LNG vaporization injection. (i ii) Fuel

z shall be measured using established business practices.

NN 98.404(a)(9) (9) An LDC shall measure all natural gas under the following standard industry temperature and pressure conditions: Cubic foot of gas at a temperature of 60 degrees Fahrenheit and at an absolute pressure of fourteen and seventy

- three hundredths (14.73) pounds per square inch. (9) An LDC shall measure all natural gas under the
followi ng standard industry temperature and pressure conditions: Cubic foot of gas at a temperature of 60 degrees Fahrenheit and at an absolute pressure of one atmosphere. Clarified standard conditions for measurements.

NN 98.404(c )(2) (2) When a reporter used the default EF provided in this section to calculate Equation NN

– 2, NN

– 3, NN

– 4, NN

– 5, or NN

– 7 of this subpart, the appropriate
value shall be taken from Table NN

– 2 of this subpart. (2) When a reporter used the default EF provided in
this section to calcula te Equation NN

- 2, NN

- 3, NN

4, NN

- 5a, NN

- 5b, or NN

- 7 of this subpart, the appropriate value shall be taken from Table NN

- 2 of this subpart. Harmonize with changes to equations

- see preamble rationale for a complete explanation

NN 98.404(d)(1) (1) Equipment used to measure quantities in Equations NN

– 1, NN

– 2, and NN

– 5 of this subpart shall be calibrated prior to its first use for reporting under this subpart, using a suitable standard method published by a consensus based standards organization or ac cording to the equipment
manufacturer's directions. (1) Equipment used to measure quantities in Equations NN

– 1, NN

– 2, NN

– 5a and NN

- 5b of this subpart shall be calibrated prior to its first use for reporting under this subpart, using a suitable
standard met hod published by a consensus based standards organization or according to the equipment
manufacturer's directions. Harmonize with changes to equations

- see preamble rationale for a complete explanation

NN 98.404(d)(2) (2) Equipment used to measure quanti ties in Equations NN

– 1, NN

– 2, and NN

– 5 of this subpart shall be recalibrated at the frequency specified by the standard method used or by the manufacturer's
directions. (2) Equipment used to measure quantities in Equations NN

– 1, NN

– 2, NN

– 5a, and NN

- 5b of t his subpart shall be recalibrated at the frequency specified by the standard method used or by the
manufacturer's directions. Harmonize with changes to equations

- see preamble rationale for a complete explanation

NN 98.404(d)(3) [(None)] (3) Equipment used to measure quantities in Equations NN

- 3, and NN

- 4 of this subpart shall be recalibrated at the frequency commonly used within the industry. Clarification of when to calibrate equipment made in case of new reporters

NN 98.404(a)(5) 5) F or an LDC using Equation NN

– 1 or NN

– 2 of this subpart, the point(s) of measurement for the natural gas volume supplied shall be the LDC city gate meter(s). 5) For an LDC using Equation NN

– 1 or NN

– 2 of this subpart, the point(s) of measurement for the natural gas volume received shall be the LDC city gate meter(s). Clarifies rule text.

NN 98.405( c)(3) (3) Whenever a NGL fractionator cannot follow the quality assurance procedures for developing a
reporter

- specific HHV, as specified in §98.404, (3) [Reserved] Deleted duplicate requirement

### 78

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change during any period for any reason, the NGL fractionator shall use the default HHV provided in
Table NN

– 1 of this part for that period.

NN 98.406(a)(4) (4) Annual quantity (in barrels) of y

- grade, bulk
NGLs received from others for fractionation. (4) Annual quantities (in barrels) of y

- grade, o

- grade,
and other bulk NGLs: (i) received. (ii) Supplied to downstream users that are not fractionated by the reporter. See preamble text for explanation

NN 98.406(a)(7) (7) An nual CO 2 mass emissions (metric tons) that
would result from the combustion or oxidation of fractionated NGLs supplied less the quantity received by other fractionators, calculated in accordance with §98.403(c)(2). (7) Annual CO 2 mass emissions (metric ton s) that
would result from the combustion or oxidation of fractionated NGLs supplied less the quantity received from other fractionators, calculated in accordance with §98.403(c)(2). If the calculated value is negative, the reporter shall report the value

a s zero. Corrects regulatory text and resolves potential for negative calculation result due to rounding of
emission factors.

NN 98.406(b)(2) (2) Annual volume in Mscf of natural gas placed into
storage. (2) Annual volume in Mscf of natural gas placed into storage or liquified and stored (Fuel 1 in Equation NN

- 5a). Includes equation terms for clarity

- see preamble
rationale line 147.

NN 98.406(b)(3) (3) Annual volume in Mscf of vaporized liquefied natural gas (LNG) produced at on

- system vaporization facilities for delivery on the distribution system that is not accounted for in paragraph (b)(1)
of this section. (3) Annual volume in Mscf of natural gas withdrawn
from on

- system storage and annual volume in Mscf of vaporized liquefied natural gas (LNG) p roduced at

on

- system vaporization facilities withdrawn from storage for delivery on the distribution system (Fuel 2 in Equation NN

- 5a). Harmonize reporting requirements with calculation changes

- see preamble rationale for a complete explanation

NN 98.406(b)(4) (4) Annual volume in Mscf of natural gas withdrawn
from on

- system storage (that is not delivered to the city gate) for delivery on the distribution system. (4) [Reserved] Reporting of revised definition Fuel 2 in 98.406(b)(3) eliminates the ne ed for this reporting
element.

NN 98.406(b)(5) (5) Annual volume in Mscf of natural gas delivered directly to LDC systems from producers or natural gas processing plants from local production. (5) Annual volume in Mscf of natural gas that bypassed the city gate(s) and was supplied through the LDC distribution system. This includes natural gas from producers and natural gas processing plants from local production, or natural gas that was vaporized upon receipt and delivered, and any other source that byp assed the city gate (Fuelz in Equation

NN

- 5b). Harmonize reporting requirements with calculation changes

- see preamble rationale for a complete explanation

NN 98.406(b)(7) (7) Annual volume in Mscf of natural gas delivered by LDC to each meter registerin g supply equal to or greater than 460,000 Mcsf during the calendar year. (7) Annual volume in Mscf of natural gas delivered by the LDC to each end

- user facility that received from the LDC deliveries equal to or greater than 460,000 Mscf during the calendar year, if known; See preamble text for explanation

### 79

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change otherwise, report the annual volume in Mscf of natural gas delivered by the LDC to each meter registering supply equal to or greater than 460,000 Mscf during the calendar year.

NN 98.406(b)(9) (9) Annual CO 2 emissions (metric tons) that would result from the complete combustion or oxidation of the annual supply of natural gas to end

- users registering less than 460,000 Mcsf, calculated in accordance with §98.403(b)(4). (9) Annual CO 2 emissions (metric tons) that would result from the complete combustion or oxidation of the annual supply of natural gas to end

- users registering less than 460,000 Mscf, calculated in accordance with §98.403(b)(4). If the calculated value is negative, the reporter shall report th e value

as zero. Corrects typographical error , and resolves potential for negative calculation result due to rounding of
emission factors.

NN 98.406(b)(12) (12) The customer name, address, and meter number of each meter reading used to report in paragra ph (b)(7) of this section. (12) The customer name, address, and meter number
of each end

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

- user, or the quantity delivered to a specific meter. Clarifies rule text.

NN 98.407 Introductory Paragraph 98.407 Records that must be retained.

In addition to the information required by §98.3(g), each annual report must contain the following
information: 98.407 Records that must be retained

. In addition to the information required by §98.3(g), the reporter shall retain the following records: Corrects requirement.

NN 98.408

- Table NN

- 1 Table NN

– 1 to Subpart HH of Part 9 8

— Default Factors for Calculation Methodology 1 of This Subpart See Appendix A for changes to Table NN

- 1 Corrects title of table , and harmonizes values with
Table C

- 1

.

NN 98.408

- Table NN

- 2 Table NN

– 2 to Subpart HH of Part 98

— Lookup
Default Values for Calculation Methodology 2 of This Subpart See Appendix A for changes to Table NN

- 2 Corrects title of table , and harmonizes values with
Table C

- 1

.

PP 98.423(a)(3)(i ) (3) To aggregate data, use either Equation PP

– 3a or

PP

– 3b in this paragraph, as appropria te. (i) For facilities with production process units that
capture a CO 2 stream and either measure it after segregation or do not segregate the flow, calculate
the total CO 2 supplied in accordance with Equation

PP

– 3a. (3) To aggregate data, use either Equat ion PP

– 3a or

PP

– 3b in this paragraph, as appropriate. (i) For facilities with production process units or production wells that capture or extract a CO 2 stream and either measure it after segregation or do not segregate the flow, calculate the total CO 2 supplied in accordance with Equation PP

– 3a. See preamble text for explanation

PP 98.426(b)(4)( i) and (ii) (4) Report density as follows:

(i) Quarterly density of CO 2 in metric tons per standard cubic meter if you report the concentration
of the CO 2 stream in paragraph (b)(3) of this section in weight percent. (4) Rep ort density as follows: (i) Quarterly density of the CO 2 stream in metric tons per standard cubic meter if you report the
concentration of the CO 2 stream in paragraph (b)(3) of this section in weight percent. Clarifies reporting requirement

### 80

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change (ii) Quarterly density of the CO 2 stream in metric tons per standard cubic meter if you report the
concentration of the CO 2 stream in paragraph (b)(3) of this section in volume percent. (ii) Quarterly density of CO 2 in metric tons pe r standard cubic meter if you report the concentration
of the CO 2 stream in paragraph (b)(3) of this section in volume percent.

PP 98.426(f)(10) (10) Enhanced oil and natural gas recovery (10) Injection of CO 2 for enhanced oil and natural gas recovery that is covered by subpart UU of this
part. See preamble text for explanation

PP 98.426(f)(11) (11) Long

- term storage (sequestration) (11) Geologic sequestration of carbon dioxide that is covered by subpart RR of this part. See preamble text for explanation

QQ 98.433(a) S t = Mass of fluorinated GHG per unit of equipment type t or foam type t (charge per piece of equipment or cubic foot of foam, kg). S t = Mass of fluorinated GHG per unit of equipment type t or foam type t (charge per piece of equipment, kg) or density of fluorinated GHG in foam (charge per cubic foot of foam, kg per cubic foot). See preamble text for explanation

QQ 98.433(b) S t = Mass in CO 2 e of the fluorinated GHGs per unit of equipment type t or foam ty pe t (charge per piece of equipment or cubic foot of foam, kg). S t = Mass in CO 2 e of the fluorinated GHGs per unit of equipment type t or foam type t (charge per piece of equipment, kg) or density of fluorinated GHG in foam ( CO 2 e per cubic foot of foam, kg CO 2 e per cubic foot). C larifies equation term.

QQ 98.434(b) (b) The inputs to the annual submission must be reviewed against the import or export transaction
records to ensure that the information submitted to EPA is being accurately transcribed as the correct chemical or blend in the correct pre

- charged equipment or closed

- cell foam in the correct quantities (metric tons) and units (kg per piece of equipment or cubic foot of foam). (b) The inputs to the annual submission mu st be reviewed against the import or export transaction
records to ensure that the information submitted to EPA is being accurately transcribed as the correct chemical or blend in the correct pre

- charged equipment or closed

- cell foam in the correct quantit ies and units. Clarifies intent of the requirement.

QQ 98.436(a)(3) (3) For closed

- cell foams that are imported inside of appliances, the identity of the fluorinated GHG contained in the foam in each appliance, the mass of
the fluorinated GHG contained in the foam in each appliance, and the number of appliances imported with each unique combination of mass and identity
of fluorinated GHG within the closed

- cell foams. (3) For closed

- cell foams that are imported inside of equipment , the identity of the fluorinated GHG contained in the foam in each appliance, the mass of
the fluorinated GHG contained in the foam in each piece of equipment , and the number of pieces of equipment imported with each unique combination
of mass and identit y of fluorinated GHG within the
closed

- cell foams. See preamble text for explanation

QQ 98.436(a)(4) (4) For closed cell

- foams that are not imported inside
of appliances , the identity of the fluorinated GHG in the foam, the density of the fluorinated GHG in the foam (kg fluorinated GHG/cubic foot), and the volume of foam imported (cubic feet) for each type (4) For closed cell

- foams that are not imported inside
of equipme nt, the identity of the fluorinated GHG in the foam, the density of the fluorinated GHG in the foam (kg fluorinated GHG/cubic foot), and the volume of foam imported (cubic feet) for each type See preamble text for explanation

### 81

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change

of closed

- cell foam with a unique combination of fluorinated GHG density and identity. of closed

- cell foam with a unique combination of
fluorinated GHG density and identity. QQ 98.436(a)(5) (5) Dates on which the pre

- charged equipment or
closed

- cell foams were imported. (5) [Reserved.] See preamble text for explanation

QQ 98.436(a)(6)(i i) (ii) For closed

- cell foams that are imported inside of

appliances, the mass of the fluorinated GHGs in CO2e contained in the foam in each appliance and the number of appliances imported for each type of appliance. (ii) For closed

- cell foams that are imported inside of equipment, the mass of the fluorinated GHGs in CO2e contained in the foam in each piece of equipment and the number of pieces of equipment imported for each equipment type. See preamble text for explanation

QQ 98.436(a)(6)(i ii) (iii) For closed

- cell foams that are not imported

inside of appliances, the mass in CO2e of the fluorinated GHGs in the foam (kg CO2e/cubic foot) and the volume of foam imported (cubic feet) for each type of closed

- cell foam. (iii) For closed

- cell foams that are not imported inside of equipment, the density in CO2e of the fluorinated GHGs in the foam (kg CO2e/cubic foot) and the volume of foam imported (cubic feet) for each type of closed

- cell foam. See preamble text for explanation

QQ 98.436(a)(6)(i v) (iv) Dates on which the closed

- cell foams were

imported. (iv) [Reserved.] See preamble text for explanation

QQ 98.436(b)(3) ( 3) For closed

- cell foams that are exported inside of appliances, the identity of the fluorinated GHG contained in the foam in each appliance, the mass of
the fluorinated G HG contained in the foam in each appliance, and the number of appliances exported with each unique combination of mass and identity
of fluorinated GHG within the closed

- cell foams. ( 3) For closed

- cell foams that are exported inside of equipment, the identity of the fluorinated GHG contained in the foam in each piece of equipment,
the mass of the fluorinated GHG contained in the foam in each piece of equipment, and the number pieces of equipment exported with each unique
combination of mass and identit y of fluorinated
GHG within the closed

- cell foams. See preamble text for explanation

QQ 98.436(b)(4) (4) For closed

- cell foams that are not exported inside of appliances, the identity of the fluorinated GHG in the foam, the density of the fluorinated GHG in the foam (kg fluorinated GHG/cubic foot), and the volume of foam exported (cubic feet) for each type
of closed

- cell foam with a unique combination of fluorinated GHG density and identity. (4) For closed

- cell foams that are not exported inside of equipme nt, the identity of the fluorinated GHG in the foam, the density of the fluorinated GHG in the foam (kg fluorinated GHG/cubic foot), and the volume of foam exported (cubic feet) for each type
of closed

- cell foam with a unique combination of
fluorinated GHG density and identity. See preamble text for explanation

QQ 98.436(b)(5) (5) Dates on which the pre

- charged equipment or
closed

- cell foams were exported. (5) [Reserved.] See preamble text for explanation

QQ 98.436(b)(6)( ii) (ii) For closed

- cell foams that are exported inside of

appliances, the mass of the fluorinated GHGs in CO2e contained in the foam in each appliance and the number of appliances imported for each type of (ii) For closed

- cell foams that are exported inside of equipment, the mass of the fluorinated GHGs in CO2e contained in the foam in each piece of equipment and the number of pieces of equipment See preamble text for explan ation

### 82

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change appliance. imported for each equipment type. QQ 98.436(b)(6)( iii) (iii) For closed

- cell foams that are not exported

inside of appliances, the mass in CO2e of the fluorinated GHGs in the foam (kg CO2 e/cubic foot) and the volume of foam imported (cubic feet) for each type of closed

- cell foam. ( iii) For closed

- cell foams that are not exported inside of equipment, the density in CO2e of the fluorinated GHGs in the foam (kg CO2 e/cubic foot) and the volume of foam imported (cubic feet) for each type of closed

- cell foam. See preamble text for explan ation

QQ 98.436(b)(6)i v) (6)(iv) Dates on which the closed

- cell foams were

exported. (6)(iv) [Reserved.] See preamble text for explanation

QQ 98.438 Closed

- cell foam means any foam pr oduct, excluding packaging foam that is constructed with a closed

- cell structure and a blowing agent containing a
fluorinated GHG. Closed

- cell foams include but are not limited to polyurethane (PU) appliance foam, PU continuous and discontinuous panel foam, PU one component foam, PU spr ay foam, extruded polystyrene (XPS) boardstock foam, and XPS sheet foam. Packaging foam means foam used exclusively during shipment or storage to temporarily enclose
items. Closed

- cell foam means any foam pro duct, excluding packaging foam that is constructed with a closed

- cell structure and a blowing agent containing a
fluorinated GHG. Closed

- cell foams include but are not limited to polyurethane (PU) foam contained in equipment, PU continuous and discontinuous panel foam, PU one component foam, PU spray foam, extruded polystyrene (XPS) boardstock foam, and XPS sheet foam. Packaging foam means foam used exclusively during shipment or storage to temporarily enclose items. See preamble text for explanation

QQ 98.438 Pre

- charged electrical equipment c omponent means any portion of electrical equipment that is charged
with SF 6 or PFCs prior to sale or distribution or offer
for sale or distribution in interstate commerce. Pre

- charged electrical equipment component means any portion of electrical equipment that is charged with a fluorinated greenhouse gas prior to sale or
distribution or offer for sale or distribution in
interstate commerce. See preamble text for explanation

RR 98.443 (b)(2) S r,p = Quarterly mass of contents in containers r that
is redelivered to another facility without being injected into your well in quarter p (metric tons) S r,p = Quarterly volume of contents in containers r that is redelivered to another facility without being injected into your well in quarter p (standard cubic

m eters) Corrects equation term for consistency of units.

RR 98.443(d)(3) (3) To aggregate production data, you must sum the
mass of all of the CO 2 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 CO 2 measured at the separator(s) represents a percentage of the total CO 2 produced. In order to account for the percentage of CO 2 produced that is estimated to remain with the produced oil or other fluid, you must multiply the quarterly mass of
CO 2 measured at the separator(s) by a percentage estimated using a methodology in yo ur approved (3) To aggre gate production data, you must sum the
mass of all of the CO 2 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 CO 2 measured at the separator(s)
represents a p ercentage of the total CO 2 produced. In order to account for the percentage of CO 2 produced that is estimated to remain with the produced oil or other fluid, you must multiply the quarterly mass of
CO 2 measured at the separator(s) by a percentage
estimated using a methodology in your approved Corrects reference.

### 83

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change MRV plan. If fluids containing CO 2 from injection wells covered under this source category are produced and not processed through a gas

- liquid separator, the concentration of CO 2 in the produced fluids must be measured at a flow meter located p rior to reinjection or reuse using methods in §98.444(f)(1). The considerations you intend to use
to calculate CO 2 from produced fluids for the mass balance equation must be described in your approved MRV plan in accordance with §98.448(d)(5). MRV plan. If fluids containing CO 2 from injection wells covered under this source category are produced and not processed through a gas

- liquid separator, the concentration of CO 2 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 CO 2 from produced fluids for the mass balance equation must be described in your approved MRV plan in accordance with § 98.448(a)(5).

RR 98.443(f)(2) CO 2 FI = Total annual CO 2 mass emitted (metric tons) from equipment leaks and vented emissions of CO 2 from equipment located on the surface between the flow meter used to measure injection quantity and
the injection wellhead. CO 2 FI = Total annual CO 2 mass emitted (metric tons) from equipment leaks and vented emissions of CO 2 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. Harmonizing change to conform the variable
definitions in RR

- 11 and RR

- 12

RR 98.446(b)(5) (5) The standard or method used to calculate each value in paragraphs (b)(1) and (b)(2) of this section. (5) The standard or method used to calculate each value in paragraphs (b)(1), (b)(2), and (b)(3) of this
section. See preamble text for explanation

SS 98.453(d) (d) Estimate the mass of SF 6 or PFCs disbursed to customers in new equipment or cylin ders over the period p by monitoring the mass flow of the SF 6 or PFCs into the new equipment or cylinders using a flowmeter or by weighing containers before and after gas from containers is used to fill equipment or cylinders. (d) Estimate the mass of SF 6 or PFCs disbursed to customers in new equipment or cylinders over the period p by monitoring the mass flow of the SF 6 or PFCs into the new equipment or cylinders using a flowmeter, or by weighing containers before and after gas from containers is used to fill equipment or cylinders, or by using the nameplate capacity of the equipment. See preamble text for explanation

SS 98.453(h) (h) The mass of SF 6 or the PFC disbursed to customers in new equipment over the period p must be determined either by using the nameplate capacity of the equipment or, in cases where equipment is shipped with a partial charge, by calculating the partial shipping charge. Ca lculate the partial shipping charge by multiplying the nameplate capacity of the equipment by the ratio of the densities of the partial charge to the full charge. To determine the equipment's actual nameplate capacity, you must measure the nameplate capaci ties of a representative sample of each make and model (h) If the mass of SF 6 or the PFC disbursed to customers in new equipment or cylinders over the period p is determined by using the nameplate capacity, or by using the nameplate capacity of the equipment and calculating the partial shipping charge, use the methods in either paragraph (h)(1) or (h)(2) of this section. (1) Determine the equipment's actual nameplate capacity, by meas uring the nameplate capacities of a representative sample of each make and model and calculating the mean value for each make and model as specified at §98.454(f); See preamble text for explanation

### 84

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change and take the average for each make and model as specified at §98.454(f). (2) If equipment is shipped with a partial charge, calculate the partial shipping charge by multiplying the nameplate capacity of the equipment by the ratio of the densities of the partial charge to the full charge.

SS 98.453(i) MF = The total annual mass of the SF 6 or PFCs, in pounds, used to fill equipment. MF = The total annual mass of the SF 6 or PFCs, in pounds, used to fill equipment during equipment
installation at electric transmission or distribution
facilities. Clarifies a calculation term.

SS 98.456(m) (m) The values for each hose and valve combina tion and the associated valve fitting sizes and hose
diameters. (m) The values for EF Ci of Equation SS

- 5 of this subpart for each hose and valve combination and the associated valve fitting sizes and hose diameters. Clarifies a reporting requirement.

SS 98.456(o) & (p) (o) The mean value for each make, model, and group

of conditions if the mass of SF 6 or the PFC disbursed to customers in new equipment over the period p is determined by assuming that it is equal to the equipment's nameplate capacity or, in cases where equipment is shipped with a partial charge, equal to its partial shipping charge. (p) The number of samples and the upper and lower bounds on the 95 percent confidence interval for each make, model, and group of conditions if the
mass of SF 6 o r the PFC disbursed to customers in new equipment over the period p is determined by assuming that it is equal to the equipment's nameplate capacity or, in cases where equipment is shipped with a partial charge, equal to its partial shipping charge. (o) If the mass of SF 6 or the PFC disbursed to customers in new equipment over the period p is determined according to the methods required in §98. 45 3 (h) of this subpart, report the mean value of nameplate capacity in pounds for each make, model, and group of co nditions. (p) If the mass of SF 6 or the PFC disbursed to customers in new equipment over the period p is determined according to the methods required in §98. 45 3 (h) of this subpart, report the number of samples and the upper and lower bounds on the 95

perc ent confidence interval for each make, model, and group of conditions. Clarifies a reporting requirement.

TT 98.460(c)(2)( xiii) (xiii) Other waste material that has a DOC value of

0.3 weight percent (on a wet basis) or less. DOC
value must be determined using a 60

- day anaerobic biodegradation test procedure identified in § 98.464(b)(4)(i) (A)

. (xiii) Other waste material that has a DOC value of 0.3 weight percent (on a wet basis) or less. DOC value must be determined using a 60

- day anaerobic biodegradatio n test procedure identified in § 98.464(b)(4)(i) . Corrects cross

- reference to 98.464(b)(4)(i) to indicate that all of the requirements in subparagraph (A) through (E) are applicable.

TT 98.463(a)(1) DOC F = Fraction of DOC dissimilated (fraction); use
the default value of 0.5. DOC F = Fraction of DOC dissimilated (fraction); use
the default value of 0.5. If measured values of DOC are available using the 60

- day anaerobic biodegradation test procedure identified in See preamble text for explanation

### 85

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change 98.464(b)(4)(i), use a default value of 1.0 .

TT 98.463(a)(1) Eq. TT

- 1 F

x = Fraction by volume of CH 4 in landfill gas

(fraction, dry basis, corrected to 0% oxygen). If you have a gas collection system, use the annual average
CH 4 concentration from measurement data fo r the current reporting year; otherwise, use the default
value of 0.5. F = Fraction by volume of CH 4 in landfill gas (fraction, dry basis, corrected to 0% oxygen). If you have a gas collection system, use the annual average
CH 4 concentration from measurement data for the current reporting year; otherwise, use the default
value of 0.5. Corrects an equation term. This term correspon d s to a factor for the current reporting year, and should not have a subscript indicating that it is a variable that changes with each disposal year.

TT 98.463(a)(2)(i i)(C ) Eq. TT

- 4b Corrects a typographical error in Equation TT

- 4b.
The summation should start with "n=1" rather than

"n

- 1"

TT 98.463(b)(1) Eq. TT

- 6 OX = Oxidation fraction. Use the default value of 0.1

(10 percent). OX = Oxidation fraction from Table HH

- 4 of subpart HH of this part. See preamble text for explanation

TT 98.464(b) (b) For each waste stream placed in the landfill during the reporting year for which you choose to
determine volatile solids concentration for the purposes of § 98.460(c)(2)(xii) or choose to
determine a landfill

- specific DOC X for use in Equation TT

- 1 of this subpart or for the purposes of § 98.460(c)(2)(xiii) 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. (b) For each waste stream placed in the landfill during the reporting year for which you choose to
determine volatile solids conce ntration and/or a

waste stream

- specific DOC X , 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, as applicable. See preamble text for explanation

TT 98.464(b)(4)( i)(E) Eq. TT

- 7

Wh ere:

DOC X = Degradable organic content of the waste stream in Year X (weight fraction, wet basis)
DOC F = Fraction of DOC dissimilated (fraction); use the default
value of 0.5. MCDsample,x= Mass of carbon degraded in the w aste stream sample in Year X as determined in paragraph (b)(4)(i)(C) of this Where:
DOC X = Degradable organic content of the waste

stream in Year X (weight fraction, wet basis)
MCD sample,x = Mass of carbon degraded in the waste stream sample in Year X as determined in paragraph (b)(4)(i)(C) of this section [milligrams (mg)].

M sample,x = Mass of waste stream sample used in the anaerobic degrad ation test in Year X (mg, wet basis). See preamble text for explanation

### 86

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change section [milligrams (mg)].

M sample,x = Mass of waste stream sample used in the anaerobic degradation test in Year X (mg, wet basis).
MCD control = Mass of carbon degraded in the cont rol sample as determined in paragraph (b)(4)(i)(B) of this section (mg).
MC control = Mass of carbon added to the control sample via the substrate material in the anaerobic degradation (mg).

TT 98.464(c) (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. (c) For each waste stream that was historically managed in the landfill but was not received during the first reporting year for which you choose to
determine volatile solids concentration and/or a

waste stream

- specific DOC X , you must dete rmine
volatile solids concentration or DOC X 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. See preamble text for explanation

TT 98.464(c)(1) (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 similar waste stream using the procedures in paragraphs (b)(1) through (b)(3) of this
section. (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 or DOC X of the similar waste stream using the applicable procedures in paragraphs (b)(1) through (b)(4) of this section. See preamble text for explanation

TT 98.464(c)(2) (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. (2) If yo u cannot identify a similar waste stream to the waste stream that was historically managed in the landfill, you may determine the volatile solids
concentration or DOC X of the historically managed waste stream using process knowledge. You must
document the basis for the volatile solids
concentration or DOC X value as determined through process knowledge. See preamble text for explanation

TT 98.466(b)(1) (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 CH 4 generation. (1) The number of waste steams (including ―Other Industrial Solid Waste (n ot otherwise listed)‖ and ―Inerts ‖) for which Equation TT

– 1 of this subpart is
used to calculate modeled CH 4 generation. See preamble text for explanation

TT 98.466(b)(5) (None) (5) For each waste stream, the decay rate (k) value
used in the calculations. See preamble text for explanation

TT 98.466(c ) (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. (c) Report the followi ng historical waste
information : (1) [Reserved] See preamble text for explanation

### 87

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change (2) The method(s) for estimating historical wast e 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 f actor (WDF)
calculated for the waste stream. (2) For each waste stream identified in paragraph (b) of this section, the method(s) for estimating historical waste disposal quantities and the range of years for which each method applies. (3) For each waste stream identified in paragraph (b) of this section for which Equation TT

- 2 of this subpart is used, provide: (i) The total number of years (N) for which disposal and production data are b oth 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 was te stream.

TT 98.466(c)(4) (4) If Equation TT

- 4 of this subpart is used, provide: (i) The value of landfill capacity (LFC). (ii) YrData. (iii) YrOpen. (4) If Equation TT

– 4a of this subpart is used, provide: (i) The value of landfill capacity (LFC). (ii) YrData. (iii) YrOpen. See preamble text for explanation

TT 98.466(c)(5) (None) (5) If Equation TT

- 4b of this subpart is used, provide: (i) WIP (i.e., the quantity of waste in

- place at the start of the reporting year from design drawings or engineering estimates (metric tons) or, for closed
landfills for which waste in

- place quantities are not available, the landfill's design capacity); (ii) The cumulative quantity of waste placed in the landfill for the years for which di sposal quantities are available from company record or from Equation

TT

- 3 of this part; (iii) YrLast; (iv) YrOpen; and (v) NYrData. See preamble text for explanation

TT 98.466(d)(3) (3) The degradable organic carbon (DOC X ) value (mass fraction) for the specified year and an
indication as to whether this was the default value
from Table TT

- 1 to this subpart, a measured value (3) For each waste stream, the degradable organic carbon (DOC X ) value (mass fraction) for the specified year and an indication as to whether this
was the default value from Table TT

– 1 to this See preamble text for explanation

### 88

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change using a 60

- day anaerobic biodegradation test as specified in §98.464(b)(4)(i), or a value based on total and volatile solids measurements as specified in §98.464(b)(4)(ii). If DOC X was determined by a 60

- day anaerobic biodegradation test, specify the test
method used. subpart, a measured value using a 60

- day anaerobic biodegradation test as specified in §98.464(b)(4)(i),
or a value based on total and volatile solids measurements as specified in §98.464(b)(4)(ii). If
DOC X was determined by a 60

- day anaerobic biodegradation test, specify the test method used.

TT 98.466(h) (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). (h) For landfills with gas collection systems, in addition to the reporting requirements in paragraphs (a) through (f) of this section, provide: (1) The annual methane generation, adjusted for oxidation, calculated using Equation TT

- 6 of this subpart, rep orted in metric tons CH 4 ; (2) The oxidation factor used in Equation TT

- 6 of this subpart; and (3) All information required under 40 CFR 98.346(i)(1) through (i)(7) and 40 CFR 98.346(i)(9) through (i)(12). See preamble text for explanation

TT 98.467 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 measurement data used for the purposes of paragraph § 98.460(c)(2)(xii) or used to determine
landfill

- specific DOC X values. 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 measurement data used for the purposes of paragraphs §98.460(c)(2)(xii) or (c)(2)(xiii) or used
to determine waste stream

- specific DOC X values for use in Equation TT

- 1 of this subpart. See preamble text for explanation

TT Table TT

- 1 T able TT

- 1 See Appendix A for changes to Table TT

- 1 See preamble text for explanation

UU 98.473(a)(2) D= Density of CO 2 at standard conditions (metric tons per standard cubic meter): 0.0018704 D= Density of CO 2 at standard conditions (metric tons per standard cubic meter): 0.0018682 Harmonizing change to conform with the density values used in 98.473(b)(2).

UU 98.473(b)(2) S r,p = Quarterly mass of contents in containers r that is redelivered to another facility without being injected into your well in quarter p (standard cubic meters) S r,p = Quarterly volume of contents in containers r that is redelivered to another facility without being injected into your well in quarter p (standard cubic meters) Corrects equation term for consistency of units.

UU 98.476(b)(5) (5) The standard or method used to calculate each value in paragraphs (b)(1) and (b)(2) of this section. (5) The standard or method used to calculate each value in paragraphs (b)(1), (b)(2), and (b)( 3) of this
section. See preamble text for explanation

UU 98.476(e) (None) (e) Report the following: (1) Whether the facility received a Research and Development project exemption from reporting See preamble text for explanation

### 89

Subpart Requirement Current Rule Text Proposed Rule Text Rationale for Change under 40 CFR Part 98 subpart RR for this reporting year. If you received an exemption, report the start and end dates of the exemption approved by EPA; (2) Whether the facility includes a well or group of
wells where a CO 2 stream was injected into subsurface geologic formations to enhance the recovery of oil during this reporting year; (3) Whether the facility includes a well or group of
wells where a CO 2 stream was injected into subsurface geologic formations to enhance the recovery of natural gas during this reporting year; (4) Whether the facility includes a well or group of
wells where a CO 2 stream was injected into subsurface geologic formations for acid gas disposal during this reporting year; (5) Whether the facility includes a well or group of
wells where a CO 2 stream was injected for a purpose other than those listed in (e)(1)through (4) of this section. If you injected CO 2 for another purpose, report the purpose of the injection.

# Attachment A

1. Proposed Amendments to Table A

– 1 to Subpart A of Part 98

— Global Warming
Potentials [100

- Year Time Horizon]

Table A

– 1 to Subpart A of Part 98

— Global Warming Potentials

[100

- Year Time Horizon]

Name CAS No. Chemical formula Global warming potential (100 yr.)

Carbon dioxide 124

– 38

– 9 CO 2 

### 1

Methane 74

– 82

– 8 CH 4 

### 21 25 a



### Nitrous oxide 10024

– 97

– 2 N 2 

### O 310 298 a



### HFC

– 23 75

– 46

– 7 CHF 3 

### 11,700 14,800 a



### HFC

– 32 75

– 10

– 5 CH 2 

### F 2 

### 650 675 a



### HFC

– 41 593

– 53

– 3 CH 3 

### F 150 92 a



### HFC

– 125 354

– 33

– 6 C 2 

### HF 5 

### 2,800 3,500 a



### HFC

– 134 359

– 35

– 3 C 2 

### H 2 

### F 4 

### 1, 000 100 a



### HFC

– 134a 811

– 97

– 2 CH 2 

### FCF 3 

### 1, 300 430 a



### HFC

– 143 430

– 66

– 0 C 2 

### H 3 

### F 3 

### 300 353 a



### HFC

– 143a 420

– 46

– 2 C 2 

### H 3 

### F 3 

### 3,800 4,470 a



### HFC

– 152 624

– 72

– 6 CH 2 

### FCH 2 

### F 53

HFC

– 152a 75

– 37

– 6 CH 3 

### CHF 2 

### 140 124 a



### HFC

– 161 353

– 36

– 6 CH 3 

### CH 2 

### F 12

HFC

– 227ea 431

– 89

– 0 C 3 

### HF 7 

### 2,900 3,220 a



### HFC

– 236cb 677

– 56

– 5 CH 2 

### FCF 2 

### CF 3 

### 1,340

HFC

– 236ea 431

– 63

– 0 CHF 2 

### CHFCF 3 

### 1,370

HFC

– 236fa 690

– 39

– 1 C 3 

### H 2 

### F 6 

### 9,810 6,300 a



### HFC

– 245ca 679

– 86

– 7 C 3 

### H 3 

### F 5 

### 693 560 a



### HFC

– 245fa 460

– 73

– 1 CHF 2 

### CH 2 

### CF 3 

### 1,030

HFC

– 365mfc 406

– 58

– 6 CH 3 

### CF 2 

### CH 2 

### CF 3 

### 794

### Name CAS No. Chemical formula Global warming potential (100 yr.)

HFC

– 43

– 10mee 138495

– 42

– 8 CF 3 

### CFHCFHCF 2 

### CF 3 

### 1, 300 640 a



### Sulfur hexafluoride 2551

– 62

– 4 SF 6 

### 23,900 22,800 a



### Trifluoromethyl sulphur pentafluoride 373

– 80

– 8 SF 5 

### CF 3 

### 17,700

Nitrogen trifluoride 7783

– 54

– 2 NF 3 

### 17,200

PFC

– 14 (Perfluoromethane) 75

– 73

– 0 CF 4 

### 6,500 7,390 a



### PFC

– 116 (Perfluoroethane) 76

– 16

– 4 C 2 

### F 6 

### 9,200 12,200 a



### PFC

– 218 (Perfluoropropane) 76

– 19

– 7 C 3 

### F 8 

### 7,000 8,830 a



### Perfluorocyclopropane 931

– 91

– 9 C

- C 3 

### F 6 

### 17,340

PFC

– 3

– 1

– 10 (Perfluorobutane) 355

– 25

– 9 C 4 

### F 10 

### 7,000 8,860 a



### Perfluorocyclobutane 115

– 25

– 3 C

- C 4 

### F 8 

### 8,700 10,300 a



### PFC

– 4

– 1

– 12 (Perfluoropentane) 678

– 26

– 2 C 5 

### F 12 

### 7,500 9,160 a



### PFC

– 5

– 1

– 14 (Perfluorohexane) 355

– 42

– 0 C 6 

### F 14 

### 7,400 9,300 a



### PFC

– 9

– 1

– 18 306

– 94

– 5 C 10 

### F 18 

### 7,500

HCFE

– 235da2 (Isoflurane) 26675

– 46

– 7 CHF 2 

### OCHClCF 3 

### 350

HFE

– 43

– 10pccc (H

– Galden 1040x) E1730133 CHF 2 

### OCF 2 

### OC 2 

### F 4 

### OC

HF 2 

### 1,870

HFE

– 125 3822

– 68

– 2 CHF 2 

### OCF 3 

### 14,900

HFE

– 134 1691

– 17

– 4 CHF 2 

### OCHF 2 

### 6,320

HFE

– 143a 421

– 14

– 7 CH 3 

### OCF 3 

### 756

HFE

– 227ea 2356

– 62

– 9 CF 3 

### CHFOCF 3 

### 1,540

HFE

– 236ca12 (HG

– 10) 78522

– 47

– 1 CHF 2 

### OCF 2 

### OCHF 2 

### 2,800

HFE

– 236ea2 (Desflurane) 57041

– 67

– 5 CHF 2 

### OCHFCF 3 

### 989

HFE

– 236fa 20193

– 67

– 3 CF 3 

### CH 2 

### OCF 3 

### 487

HFE

– 245cb2 22410

– 44

– 2 CH 3 

### OCF 2 

### CF 3 

### 708

HFE

– 245fa1 84011

– 15

– 4 CHF 2 

### CH 2 

### OCF 3 

### 286

HFE

– 245fa2 1885

– 48

– 9 CHF 2 

### OCH 2 

### CF 3 

### 659

HFE

– 254cb2 425

– 88

– 7 CH 3 

### OCF 2 

### CHF 2 

### 359

### Name CAS No. Chemical formula Global warming potential (100 yr.)

HFE

– 263fb2 460

– 43

– 5 CF 3 

### CH 2 

### OCH 3 

### 11

HFE

- 329mcc2 67490

- 36

- 2 CF 3 

### CF 2 

### OCF 2 

### CHF 2 

### 919

HFE

– 338mcf2 156053

– 88

– 2 CF 3 

### CF 2 

### OCH 2 

### CF 3 

### 552

HFE

– 338pcc13 (HG

– 01) 188690

– 78

– 0 CHF 2 

### OCF 2 

### CF 2 

### OCHF 2 

### 1,500

HFE

– 347mcc3 28523

– 86

– 6 CH 3 

### OCF 2 

### CF 2 

### CF 3 

### 575

HFE

– 347mcf2 E1730135 CF 3 

### CF 2 

### OCH 2 

### CHF 2 

### 374

HFE

– 347pcf2 406

– 78

– 0 CHF 2 

### CF 2 

### OCH 2 

### CF 3 

### 580

HFE

– 356mec3 382

– 34

– 3 CH 3 

### OCF 2 

### CHFCF 3 

### 101

HFE

– 356pcc3 160620

– 20

– 2 CH 3 

### OCF 2 

### CF 2 

### CHF 2 

### 110

HFE

– 356pcf2 E1730137 CHF 2 

### CH 2 

### OCF 2 

### CHF 2 

### 265

HFE

– 356pcf3 35042

– 99

– 0 CHF 2 

### OCH 2 

### CF 2 

### CHF 2 

### 502

HFE

– 365mcf3 378

– 16

– 5 CF 3 

### CF 2 

### CH 2 

### OCH 3 

### 11

HFE

– 374pc2 512

– 51

– 6 CH 3 

### CH 2 

### OCF 2 

### CHF 2 

### 557

HFE

– 449s 1 l (HFE

– 7100)
Chemical blend 163702

– 07

– 6
163702

– 08

– 7 C 4 

### F 9 

### OCH 3



### (CF 3 

### ) 2 

### CFCF 2 

### OCH 3 

### 297

HFE

– 569sf2 (HFE

– 7200)
Chemical blend 163702

– 05

– 4
163702

– 06

– 5 C 4 

### F 9 

### OC 2 

### H 5



### (CF 3 

### ) 2 

### CFCF 2 

### OC 2 

### H 5 

### 59

Sevoflurane 28523

– 86

– 6 CH 2 

### FOCH(CF 3 

### ) 2 

### 345

HFE

– 356mm1 13171

– 18

– 1 (CF 3 

### ) 2 

### CHOCH 3 

### 27

HFE

– 338mmz1 26103

– 08

– 2 CHF 2 

### OCH(CF 3 

### ) 2 

### 380

(Octafluorotetramethy

lene)hydroxymethyl group NA X

- (CF 2 

### ) 4 

### CH(OH)

- X 73

HFE

– 347mmy1 22052

– 84

– 2 CH 3 

### OCF(CF 3 

### ) 2 

### 343

Bis(trifluoromethyl)

- methanol 920

– 66

– 1 (CF 3 

### ) 2 

### CHOH 195

2,2,3,3,3

- pentafluoropropanol 422

– 05

– 9 CF 3 

### CF 2 

### CH 2 

### OH 42

PFPMIE NA CF 3 

### OCF(CF 3 

### )CF 2 

### OCF

2 

### OCF 3 

### 10,300

HFC

- 1234ze b 

### 29118

- 24

- 9 C 3 

### H 2 

### F 4 

### 6

hexafluoropropylene (HFP) b 

### 116

- 15

- 4 C 3 

### F 6 

### 0.25

### Name CAS No. Chemical formula Global warming potential (100 yr.)

perfluoromethyl vinyl ether (PMVE) b 

### 1187

- 93

- 5 CF(CF 3 

### )OCF 3 

### 3

tetrafluoroethylene (TFE) b 

### 116

- 14

- 3 C 2 

### F 4 

### 0.02

trifluoro propene (TFP) b 

### 677

- 21

- 4 C 3 

### H 3 

### F 3 

### 3

vinyl fluoride (VF) b 

### 75

- 02

- 5 C 2 

### H 3 

### F 0.7

vinylidiene fluoride (VF2) b 

### 75

- 38

- 7 C 2 

### H 2 

### F 2 

### 0.9

carbonyl fluoride b 

### 353

- 50

- 4 COF 2 

### 2

perfluoropropyl vinyl ether b 

### 1623

- 05

- 8 C 5 

### F 10 

### O 3

perfluoroethyl vinyl ether b 

### 10493

- 43

- 3 C 4 

### F 8 

### O 3

HFC

- 1234yf b 

### 754

- 12

- 1 C 3 

### H 2 

### F 4 

### 4

perfluorethyl iodide (2

- I) b 

### 354

- 64

- 3 C 2 

### F 5 

### I 3

perfluorbutyl iodide (PFBI, 42

- I) b 

### 423

- 39

- 2 C 4 

### F 9 

### I 3

perfluorhexyl iodide (6

- I) b 

### 355

- 43

- 1 CF 3 

### CF 2 

### CF 2 

### CF 2 

### CF 2 

### CF 2 

### I
C 6 

### F 13 

### I 2

perfluoroctyl iodide (8

- I) b 

### 507

- 63

- 1 C 8 

### F 17 

### I 2



### 1,1,1,2,2

- pentafluoro

- 4

- iodo butane (22

- I) b 

### 40723

- 80

- 6 C 4 

### H 4 

### F 5 

### I 2

1,1,1,2,2,3,3,4,4

- nonafluoro

- 6

- iodo hexane (42

- I) b 

### 2043

- 55

- 2 C 6 

### H 4 

### F 9 

### I 2

perfluorobutyl ethene (42

- U) b 

### 19430

- 93

- 4 C 6 

### H 3 

### F 9 

### 2

perfluorohexyl ethene (62

- U) b 

### 25291

- 17

- 2 C 8 

### H 3 

### F 13 

### 1

perfluorooctyl ethene (82

- U) b 

### 21652

- 58

- 4 C 10 

### H 3 

### F 17 

### 1

1H,1H, 2H,2H

- perfluorohexan

- 1

- ol (42

- AL) b 

### 2043

- 47

- 2 C 6 

### H 5 

### F 9 

### O 5

FK

- 5

- 1

- 12 Perfluoroketone; FK

- 5

- 1

- 12myy2; n

- Perfluorooctane;
Octanedecafluorooctane b 

### 756

- 13

- 8 CF 3 

### CF 2 

### C(O)CF (CF 3 

### ) 2 

### 1.8

C7 Fluoroketone, Novec 774/ FK

- 6

- 1

- 12 813

- 44

- 5 and
813

- 45

- 6 C 7 

### F 14 

### O Chemical Blend 1

trans

- 1

- chloro

- 3,3,3

- trifluoroprop

- 1

- ene
b 

### 2730

- 43

- 0 C 3 

### H 2 

### ClF 3 

### 7

Hexadecofluoroheptane b


### (PFC

- 6

- 1

- 12) 335

- 57

- 9 C 7 

### F 16 

### 7930

### Name CAS No. Chemical formula Global warming potential (100 yr.)

octadecafluorooctane b


### (PFC

- 7

- 1

- 18) 307

- 34

- 6 C 8 

### F 18 

### 8340

a 

### The GWP for this compound is different than the GWP in the version of Table A

- 1 to subpart A of part 98 published on October 30, 2009.

b 

### The GWP for this compound was not provided in the version of Table A

- 1 to subpart A of part 98 published on October 30, 2009.

NA

– Not available

3 . Proposed Amendments to Table A

- 6 to 40 CFR part 98, subpart A:

Table A

– 6 to Subpart A of Part 98

— Data Elements That Are Inputs to Emission Equations and for Which the Reporting Deadline Is March 31, 2013

Subpart Rule citation

(40 CFR part 98) Specific data elements for which reporting date is March 31, 2013 (―All‖ means all data elements in the cited paragraph are not required to be reported until March 31, 2013)

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)(iv)(G) All.

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)(x)(A) All.

C 98.36(e)(2)(xi) All.

DD 98.306(a)(2) All.

DD 98.306(a)(3) All.

DD 98.306(d) All.

DD 98.306(e) All.

DD 98.306(f) All.

### Subpart Rule citation (40 CFR part 98) Specific data elements for which reporting date is March 31, 2013 (―All‖ means all data elements in the cited paragraph are not required to be reported until March 31, 2013)

DD 98.306(g) All.

DD 98.306(h) All.

DD 98.306(i) All.

DD 98.306(j) All.

DD 98.306(k) All.

DD 98.306(l) All.

FF 98.326(a) All.

FF 98.326(b) All.

FF 98.326(c) All.

FF 98.326(f) Only quarterly volumetric flow rate.

FF 98.326(g) Only quarterly CH 4 

### concentration.

FF 98.326(h) Only weekly volumetric flow used to

calculate CH 4 

### liberated from degasification systems.

FF 98.326(j) All.

FF 98.326(k) All.

FF 98.326(o) All.

FF 98.326(p) Only assumed destruction efficiency for the primary destruction device

and assumed destruction efficiency for the backup destruction device.

HH 98.346(a) Only year in which landfill first accepted waste, last year the landfill accepted waste (if used as an input in Equation HH

– 3), capacity of the landfill (if used as an input in Equatio n HH

– 3), 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

### Subpart Rule citation (40 CFR part 98) Specific data elements for which reporting date is March 31, 2013 (―All‖ means all data elements in the cited paragraph are not required to be reported until March 31, 2013)

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.

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 CH 4 

### in landfill gas and methane correction factor (MCF)

values

.

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 surfa ce 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 CH 4 

### generation value.

II 98.356(b)(1) All.

II 98.356(b)(2) All.

II 98.356(b)(3) All.

### Subpart Rule citation (40 CFR part 98) Specific data elements for which reporting date is March 31, 2013 (―All‖ means all data elements in the cited paragraph are not required to be reported until March 31, 2013)

II 98.356(b)(4) All.

II 98.356(b)(5) All.

II 98.356(d)(1) All.

II 98.356(d)(7) All.

II 98.356(d)(8) Only annual operating hours for the primary destruction device, annual operating hours for the backup destruction device, destruction efficiency of the primary destruction device, and destruction efficiency of the backup destruction device.

SS 98.456(a) All.

SS 98.456(b) All.

SS 98.456(c) All.

SS 98.456(d) All.

SS 98.456(e) All.

SS 98.456(f) All.

SS 98.456(g) All.

SS 98.456(h) All.

SS 98.456(i) All.

SS 98.456(j) All.

SS 98.456(m) All.

SS 98.456(n) All.

SS 98.456(o) All.

SS 98.456(q) All.

SS 98.456(r) All.

SS 98.456(s) All.

SS 98.456(t) Only for any missing data the substitute parameters used to

### Subpart Rule citation (40 CFR part 98) Specific data elements for which reporting date is March 31, 2013 (―All‖ means all data elements in the cited paragraph are not required to be reported until March 31, 2013)

estimate emissions in their absence.

TT 98.466(a)(2) All.

TT 98.466(a)(3) Only last year the landfill accepted waste (for closed landfills using Equation TT

– 4).

TT 98.466(a)(4) Only capacity of the landfill in metric tons (for closed landfills using Equation TT

– 4).

TT 98.466(c)(1) All.

TT 98.466(c)(4)(i) All.

TT 98.466(c)(4)(ii) All.

TT 98.466(c)(4)(iii) All.

TT 98.466(d)(1) All.

TT 98.466(d)(2) Only degradable organic carbon (DOC X 

### )

value used in calculations.

TT 98.466(d)(3) Only fraction of CH 4 

### in landfill gas.

TT 98.466(e)(2) Only 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 (for facilities using a landfill gas collection system).

TT 98.466(f) All.

### 4. Propose d Amendments to Table C

- 1 to 40 CFR part 98, subpart C :

Table C

– 1 to Subpart C

— Default CO&ihel2 CO 2 

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

Fuel type Default high heat value Default CO 2 

### emission factor

Coal and coke mmBtu/short ton kg CO 2 

### /mmBtu

Anthracite 25.09 103. 54 69

Waste Anthracite (Culm) See footnote 1 103.69

Bituminous 24.93 93. 40 28

Waste Bituminous (Gob) See footnote 1 93.28

Subbituminous 17.25 97. 02 17

Lignite 14.21 96.36 97.72

Coal Coke 24.80 102.04 113.67

Mixed (Commercial sector) 21.39 95.26 94.27

Mixed (Industrial coking) 26.28 93. 65 90

Mixed (Industrial sector) 22.35 93.91 94.67

Mixed (Electric Power sector) 19.73 94.38 95.52

Natural gas mmBtu/scf kg CO 2 

### /mmBtu

(Weighted U.S. Average) 1. 028 026 × 10 −3 

### 53.0 2 6

Petroleum products mmBtu/gallon kg CO 2 

### /mmBtu

Distillate Fuel Oil No. 1 0.139 73.25

Distillate Fuel Oil No. 2 0.138 73.96

Distillate Fuel Oil No. 4 0.146 75.04

Residual Fuel Oil No. 5 0.140 72.93

Residual Fuel Oil No. 6 0.150 75.10

Used Oil 0. 135 138 74.00

Kerosene 0.135 75.20

Liquefied petroleum gases (LPG) 2 

### 0.092 62.98 61.71

Propane 2 

### 0.091 61.46 62.87

Propylene 2 

### 0.091 65.95 67.77

Ethane 2 

### 0. 069 068 62.64 59.60

### Fuel type Default high heat value Default CO 2 

### emission factor

Ethanol 0.084 68.44

Ethylene 3 

### 0. 100 058 67.43 65.96

Isobutane 2 

### 0. 097 099 64.91 64.94

Isobutylene 2 

### 0.103 67.74 68.86

Butane 2 

### 0. 101 103 65.15 64.77

Butylene 2 

### 0. 103 105 67.73 68.72

Naphtha (<401 deg F) 0.125 68.02

Natural Gasoline 0.110 66.8 8 3

Other Oil (>401 deg F) 0.139 76.22

Pentanes Plus 0.110 70.02

Petrochemical Feedstocks 0. 129 125 70.97 71.02

Petroleum Coke 0.143 102.41

Special Naphtha 0.125 72.34

Unfinished Oils 0.139 74. 49 54

Heavy Gas Oils 0.148 74.92

Lubricants 0.144 74.27

Motor Gasoline 0.125 70.22

Aviation Gasoline 0.120 69.25

Kerosene

- Type Jet Fuel 0.135 72.22

Asphalt and Road Oil 0.158 75.36

Crude Oil 0.138 74. 49 54

Other fuels

- solid mmBtu/short ton kg CO 2 

### /mmBtu

Municipal Solid Waste 9.95 4 

### 90.7

Tires 26.87 28.00 85.97

Plastics 38.00 75.00

Petroleum Coke 30.00 102.41

Other fuels

— gaseous mmBtu/scf kg CO 2 

### /mmBtu

Blast Furnace Gas 0.092 × 10 −3 

### 274.32

### Fuel type Default high heat value Default CO 2 

### emission factor

Coke Oven Gas 0.599 × 10 −3 

### 46.85

Propane Gas 2.516 × 10 −3 

### 61.46

Fuel Gas 2 5 

### 1.388 × 10 −3 

### 59.00

Biomass fuels

— solid mmBtu/short ton kg CO 2 

### /mmBtu

Wood and Wood Residuals (dry basis) 6 

### 15.38 17.48 93.80

Agricultural Byproducts 8.25 118.17

Peat 8.00 111.84

Solid Byproducts 25.83 10.39 105.51

Biomass fuels

— gaseous mmBtu/scf kg CO 2 

### /mmBtu

Biogas (Captured methane) Landfill Gas 0. 841 485 × 10 −3 

### 52.07

Other Biomass Gases 0.655 x 10 - 3 

### 52.07

Biomass Fuels

— Liquid mmBtu/gallon kg CO 2 

### /mmBtu

Ethanol 0.084 68.44

Biodiesel 0.128 73.84

Biodiesel (100%) 0.128 73.84

Rendered Animal Fat 0.125 71.06

Vegetable Oil 0.120 81.55

1 

### Provisions of the rule referencing ―default HHVs from Table C

- 1‖ do not apply to culm and gob. The HHV for culm and gob must be determined according to the procedures specified in the Tier 2 Calculation Methodology

.

2 

### The HHV for c omponents of LPG determined at 60 o F and saturation pressure with the exception of ethylene

.

3 

### Ethylene HHV determin ed at 41 o F (5 o C) and saturation pressure.

4 

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

5 

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

the default CO 2 

### emission factor for fuel gas combustion under the

### conditions prescribed in §98.243(d)(2)(i) and (d)(2)(ii) and

§98.252(a)(1) and (a)(2), respectively. Otherwise, reporters subject to subpart X or subpart Y shall use either Tier 3 (Equation C

– 5) or

Tier 4.

6 

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

- 1: HHV

w 

### =((100

- M)/100)*HHV d 

### where HHV

w 

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

### =dry basis HHV from Table C

- 1

.



### 5. Proposed Amendments to Table C

- 2 to 40 CFR part 98 , subpart C :

Table C

– 2 to Subpart C

— Default CH&ihel4 CH 4 

### ; and N&ihel2;O N 2 

### O Emission Factors for Various Types of Fuel

Fuel type Default CH&ihel4 CH 4 

### ; emission factor (kg
CH&ihel4 CH 4 

### ; /mmBtu) Default N&ihel2;O N 2 

### O emission factor (kg N&ihel2;O N 2 

### O /mmBtu)

Coal and Coke (All fuel types in Table C

– 1) 1 

### 1.1 × 10 −02 

### 1.6 × 10 −03



### Anthracite for FBCs only 2 

### 1.1 x 10 - 02 

### 1.6 x 10 - 01



### Waste Anthracite (Culm) for FBCs only 2 

### 1.1 x 10 - 02 

### 4.0 x 10 - 01



### Bituminous for FBCs only 2 

### 1.1 x 10 - 02 

### 1.3 x 10 - 01



### Waste Bituminous (Gob) for FBCs only 2 

### 1.1 x 10 - 02 

### 2.9 x 10 - 01



### Subbituminous for FBCs only 2 

### 1.1 x 10 - 02 

### 6.5 x 10 - 0 2



### Lignite for FBCs only 2 

### 1.1 x 10 - 02 

### 1.1 x 10 - 01



### Natural Gas 1.0 × 10 −03 

### 1.0 × 10 −04



### Petroleum (All fuel types in
Table C

– 1) 3.0 × 10 −03 

### 6.0 × 10 −04



### Fuel Gas 3.0 × 10 −03 

### 6.0 × 10 −04



### Municipal Solid Waste 3.2 × 10 −02 

### 4.2 × 10 −03



### Tires 3.2 × 10 −02 

### 4.2 × 10 −03



### Blast Furnace Gas 2.2 × 10 −05 

### 1.0 × 10 −04



### Coke Oven Gas 4.8 × 10 −04 

### 1.0 × 10 −04



### Biomass Fuels

— Solid (All fuel types in Table C

– 1 )

, except wood and wood residuals) 3.2 × 10 −02 

### 4.2 × 10 −03

### Fuel type Default CH&ihel4 CH 4 

### ; emission factor (kg
CH&ihel4 CH 4 

### ; /mmBtu) Default N&ihel2;O N 2 

### O emission factor (kg N&ihel2;O N 2 

### O /mmBtu)

Wood and wood residuals 7.2 x 10 - 3 

### 3.6 x 10 - 3



### Biogas Biomass Fuels

Gaseous (All fuel types in
Table C

- 1) 3.2 × 10 −03 

### 6.3 × 10 −04



### Biomass Fuels

— Liquid (All fuel types in Table C

– 1) 1.1 × 10 −03 

### 1.1 × 10 −04

1 

### Use of the default emission factors for the coal and coke category may not be used to estimate emissions from combusting anthracite, waste anthracite, bituminous, waste bituminous, subbituminous, or lignite

coal burned in an FBC.

2 

### Use of these default emission factor s is required for FBCs burning the specified coal type.

Note: Those employing this table are assumed to fall under the IPCC definitions of the ―Energy Industry‖ or ―Manufacturing Industries and Construction‖. In all fuels except for coal the values for the se two categories are identical. For coal combustion, those who fall within the IPCC ―Energy Industry‖ category may employ a value of 1g of CH&ihel4;/mmBtu.

### 6. Proposed Amendments to Table AA

- 1 to 40 CFR part 98, subpart AA :

Table AA

– 1 to Subpart AA of Part 98

— Kraft Pulping Liquor

Emissions Factors for Biomass

- Based CO 2 

### , CH 4 

### , and N 2 

### O

Wood furnish Biomass

- based emissions factors (kg/mmBtu HHV)

CO 2 

### a CH 4 

### N 2 

### O

North American Softwood 94.4 0.030 0.0019 0.005 0 .00042

North American Hardwood 93.7 0.0019 0 .00042

Bagasse 95.5 0.0019 0.00042

Bamboo 93.7 0.0019 0.00042

Straw 95.1 0.0019 0.00042

a 

### Includes emissions from both the recovery furnace and pulp mill lime

kiln.



### 7. Proposed Amendments to Table AA

- 2 to 40 CFR part 98, subpart AA :

Table AA

– 2 to Subpart AA of Part 98

— Kraft Lime Kiln and Calciner

Emissions Factors for Fossil Fuel

- Based CH&ihel4; CH 4 

### and N&ihel2;O N 2 

### O

Fuel Fossil fuel

- based emissions factors (kg/mmBtu HHV)

Kraft lime kilns Kraft calciners

CH&ihel4; CH 4 

### N&ihel2;O N 2 

### O CH&ihel4; CH 4 

### N&ihel2;O N 2 

### O

Residual Oil (any type) 0.0027 0 0.0027 0.0003

Distillate Oil (any type) 0.0027 0 0.0027 0.0004

Natural Gas 0.0027 0 0.0027 0.0001

Biogas 0.0027 0 0.0027 0.0001

Petroleum coke 0.0027 0 NA a a 

### NA a



### Other Fuels See Table

C

- 2 0 See Table

C

- 2 See Table

C

- 2

a Emission factors for kraft calciners are not available.

### 8. Proposed Amendments to Table HH

- 1 to 40 CFR part 98, subpart H H :

Table HH

– 1 to Subpart HH of Part 98

— Emissions Factors, Oxidation

Factors and Methods

Factor Default value Units

DOC and k values

— Bulk waste option

DOC (bulk waste) 0.20 Weight fraction, wet

basis.

k (precipitation plus

recirculated leachate a 

### <20 inches/year) 0.02 yr−1

k (precipitation plus

recirculated leachate a 

### 20

– 40 inches/year) 0.038 yr−1

k (precipitation plus

recirculated leachate a 

### >40 inches/year) 0.057 yr−1

DOC and k values

— Modified bulk MSW option

DOC (bulk MSW, excluding inerts
and C&D waste) 0.31 Weight fraction, wet

basis.

DOC (inerts, e.g., glass, plastics, metal, concrete) 0.00 Weight fraction, wet

basis.

DOC (C&D waste) 0.08 Weight fraction, wet

basis.

k (bulk MSW, excluding inerts
and C&D waste) 0.02 to 0.057 b 

### yr−1

k (inerts, e.g., glass, plastics, metal, concrete) 0.00 yr−1

k (C&D waste) 0.02 to 0.04 b 

### yr−1

DOC and k values

— Waste composition option

### Factor Default value Units

DOC (food waste) 0.15 Weight fraction, wet

basis.

DOC (garden) 0.2 Weight fraction, wet

basis.

DOC (paper) 0.4 Weight fraction, wet

basis.

DOC (wood and straw) 0.43 Weight fraction, wet
basis.

DOC (textiles) 0.24 Weight fraction, wet

basis.

DOC (diapers) 0.24 Weight fraction, wet

basis.

DOC (sewage sludge) 0.05 Weight fraction, wet

basis.

DOC (inerts, e.g., glass, plastics, metal, cement) 0.00 Weight fraction, wet

basis.

k (food waste) 0.06 to 0.185 c 

### yr−1

k (garden) 0.05 to 0.10 c 

### yr−1

k (paper) 0.04 to 0.06 c 

### yr−1

k (wood and straw) 0.02 to 0.03 c 

### yr−1

k (textiles) 0.04 to 0.06 c 

### yr−1

k (diapers) 0.05 to 0.10 c 

### yr−1

k (sewage sludge) 0.06 to 0.185 c 

### yr−1

k (inerts e.g., glass, 0.00 yr−1

### Factor Default value Units

plastics, metal, concrete)

Other parameters

— All MSW landfills

MCF 1.

DOC F 

### 0.5

F 0.5

OX 0.1 See Table HH

4 of this subpart

DE 0.99

a 

### Recirculated leachate (in inches/year) is the total volume of leachate recirculated from company records or engineering estimates divided by the area of the portion of the landfill containing waste with appropriate unit conversions. Alternatively, landfills that use leachate recirculation can elect to use the k value of 0.057 rather than calculating the

reci rculated leachate rate.

b 

### Use the lesser value when precipitation plus recirculated leachate is less than 20 inches/year. Use the greater value when precipitation plus recirculated leachate is greater than 40 inches/year. Use the average of the range of val ues when precipitation plus recirculated leachate is 20 to 40 inches/year (inclusive). Alternatively, landfills that use leachate recirculation can elect to use the greater value rather than calculating the recirculated leachate rate.

c 

### Use the lesser value when the potential evapotranspiration rate exceeds the mean annual precipitation rate plus recirculated leachate. Use the greater value when the potential evapotranspiration rate does not exceed the mean annual precipitation rate plus recirculated leachat e. Alternatively,

landfills that use leachate recirculation can elect to use the greater value rather than assessing the potential evapotranspiration rate or recirculated leachate rate.

9. Proposed Amendments to Table HH

- 2 to 40 CFR part 98, subpart H H :

### Table HH

– 2 to Subpart HH of Part 98

— U.S. Per Capita Waste Disposal Rates

Year Waste per capita ton/cap/yr 

### % to

SWDS

1950 0.63 

### 100

1951 0.63 

### 100

1952 0.63 

### 100

1953 0.63 

### 100

1954 0.63 

### 100

1955 0.63 

### 100

1956 0.63 

### 100

1957 0.63 

### 100

1958 0.63 

### 100

1959 0.63 

### 100

1960 0.63 

### 100

1961 0.64 

### 100

1962 0.64 

### 100

1963 0.65 

### 100

1964 0.65 

### 100

1965 0.66 

### 100

1966 0.66 

### 100

1967 0.67 

### 100

1968 0.68 

### 100

1969 0.68 

### 100

1970 0.69 

### 100

1971 0.69 

### 100

1972 0.70 

### 100

1973 0.71 

### 100

1974 0.71 

### 100

1975 0.72 

### 100

1976 0.73 

### 100

1977 0.73 

### 100

1978 0.74 

### 100

1979 0.75 

### 100

1980 0.75 

### 100

1981 0.76 

### 100

1982 0.77 

### 100

1983 0.77 

### 100

1984 0.78 

### 100

1985 0.79 

### 100

1986 0.79 

### 100

1987 0.80 

### 100

1988 0.80 

### 100

1989 0. 

### 85 83 

### 84

1990 0. 

### 84 82 

### 77 Deleted Cells

### Year Waste per capita ton/cap/yr 

### % to

SWDS

1991 0. 

### 78 76 

### 76

1992 0. 

### 76 74 

### 72

1993 0. 

### 78 76 

### 71

1994 0. 

### 77 75 

### 67

1995 0. 

### 72 70 

### 63

1996 0. 

### 71 68 

### 62

1997 0. 

### 72 69 

### 61

1998 0. 

### 78 75 

### 61

1999 0. 

### 78 75 

### 60

2000 0. 

### 84 80 

### 61

2001 0. 

### 95 91 

### 63

2002 1. 

### 06 02 

### 66

2003 1. 

### 06 02 

### 65

2004 1. 

### 06 01 

### 64

2005 

### 1.06 0.98 

### 64

2006 

### 1.06 0.95 

### 64

2007 0.95

2008 0.95

2009 and all later years 0.95


### Editorial Note: At 75 FR 66474, October 28, 2010, Table HH

– 2 to subpart HH was amended; however, the amendment could not be incorporated as instructed. Deleted Cells

### 10. Proposed Table HH

- 4 to 40 CFR part 98, subpart H H :

Table HH

– 4 to Subpart HH of Part 98

— Landfill Methane Oxidation

Fractions

If your methane flux rate a 

### for the

reporting year is: Use this l andfill methane

oxidation fraction:

Less than 10 g rams per square

meter per day (g/m 2 

### /d) 0.35

10 to 70 g/m 2 

### /d 0.25

Greater than 70 g/m 2 

### /d 0.10

a 

### Methane flux rate (in g rams per square meter per day; g/m 2 

### /d) is the mass flow rate of methane per unit area at the bottom of the surface soil prior to any oxidation and is calculated as

follows. For Equation HH

- 5 of this subpart, or for Equation TT

- 6 of subpart TT of this part,

For Equation HH

- 6 of this subpart,

For Equations HH

- 7 of this subpart,

For Equation HH

- 8 of this subpart,

Where:

MF = Methane flux rate from the landfill in the reporting

year ( g rams per square meter per day, g/m 2 

### /d ).

K = unit conversion factor = 10 6 

### /365 (g/metric ton per

days/year) or 10 6 

### /366 for a leap year. Field Code Changed

Field Code Changed

Field Code Changed

Field Code Changed

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

m 2 

### ).

G CH 4 

### = Modeled methane generation rate in reporting year from

Equation HH

– 1 of this subpart, or, for application with Equation HH

- 6 only, the greater of the m odeled methane generation rate in reporting year from Equation HH

– 1 of this subpart and t he quantity of

recovered CH 4 

### from Equation HH

– 4 of this subpart (metric tons CH 4 

### ).

CE = Collection efficiency estimated at landfill, taking

into account system coverage, operation, and cover system materials from Table HH

– 3 of this subpart. If area by soil cover type information is not available, use default value of 0.75 (CE4 in table HH

– 3 of this subpart) for all areas under active influence of the

collection s ystem.

N = Number of landfill gas measurement locations

(assoc i ated with a destruction device or gas sent off

site). If a single monitoring location is used to

monitor volumetric flow and CH 4 

### concentration of the recovered gas sent to one or multiple des truction devices, then N=1.

R n 

### = Quantity of recovered CH 4 

### from Equation HH

– 4 of this

subpart for the n th 

### measurement location (metric tons).

f Rec , n 

### = Fraction of hours the recovery system associated with

the n th 

### measurement location was operating (annual operating hours/8760 hours per year or annual operating hours/8 78 4 hours per year for a leap year ).

1 1

. Proposed Amendments to Table MM

- 1 to 40 CFR part 98, subpart MM :

### Table MM

– 1 to Subpart MM of Part 98

— Default Factors for Petroleum Products and Natural Gas Liquids 12



### Products Column A: density (metric tons/bbl) Column B:

carbon

share (% of mass) Column C:

emission factor (metric tons

CO 2 

### / bbl)

Finished Motor Gasoline

Conventional

— Summer

Regular 0.1181 86.66 0.3753

Midgrade 0.1183 86.63 0.3758

Premium 0.1185 86.61 0.3763

Conventional

— Winter

Regular 0.1155 86.50 0.3663

Midgrade 0.1161 86.55 0.3684

Premium 0.1167 86.59 0.3705

Reformulated

— Summer

Regular 0.1167 86.13 0.3686

Midgrade 0.1165 86.07 0.3677

Premium 0.1164 86.00 0.3670

Reformulated

— Winter

Regular 0.1165 86.05 0.3676

Midgrade 0.1165 86.06 0.3676

Premium 0.1166 86.06 0.3679

Gasoline

— Other 0.1185 86.61 0.3763

Blendstocks

CBOB

— Summer

Regular 0.1181 86.66 0.3753

Midgrade 0.1183 86.63 0.3758

Premium 0.1185 86.61 0.3763

CBOB

— Winter

Regular 0.1155 86.50 0.3663

Midgrade 0.1161 86.55 0.3684

Premium 0.1167 86.59 0.3705

### Products Column A: density (metric tons/bbl) Column B:

carbon

share (% of mass) Column C:

emission factor (metric tons

CO 2 

### / bbl)

RBOB

— Summer

Regular 0.1167 86.13 0.3686

Midgrade 0.1165 86.07 0.3677

Premium 0.1164 86.00 0.3670

RBOB

— Winter

Regular 0.1165 86.05 0.3676

Midgrade 0.1165 86.06 0.3676

Premium 0.1166 86.06 0.3679

Blendstocks

— Other 0.1185 86.61 0.3763

Oxygenates

Methanol 0.1268 37.48 0.1743

GTBA 0.1257 64.82 0.2988

MTBE 0.1181 68.13 0.2950

ETBE 0.1182 70.53 0.3057

TAME 0.1229 70.53 0.3178

DIPE 0.1156 70.53 0.2990

Distillate Fuel Oil

Distillate No. 1

Ultra Low Sulfur 0.1346 86.40 0.4264

Low Sulfur 0.1346 86.40 0.4264

High Sulfur 0.1346 86.40 0.4264

Distillate No. 2

Ultra Low Sulfur 0.1342 87.30 0.4296

Low Sulfur 0.1342 87.30 0.4296

High Sulfur 0.1342 87.30 0.4296

Distillate Fuel Oil No. 4 0.1452 86.47 0.4604

Residual Fuel Oil No. 5 (Navy Special) 0.1365 85.67 0.4288

Residual Fuel Oil No. 6 0.1528 84.67 0.4744

### Products Column A: density (metric tons/bbl) Column B:

carbon

share (% of mass) Column C:

emission factor (metric tons

CO 2 

### / bbl)

(a.k.a. Bunker C)

Kerosene

- Type Jet Fuel 0.1294 86.30 0.4095

Kerosene 0.1346 86.40 0.4264

Diesel

— Other 0.1452 86.47 0.4604

Petrochemical Feedstocks

Naphthas (< 401 °F) 0.1158 84.11 0.3571

Other Oils (> 401 °F) 0.1390 87.30 0.4450

Unfinished Oils

Heavy Gas Oils 0.1476 85.80 0.4643

Residuum 0.1622 85.70 0.5097

Other Petroleum Products and Natural Gas Liquids

Aviation Gasoline 0.1120 85.00 0.3490

Special Naphthas 0.1222 84.76 0.3798

Lubricants 0.1428 85.80 0.4492

Waxes 0.1285 85.30 0.4019

Petroleum Coke 0.1818 92.28 0.6151

Asphalt and Road Oil 0.1634 83.47 0.5001

Still Gas 0.1405 77.70 0.4003

Ethane 3 

### 0. 0866 0579 79.89 0. 2537 170

Ethylene 4 

### 0. 0903 0492 85.63 0. 2835 154

Propane 3 

### 0. 0784 0806 81.71 0. 2349 241

Propylene 3 

### 0. 0803 0827 85.63 0. 2521 260

Butane 3 

### 0. 0911 0928 82.66 0. 2761 281

Butylene 3 

### 0. 0935 0972 85.63 0. 2936 305

Isobutane 3 

### 0. 0876 0892 82.66 0. 2655 270

Isobutylene 3 

### 0. 0936 0949 85.63 0. 2939 298

Pentanes Plus 0.1055 83.63 0.3235

Miscellaneous Products 0.1380 85.49 0.43261 

### In the case of products blended with some portion of biomass

based fuel, the carbon share in Table MM

– 1 of this subpart represents only the petroleum

- based components.

2 

### Products that are derived entirely from biomass should not be reported, but products that were derived from both biomas s and a petroleum product (i.e., co

- processed) should be reported as the petroleum product that it most closely represents.

3 

### The density and emission factors for components of LPG determined at 60oF and saturation pressure (LPGs other than ethylene)

4 

### The d ensity and emission factor for ethylene determined at 41oF and saturation pressure.

1 2

. Proposed Amendments to Table NN

- 1 to 40 CFR part 98, subpart NN :

Table NN

– 1 to Subpart HH NN of Part 98

— Default Factors for Calculation Methodology 1 of This Subpart

Fuel Default high high er heating value

factor value 1 

### Default CO 2 

### emission

factor (kg CO 2 

### / MMBtu)

Natural Gas 1. 028 02 6 MMBtu/Mscf 53. 02 0 6

Propane 3.82 2 3.84 MMBtu/bbl 61.46 62.87

Normal

butane 4. 242 4.34 MMBtu/bbl 65.15 64.77

Ethane 4.032 2.8 5 MMBtu/bbl 62.64 59.60

Isobutane 4. 074 1 6 MMBtu/bbl 64.91 64.94

Pentanes plus 4.62 0 MMBtu/bbl 70.02

1 

### Conditions for higher heating values presented in MMBtu/bbl are 60oF and saturation pressure.

1 3 . Proposed Amendments to Table NN

- 2 to 40 CFR part 98, subpart NN:

Table NN

– 2 to Subpart HH NN of Part 98

— Lookup Default Values for Calculation Methodology 2 of This Subpart

Fuel Unit Default CO 2 

### emission value (MT CO 2 

### / Unit) 1



### Natural Gas Mscf 0. 055 054 4

Propane Barrel 0. 235 241

### Fuel Unit Default CO 2 

### emission value (MT CO 2 

### / Unit) 1



### Normal butane Barrel 0. 276 281

Ethane Barrel 0. 253 170

Isobutane Barrel 0. 266 270

Pentanes plus Barrel 0.324

1 

### Conditions for emission value presented in MT CO 2 

### /bbl are 60oF and saturation pressure.

1 4

. Proposed Amendments to Table TT

- 1 to 40 CFR part 98, subpart T T :

Table TT

– 1 to Subpart TT

— Default DOC and Decay Rate Values for

Industrial Waste Landfills

Industry/Waste Type DOC (weight fraction, wet basis) k

[dry

climate a 

### ] (yr −1 

### ) k

[moderate

climate a 

### ] (yr −1 

### ) k

[wet

climate a 

### ] (yr −1 

### )

Food Processing (other than sludge) 0.22 0.06 0.12 0.18

Pulp and Paper (other than sludge) 0.20 0.02 0.03 0.04

Wood and Wood Product (other than sludge) 0.43 0.02 0.03 0.04

Construction and

Demolition 0.08 0.02 0.03 0.04

Industrial Sludge 0.09 0.02 0.04 0.06

Inert Waste [ i.e.
, wastes listed in §98.460(c)(2)] 0 0 0 0

Other Industrial Solid Waste (not otherwise listed) 0.20 0.02 0.04 0.06

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 e ngineering estimates and applied to thelandfill divided by the area of the portion of the landfill containing waste

[with appropriate unit conversions].



### (1) Dry climate = precipitation plus recirculated leachate less than 20 inches/year
(2) Moderate climate = precipitation plus recirculated leachate from 20 to 40 inches/year (inclusive) (3) Wet climate = precipitation plus recirculated leachate greater than 40 inches/year Alternatively, landfills that use leachate recirculation

can elect to use the k value for wet climate rather than calculating the recirculated leachate rate. (1) Dry climate = precipitation plus recirculated leachate less than 20 inches/year.