### 1

**MEMORANDUM FROM:**  Rachel Schmeltz , U.S. EPA, Climate Change Division **TO** : Docket EPA

- HQ

- OAR

- 201 2

- 0934 **DATE:** September 24 , 2013 **SUBJECT:** Table of Final 2013 Revisions to the Greenhouse Gas Reporting Rule

**1.0 INTRODUCTION**  The 2009 f

inal GHG reporting rule (2009 final rule) was signed b y 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 amending specific provisions in the Greenhouse Gas Reporting 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 provi sions that have been the subject of questions from reporting entities

. The purpose of this memorandum is to provide a detailed list of each change finalized in this action

. The table in section 3.0 contains a list of each finalized change, the rule langu age for

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

- references that do not revise the output of the calculations, harmonizing changes within a subpart (such as changes to terminology), simple editorial and m inor 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 each section of Part 98 for whi ch EPA is finalizing changes. **2.0 SUMMARY OF**  **CHANGES INCLUDED** EPA is finalizing 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.

**S ubpart**  A

- General Provision C

- General Stationary Fuel Combustion Sources E

- Adipic Acid Production G

– Ammonia Manufacturing H

– Cement production I

– Electronics Manufacturing 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

### 3 **S ubpart**  DD

- Electrical Transmission and Distribution Equipment Use 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

- Inj ection of Carbon Dioxide



### 3.0 **SUMMARY OF TECHNICAL CORRECTION**  **S AND OTHER AMENDMEN TS**  The following table summarizes the amendments for various subparts of Part 98 which are being addressed b y the 2013 Revisions to the Greenhouse Gas Reporting Rule

. Where applicable, we have indicated where the rule text has been revised followin g proposal. For these items, the rationale for minor editing changes (typ os, formatting) is in the table. The rationale for more significant rule changes is included in the final preamble or the EPA’s response to comment document in Docket Id. No. EPA

- HQ

- OAR

- 2012

- 0934, as indicated.

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**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? 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 pro vide the latitude and longitude representing the geographic centroid or center point 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 f our digits to the right of the decimal point

. Yes See final pream ble 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 proposal preamble 19802 )

A 98.3(c )(13) (None) (13) An indication of whether the facility includes one or more plant sites that have been assigned a “plant code” (as defined under § 98.6) by either the Department of Energy’s Energy Information Administration or by the EPA’s Clean Air Markets Division. Yes See final preamble 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 Administrator 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 per iod, and the Administrator does not respond to the request by the end of such period, the extension request is deemed to be automatically granted for 30 mo re days. During the automatic 30

- day extension, the Administrator will determine what extension, if (4) Notwithstanding paragraphs (h)(1) and (h)(2) of this section, upon request by the owner or operator, the Administrator may provide reasonable extensions of the 45

- day

period for submission of the revised report or information under paragraphs (h)(1) and (h)(2) of this section. If the Administrator receives a request for extension of the 45

- day period, by e

- mail to an address prescribed by the Administrator p rior 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 See proposal preamble 19802 )

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**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  any, beyond the automatic extension is reasonable and will provide any such additional extension. 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 informati on under paragraphs (h)(1) and (h)(2) with 75 days. The Administrator will approve the extension request if the request demonstrates to the Administrator’s satisfaction that it is not practicable to collect and process the data needed to resolve potential reporting errors identified pursuant to paragraphs (h)(1) or (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 for the planned process equipment or unit shutdown that was provided in the original request. (ii) Any subsequent ext ensions 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 for the planned process equipment or unit shut down that was provided in the original or most recently approved request. Clarifies BAMM requirement.

A 98.3(k)(1) (None) (k) Revised g lobal w arming p otentials and special provisions for reporting year 2013

. This paragraph (k) applies to owners or operators of facilities or suppliers that first become subject to any subpart of part 98 sole ly due to an amendment to Table A

- 1 of this subpart. (1) A facility or supplier that was not subject to any subpart of part 98 for reporting year 2012, but first becomes subject to any subpart of part 98 due to a change in the GWP for one or more compounds in Table A

- 1 of this subpart, Global Warming Potentials, is not required to submit an annual GHG report for reporting year 2013. S ee final pream ble text for explanation

A 98.3(k)(2) (None) (2) A facility or supplier that is subject to a subpart of part 98 for reporting year 2012, but first becomes subject to any subpart of part 98 due to a change in the GWP for one or more compounds in Table A

- 1 of this subpart, is not required to include those subparts for which the facility is subject only due to Ye s See final pream ble text for explanation

. Minor text edits in final rule

.

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**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  the change in the GWP in the annual GHG report submitted for reporting year 2013. A 98.3(k)(3 ) (None) (3) Starting on January 1, 2014, facilities or suppliers identified in paragraphs (k)(1) or (k)(2) of this section must start monitoring and collecting GHG data in compliance with the applicable subparts of part 98 for w

hich the facility is subject due to the change in the GWP for the annual greenhouse gas report for reporting year 2014, which is due by March 31, 2015. A 98.3(l) (None) (l) Special provision for best available monitoring methods in 2014. This paragraph (l) 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 W arming Potentials. See final pream ble text for explanation

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 method ologies and equations in the “Calculating GHG Emissions” sections of each relevant subpart, but may use the best available monitoring method for any parameter for which it is not reasonably feasible to acquire, install, and operate a required piece of mo ni toring equipment by January 1, 2014. Starting no later than April 1, 2014, the ow ner or operator must discontinue using best available methods and begin following all applicable monitoring and QA/QC requirements of this part, except as provided in paragrap h (l)(2) of this section. Best available mo nitoring methods means any of the following methods: See final pream ble text for explanation

A 98.3(l)(1)(i)

- (None) (i) Monitoring methods currently used by the facility See final pream ble text for

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**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  (iv) that do not meet the specifications of a relevant subpart. (ii) Supplier data. (iii) Engineering calculations. (iv) Other company records. 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. (ii) Content of request. Re quests must contain the following information: See final pream ble text for explanation

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 mo nitoring instrumentation will be installed. See final pream ble 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 neede d. See final pream ble 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 final pream ble 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 alternative vendors promised delivery, backorder notices or unexpected delays, descriptions of actions taken to e xpedite delivery, and the current expected date of delivery. See final pream ble text for explanation

A 98.3(l)(2)(ii)( E) (None) (E) If the reason for the extension is that the equipment cannot be installed without a process unit shutdown, include support ing documentation demonstrating that it is not practicable to isolate the equipment and install the monitoring instrument See final pream ble text for explanation

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**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  without a full process unit shutdow n. Include the date of the most recent process unit shutdown, the frequency of shutdowns for this p rocess unit, and the date of the next planned shutdown during which the mo nitoring 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 REG ISTER] and April 1, 2014, include a justification of why the equipment could not be obtained and installed during that shutdown. 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 as reasonably feasible and the expected date by which the equipment will be installed and operating. See final pream ble text for explanation

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 mo nitoring equipment by April 1, 2014. The use of best available methods under thi s paragraph (l) will not be approved beyond December 31 , 2014. See final pream ble text for explanation

A 98.6 Continuous bleed means a continuous flow of pneumatic supply gas to the process measurement device (e.g. level control, temperature control, pre ssure control) where the supply gas pressure is mo dulated 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. 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 mo dulated 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, 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 coal mine. Degasification systems include gob and premine surface drainage we lls, gob and premine in

- mine drainage wells, and in

- mine See proposal preamble 19802 )

### 9

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  and post

- mining systems. gob and premine cross

- measure borehole wells. 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 all or a portion of the full volume of the actuator intermittently when control action is necessary, but does not bleed continuously. See proposal preamble 19802 )

A 98.6 98.6 No definition Plant code means either of the following: (1) The Plant ID code assigned by the Department of Energy’s Energy Information Administration. The E nergy I nformation A dministration Plant ID code is also referred to as the “ORIS code” , “ORISPL code , ” “Facility ID”, or “Facility code”, among other names. (2) If a Plant ID code has not been assigned by the D epartment of E nergy ’s E nergy I nformation A dministration , then plant code means a code beginning with “88” assigned by the EPA’s Clean Air Markets Division for electronic reporting. Yes See final preamble text for explanation

A 98.6 Ventilation well or shaft means a well or shaft em ployed 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 em ployed at an underground coal mine to serve as the outlet or conduit to move air from the ventilation system out of the mine. See proposal preamble 19802 )

A 98.6 Ventilation system means a system that is used to contr ol the concentration of methane and other gases within mine working areas through mine ventilation, rather than a mine degasification system. A ventilation system consists of fans that move air through the mine workings to dilute methane concentrations. Th is includes all ventilation shafts and wells at the underground coal mine. Ventilation system means a system that is used to control the concentration of methane and other gases within mine working areas through mine ventilation, rather than a mine degasif ication system. A ventilation system consists of fans that move air through the mine workings to dilute methane concentrations. See proposal preamble 19802 )

A 98.7(n) (n) The following material is available from the International SEMATECH Manufacturing Initiative, (n) [Reserved] Yes Harmonizing change with revision to paragraph 98.96(y)(3)(i).

### 10

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  2706 Montopolis Drive, Austin, Texas 78741, (512) 356

- 3500, http://ismi.sematech.org. (1) Guideline for Environmental Characterization of Semiconductor Proces s Equipment, International SEMATECH Manufacturing Initiative Technology Transfer #06124825A

- ENG, December 22, 2006 (International SEMATECH #06124825A

- ENG), IBR approved for §98.94(d), §98.94(d)(1), §98.94(e), §98.94(e)(1), §98.94(g)(1), §98.96(f)(4), and § 98.97(b)(1). (2) [Reserved] A Table A

- 1 Table A

- 1 See Appendix A for changes to Table A

- 1 See final pream ble 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, hav ing 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 percent of the annual heat input to the unit, or if §98.36(c)(3) applies, to the group of units served by a common supply pipe. See proposal preamble 19802 )

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

mmBtu/hr for boilers and process heaters only and relevant unit s 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.

### 11

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  C 98.36(b)(11) None (11) If applicable, the plant code (as defined in §98.6). Yes See final pream ble text for explanation C 98.36(c)(1)(xi ) None (xi) If applicable, the plant code (as defined in §98.6). Yes See final preamble text for explanation C 98.36(c)(2)(x) None (x) Reserved. Yes Reserved for Revisions to Reporting and Recordkeeping and Proposed Confidentiality Determinations Under the Greenhouse Gas Reporting Program (78 FR 55994, September 11, 2013). C 98.36(c)(2)(xi ) None (xi) If applicable, the plant code (as defined in §98 .6). Yes See final preamble text for explanation 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 98.36(c)(3)(x) None (x) If applicable, the plant code (as defined in §98.6). Yes See final preamble text for explanation C 98.36(d)(1)(x ) None (x) If applicable, the plant code (as defined in §98.6). Yes See final preamble text for explanation C 98.36(d)(2)(ii )(J) None (J) If applicable, the plant code (as defined in §98.6). Yes See final preamble text for explanation C 98.36(d)(2)(ii i)(J) None (J) If applicable, the plant code (as defined in §98.6). Yes See final preamble text for explanation C Table C

- 1 Table C

- 1 See Appendix A for changes to Table C

- 1 See proposal preamble 19802 ) C Table C

- 2 Table C

- 2 See Appendix A for changes to Table C

- 2 See proposal preamble 19802 ) 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 abatement technology “N” is located

after your test point, you must determine the destruction efficiency according to paragraphs ( d)(1), (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 Clarifies requirement.

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**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  (2), or (3) of this section. (d)(1), (d)(2), or (d)(3) of this section. E 98.53(e) (e) If any N 2 O abatement technology “N” is located

after your test point, you must determine 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) If the adipic acid production unit exhausts to any N 2 O abatement technology “N”, you must determine 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 thi s section. Clarifies requirement.

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 operating). 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 o f 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 technology 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 9 8.53(g)(3) DF N = Destruction efficiency of N 2 O abatement DF N = Destruction efficiency of N 2 O abatement Clarifies a calculation term.

### 13

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  technology “N” (percent of N 2 O removed from vent stream). technology “N” (decimal fraction of N 2 O removed from vent stream). E 98.53(g)(3) AF N = Abatement utilization factor of N 2 O

abatement technology “N” (percent of time that the abatement technology is operating). AF N = Abatement utilization factor of N 2 O abatement technology “N” (decimal fract ion of time that the abatement technology is operating). Clarifies a calculation term.

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 technology “N”). Clarifies a calculation term.

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

adipic acid p roduced. You must also determine the mo nthly 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 determine the mo nthly amount of adipic acid produced during which N 2 O abatement technology is operating. These mo nthly amounts are determined according to the method s in paragraphs (c)(1) or (c)(2) of this section. Corrects a requirement for consistency throughout 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 produced. 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 section. 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 yo ur 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 yo ur 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 k S k L k G k CO 

### CO

CO CO E

, , 2 , , 2 , , 2 , 2 

### 

  

# 

 

###  j

k k CO 

### E CO 1 ,

2 2

### 14

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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

recycle stream used to determine monthly feedstock consumption or monthly wa ste recycle stream quantity, you must determine the best availabl e estimate(s) of the parameter(s), based on all available process data. (b) For missing feedstock supply rates used to determine monthly feedstock consumption, you must determine the best available estimate(s) of the parameter(s), based on all available process data. Correction to missing data procedures to remove 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 information 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 th e 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

yo u must report the following information: (b) If a CEMS is not used to measure emissions, then yo u 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. Cl arifies the units of the emissions.

H 98.86(a)(2) (2) Monthly cement production from each kiln at the facility. (2)Annual facility cement production. See proposal preamble 19802 ) I 98.96(y)(3)(i) (i) The testing of tools to determine the potential

effect on current utilization and by

- product formation rates and destruction or removal efficiency values under the new conditions. You must follow the QA/QC procedures in the International SEMATECH #60124825A

- ENG (incorporated by reference, see § 98.7) when measuring and calculating process sub

- ty pe and process type fluorinated GHG and N 2 O utilization and by

- product formation rates. (i) The testing of tools to determine the potential effect on current utilization and by

- product formation rates an d destruction or removal efficiency values under the new conditions. Yes See final preamble text for explanation.

### 15

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 proposal preamble 19802 )

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 proposal preamble 19802 )

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 proposal preamble 19802 )

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 Subpart 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 paragraphs (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 proposal preamble 19802 )

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

yo ur 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 rather than yo ur best esti mate 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 fluorinated 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 (b) For each continuous glass melting furnace that is Corrects reference

### 16

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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. 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. N 98.143(b)(2)(i v) 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

- based mineral i in carbonate

- based raw material i. Clarifies the equation term

N 98.143(b)(2)(i v) 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 data 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 Comb ustion 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 Com bustion of Coal and Coke by Inductively Cou pled Plasma

—Atomic Emission Spectrometry (incorporated by reference, see §98.7). (b) You must measure carbonate

- based mineral mass fractions at least annually to verify the mass fraction data provided by the supplier of the raw material; 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, yo u 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 Plasma

— Atomic Emission Spectrometry (incorporated by reference, see §98.7). See proposal preamble 19802 )

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

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

- based raw

material charged to a continuous 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

### 17

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 oxidizer 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) Where: E D = Mass of HFC

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

– 8 of this section. (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) Where: E D = Mass of HFC

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

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

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 See proposal preamble 19802 )

### 18

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  and that the concentration is below the detection limit.

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 mo nthly, use the arithmetic average of values obtained during the month as the monthly average. See proposal preamble 19802 )

P 98.163(b)(1) Fdstk n = Volume of the gaseous fuel and feedstock used in month n (scf (at standard conditio ns 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 frequently 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

- mo le). Fdstk n = Volume or mass of

the gaseous fuel or feedstock used in month n (scf (at standard conditions of 68 °F and atmospheric pressure) or kg of fuel or feedstock). CC n = Average carbon content of the gaseous fuel or feedstock for month n (kg carbon per kg of fuel or feedstock). MW n = Average molecular weight of the gaseous fuel or feedstock for month n (kg/kg

- mo le). If you measure mass, the term “MW n/MVC” is replaced with “1”. Yes See final preamble text for explan ation

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 gallo n of fuel and feedstock). Fdstk n =Volume or mass of

the liquid fuel or feedstock used in month n (gallons or kg of fuel or feedstock). CC n = Average carbon content of the liquid fuel or feedstock, for month n (kg carbon per gallon or kg of fuel or feedstoc k). Yes See final preamble text for explanation

P 98.163(b)(3) Fdstk n = Mass of solid fuel and feedstock used in Fdstk n = Mass of solid fuel or feedstock used in Clarifies equation terms

### 19

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  mo nth n (kg of fuel and feedstock). CC n = Average 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). mo nth n (kg of fuel or feedstock). CC n = Average carb on content of the solid fuel or feedstock, for month n (kg carbon per kg of fuel or feedstock). 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, nap htha, 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 and feedstocks delivered by bulk transport (e.g., by truck o r rail). See proposal preamble 19802 )

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 upon 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 having consistent composition, or upon delivery for solid fuels and feedstocks delivered by bulk transport (e.g., by truck or rail). See proposal preamble 19802 )

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, maintained, and calibrated according to the manufacturer's instructions; and the methods used for operation, maintenance, and calibration of the GC are documented in the w

ritten monitoring pl an for the unit under §98.3(g)(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 chromatograp hic analysis of the fuel and feedstock, provided that the chromatograph is operated, maintained, and calibrated according to the manufacturer's instructions; and the methods used for operation, maintenance, and calibration of the chromatograph are document ed in the written mo nitoring plan for the unit under §98.3(g)(5). See proposal preamble 19802 )

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 None See proposal preamble 19802 )

### 20

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  to measure GHG emissions. (2) Fossil fuel consumptio n, 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 m ethodology in §98.33(d) is used to calculate CO 2 emissions from sorbent.
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 devi ces must also be recorded, and the technical basis for these estimates must be provided. None See proposal preamble 19802 )

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 proposal preamble 19802 )

P 98.166(b )(2) (2) Monthly consumption of each fuel and feedstock

used for hydrogen production and its type (scf of gaseous fuels and feedstocks, gallons of liquid fuels and feedstocks, kg of solid fuels and feedstocks). (2) Monthly consumption of each fuel and feedstock used for hydrogen production and its type (scf or kg of gaseous fuels and feedstocks, gallons or kg of liquid fuels and feedstocks, kg of solid fuels and fee dstocks). Yes See final preamble text for explanation

P 98.166(b)(5 ) (5) Monthly analyses of carbon content for each fuel

and feedstock used in hydrogen production (kg carbon/kg of gaseous and solid fuels and feedstocks , (kg carbon per gallon of liquid fuels and feedstocks). (5) Monthly analyses of carbon content for each fuel and feedstock used in hydrogen production (kg carbon/kg of gaseous and solid fuels and feedstocks , kg carbon per gallon or kg of liquid fuels and feedstocks). Yes See final preamble text for explanation

P 98.167(c ) (None) (c) For units using the calculation methodologies Yes See proposal preamble

### 21

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  described in 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 consump tion, 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. 19802 ). Final rule corrects typo.

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, calibration of weighing equipment, fuel and feedstock flow meters, and other measurement devices. The estimated accuracy of measurements m ade with these devices must also be recorded, and the technical basis for these estimates must be provided. See proposal preamble 19802 )

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 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 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 col l ocated with an integrated iron and steel manufacturing process, direct reduction furnaces not collocated with an integrated iron and steel manufacturing process, and electric arc furnace (EAF) steelmaking not col l ocated with an integrated 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 See proposal preamble 19802 )

### 22

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  process located at a facility with an integrated iron and steel manufacturing process is part of the integrated iron and steel manuf acturing facility. has a basic oxygen furnace for refining molten iron into steel. E ach 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 ) (F s ) = Annual mass of the solid fuel combusted (metric tons). (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). (F g) = Annual volume o f the gaseous fuel combusted ( scf ). (F l ) = Annual volume o f the liquid fuel combusted (gallons). (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 an aly sis 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). (F s ) = Annual mass of the solid fuel use d (metric tons). (C sf ) = Carbon content of the solid fuel, from the fuel analysis (expressed as a decimal fraction). (F g) = Annual volume o f the gaseous fuel used ( scf ). (F l ) = Annual volume o f the liquid fuel used (gallons). (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 co ntrol residue, from the carbon analysis results (expressed as a decimal fraction). Clarifies equation terms

Q 98.173(b)(1)(i i), (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 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 w eight, expressed as a decimal fraction). (C Iron) = Carbon content of the molten iron, from the carbon analysis results (expressed as a decimal 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 Carbon) = Carbon content of the carbonaceous materials, from the carbon analysis results (expressed as a decimal fra ction). (C Steel ) = Carbon content of the steel, from the carbon analysis results (expressed as a decimal fraction). (C Slag) = Carbon content of the slag, from the carbon Clarifies equation terms

### 23

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  (C Slag) = Carbon content of the slag, from the carbon analysis (percent by weight, expressed as a decimal fraction). (C R) = Carbon content of the air pollution control residue, from the carbon analysis results (perc ent by weight, expressed as a decimal fraction). 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)(i ii) (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 content of the air pollution control residue, from the carbon analysis results (percent by weight, expressed as a d ecimal fraction). (C Coal ) = Carbon content of the coal, from the carbon analysis results (expressed as a decimal fraction). (C Coke ) = Carbon content 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)(i v) (F g) = Annual volume o f the gaseous fuel combusted

( scf ). (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, expre ssed 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). (F g) = Annual volume o f the gaseous fuel used ( scf ). (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 deci ma 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)( 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) (Eq. Q

- 5) Where: CO 2 = Annual CO 2 ma ss emissions from the EAF (metri c tons). (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 Flux )+(Electrode)*(C Electrode )+(Carbon)*(C Carbon)

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

)*MW/MVC*0. 001

- (Slag)*(C Slag)

- (R)* (C R)] (Eq. Q

- 5) Where: CO 2 = Annual CO 2 ma ss emissions from the EAF See proposal preamble 19802 )

### 24

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 mas s 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, 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 (percent by weight, expressed as a decimal fraction). (Slag) = Annual mass of slag produced by the furnace (metric tons). (C Slag) = Carbon content of the slag, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (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 carb on 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 analysis results (expressed as a decimal fraction). (Carbon) = Annual mass of carbonaceous mate rials (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). (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

### 25

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  (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). (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) = Conver sion 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 results (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 (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) (Eq. Q

- 6) 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 (percent by weight, expressed as a dec imal 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 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). (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)} (Eq. Q

- 6) 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 analysis 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). Clarifies the order of ope the equation.

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

(scf). (F g) = Annual volume of the gaseous fuel us ed (scf). (C Ore ) = Carbon content of the iron ore or iron ore Clarifies equation terms

### 26

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  (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 fraction). (C Other) = Average carbon content of the other materials charged to the furnace, from the carbon analysis result s (percent by weight, expressed as a decimal fraction). (C Iron) = Carbon content of the iron, from the carbon analysis results (percent by weight, expressed as a decimal fraction). (C NM ) = Carbon content of the non

- me tallic materials, from the carbon analy sis 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). pellets, from the carbon analysis results (expressed as a decimal fraction). (C Carbon) = Carbon content of the carbonaceous materials, 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 the iron, from the carbon analysis results (expressed as a decimal f raction). (C NM ) = Carbon content of the non

- me tallic materials, 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 fractio n).

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 emiss ions 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 stack as any combustion unit or process equip me nt 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 paragraph (b) of this section shall not be used t o calculate process emissions. The ow

ner or operator shall report under this subpart the combined stack emissions according to the Tier 4 Calculation Methodology in (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 Tier 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 Fuel Combustion Sources), then the calculation methodology in paragraph (b) of this section shall not be used to calculate process emissions. The ow

ner or operator shall report under See proposal preamble 19802 )

### 27

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  §98.33(a)(4) and all associated requirements for Tier 4 in subpart C of this part (General Stationary Fuel Com bustion Sources). this subpart the combined stack emissi ons according to the Tier 4 Calculation 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 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, we ighed 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 mo nth, and sum the monthly mass to determine the annual mass for each p rocess 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 p lant 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 mo nth, 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 o f steel output from decarburization vessels is required. See proposal preamble 19802 )

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 o r 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, decarbur ization 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 s teel 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 exhaust for a period spanning at least 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 ty pes of steel. See proposal preamble 19802 )

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 esti mate See proposal preamble 19802 )

### 28

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  in §98.173(b)(1) or for facilities that estimate emissions using the site

- specific emission factor procedure 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 emis sion 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, except as provided in §98.174(b )(4), report the following information for each process: See proposal preamble 19802 )
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 and 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 determination of the mass of ste el 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 other 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, shells 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 combined process and co mb ustion 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 (General Stationary Fuel Comb ustion 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 C EMS 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 Fuel Combustion Sources). Clarifies language.

### 29

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  S 98.193(b)(1) (1) Calculate and report under this subpart the

combined process and combustion CO 2 emissions 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 (General Stationary Fuel Combustion Sources). (1) Calculate and report under this subpart the combined process and combustion CO 2 emissions from all lime kilns by operating and maintaining a CEM S 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 (General Stationary Fuel Combustion Sources). Clarifies language.

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)(i i) (ii) You must calculate a monthly emission factor for

each type of calcined byprodu ct/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) using Equation S

–2 of this section: Clarifies langu age.

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

byproduct/ waste type i sold, for month 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)(i i) 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 calculation term.

S 98.193(b)(2)(i ii) (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 i s not sold (including lime kiln dust and scrubber sludge) using Equation S

– 3 of this section: Clarifies language.

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

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

### 30

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  tons MgO / metric ton lime). (metric tons MgO / metric ton lime). S 98.193(b)(2)(i ii) M Waste,i = Annual weight or mass of calcined

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

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) You 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 mo nth n, ( metric tons CO 2 /ton byproduct/waste) from Equation S

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

–2 of this section. Clarifies 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 wa ste 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/waste s 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

ty pe of lime product that is produced and each calcined by

product/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 difference in the beginning of and end of year inventories for these (a) You must determine the total quantity of each ty pe 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, inc luding 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 difference in the beginning of and end of year inventories for these Clarifies language.

### 31

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  products, when measurements represent lime sold. produ cts, when measurements represent lime sold. 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 instruments identified in parag raph (a) of this section or by using a calcined byproduct/waste generation rate. (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 instruments identified in paragraph (a) of this section or by using a calcined byproduct or waste generation rate. Clarifies language.

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

(percent total CaO and percent total MgO ) of each ty pe 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 byproduct/waste that is not sold on an annual basis. (c) You must determine the chemical composition (percent total CaO and percent tota l MgO) of each ty pe 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 ty pe of calcined byproduct or waste sold on a monthly basis. You must determine the chemical composition for each type 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 data value shall be the best available estimate based on all available process data or data used for acco unting purposes. (a) For each missing value of the quantity of lime produced (by lime type), and quantity of calcined byproduct or waste produced and sold, the substitute data value shall be the best available estimate based on all available process data o r 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 quantity 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 wa ste 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 wa ste 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 (2) Monthly emission factors (metric ton CO 2 /ton Clarifies language.

### 32

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  produced. lime product) for each lime product type produced

. 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 lime type produced and each calcined lime byproduct/waste type. (4) Standard method used (ASTM or NLA testing method) to determine chemical compositions of each lime type produced and each calcined lime byproduct or waste type. Clarifies language.

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 wa ste 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 wa ste 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/w astes 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 performance 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 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 (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 technolo gy 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 Clarifies terminology of the production units

### 33

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  processes are operating and base the site

- specific emission factor on the combined production rate of the multiple nitric acid production units. processes are operating and base the site

- specific emission factor on the combined production rate of the multiple nitric acid trains. 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) per hour. (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 hour. Clarifies units of meas

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 destruction 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 abatement technology “N” according to paragraphs (d)(1), (d)(2), or (d)(3) of this section. Clarifies requi rement.

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 acid 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. Clarifies requirement

V 98.223(e) P a,t,N P t,N Corrects equation term V 98.223(g)(1) EN 2 O t = Annual N 2 O ma ss emissions from nitric acid production unit “t” according to this Equation V

– 3a (metric tons) EN 2 O t = Annual N 2 O ma ss 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” (decima l fraction of N 2 O removed from vent stream). Corrects a calculation term.

V 98.223(g)(1) AF = Abatement utilization factor of N 2 O abatement technology “N” for nitric acid train “t” (percent of time that the abatement technology is operating). AF = Abate ment utilization factor of N 2 O abatement technology “N” for nitric acid train “t” (decimal fraction of annual production during 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 (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 Corrects a paragraph reference

### 34

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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: 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: V 98.223(g)(2) EN 2 O t = Annual N 2 O mass emissions from nitric acid production unit “t” according to this Equation V

– 3b (metric tons). EN 2 O t = Annual N 2 O mass emissions from nitric acid train “t” according to this Equation V

– 3b (metric tons). Clarifies terminology of the production units V 98.223(g)(2) EFN 2 O ,t = N 2 O emissions factor for unit “t” (lb N 2 O /ton nitric acid produced). EFN 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 = Destruct ion 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 98.22 3(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 (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 Corrects a paragraph reference

### 35

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  section), and the abatement utilization factor (determined in paragraph (e) of this section), according to Equation V

– 3c of this section: section), and the abatement utilization factor (determined in paragraph (e) of this section), according to Equation V

– 3c of this section: V 98.223(g)(3) EN 2 O t = Annual N 2 O mass emissions from nitric acid production unit “t” according to this Equation V

– 3c (metric tons). EN 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) EFN 2 O ,t = N 2 O emissions factor for unit “t” (lb N 2 O /ton nitric acid produced). EFN 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)(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 technology “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) EN 2 O t = Annual N 2 O mass emissions from nitric acid production unit “t” according to this Equation V

– 3d (metric tons). EN 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 9 8.223(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, 100 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 mo nthly 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 (e) You must determine the total monthly amount of nitric acid produced. You must also determine the mo nthly 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) Clarifies requirements.

### 36

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  paragraphs (c)(1) or (2) of this section. of this section. V 98.224(f) (f) You must determine the annual amount of nitric acid produced. You must also determine the annual amount of nitric acid produced w hile N 2 O abatement technology (located after the test point) is operating f or 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 amount of nitric acid produced. You must also determine the annual amount of nitric acid produced w hile N 2 O abatement technology is operating for each nitric acid train. These annual amounts are determined by summing the respective monthly nitric acid quantities 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. V 98.226(o) (None) (o) [Reserved] Corrects 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 s ent to each abatement technology) if Equation V

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

W 98.233 (a) Conv i = Conversion from standard cubic feet to metric tons CO 2 e; 0.0004 03 for CH 4 , and 0.00005262 for CO 2 . Conv i = Conversion from standard cubic feet to metric tons CO 2 e; 0.00047 9 for CH 4 , and 0.00005262 for CO 2 . Corrects a calculation term.

W 98.233 (c) Conv i = Conversion from standard cubic feet to metric tons CO 2 e; 0.0004 03 for CH 4 , and 0.00005262 for CO 2 . Conv i = Conversion from standard cubic feet to metric tons CO 2 e; 0.00047 9 for CH 4 , and 0.00005262 for CO 2 . Corrects a calculation term.

W 98.233 (v) GWP = Global warming potential, 1 for CO 2 , 21 for CH 4 , and 310 for N 2 O. GWP = Global warming potential, 1 for CO 2 , 25 for CH 4 , and 298 for N 2 O. Corrects a calculation term. X 98.242(b)(2) (2) If you comply with §98.243(c), report CO 2 , CH 4 , and N 2 O com

bustion 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 (General Stati onary 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 com

bustion 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 , including units th at are not part of the petrochemical process unit, are not to be reported under subpart C of this part. Determine the applicable Tier in subpart C of this part (General Stationary Fuel Combustion Sources) based on the maximum rated heat input capacity of the stationary combustion source. Yes See final pream ble text for explanation

X 98.243(b) (b) Continuous emission monitoring system (CEMS). Route all process vent emissions and (b) Continuous emission monitoring system (CEMS). Ro ute all process vent emissions and Yes See proposal preamble 19802 )

. Final rule corrects typo.

### 37

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  emissions from combustion of process off

- gas to one or more stacks and determi ne 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, ca lculate CH 4 and N20 emissions in accordance with subpart C of this part (use the Tier 3 methodology, 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 each flare, calculate CO 2 , CH 4 , and N 2 O emissions using the methodology specified in §98.253(b)(1) through (b)(3). emissions from stationary com bustion 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 (b) (3) of this section. (1) Determine CO 2 emis sions from each stack (except flare stacks) according to the Tier 4 Calculation 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, calculat e CH 4 and N 2 O emissions in accordance with subpart C of this part (use Equation 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 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 del ivered in lots, and if multiple deliveries of the same feedstock are received from the same supply source in a given calendar month, only one representative sample is required. Alternatively, you may use the results of analyses conducted by a fuel or feeds tock 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 sample of each feedstock and product at least once per month and determine the carbon content of ea ch sample according to the procedures of §98.244(b)(4). If multiple valid carbon content measurements are made during the monthly measurement period, average them arithmetically. However, if a particular liquid or solid feedstock is delivered in lots, and if multiple deliveries of the same feedstock are received from the same supply source in a given calendar month, only one representative sample is required. Alternatively, you may use the results of analyses conducted by a feedstock supplier, or product cu stomer, provided the sampling and analysis is conducted at least once per mo nth using any of the procedures specified in §98.244(b)(4). See proposal preamble 19802 )

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 analysis specified in paragraph (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, Yes See proposal preamble 19802 )

. Final rule corrects typo.

### 38

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  (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 periods of operation when off

specification product is produced. You must maintain records of any determination made in accordance with this paragraph (c)(4) along w ith all supporting data, calculations, and other information. You must reevaluate determinations made under this paragrap h (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 so that the average monthly c oncentration falls below99.5 percent, you are no longer permitted to use this alternative method. yo u may determine carbon content in accordance with paragraphs (c)(4)(i) through (c)(4) (iii) of this section. (i) Calculate the carbon content assuming 100 p ercent of that feedstock or product is the specific compound. (ii) M aintain records of any determination made in accordance with this paragraph (c)(4) along w ith all supporting data, calculations, and other information. (iii) 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 composition changes so that the aver age mo nthly concentration falls below99.5 percent, you are no longer permitted to use this alternative method. X 98.243(c)(5)(i ) 

#   Cg F CC MW MVC P CC MW

MVC gf i n gf i n f i n gp i n gp i n p i n i jork

n              

  

##  

, , ,

, , ,

* ( ) * ( ) ( ) * ( ) * ( )

1 1 12 Yes Harmonizing change revises parameters (MW f

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

from carbon (C ) in gaseous materials (kilograms/year, kg/yr)

. (F gf ) i,n = Volume of gaseous feedstock i introduced in mo nth "n" (standard cubic feet, scf ). (MW f ) i = Molecular w eight of gaseous feedstock i (kg/kg

- mole). (P gp ) i,n = volume of gaseous product i produced in mo nth "n" (scf). (MWp ) i,n = Molecular w e i ght of gaseo us 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 ) i,n = Volume or mass of gaseous feedstock i introduced in month "n" (scf or kg). If you measure mass, the term (MW f

) i ,n/MVC is replaced w ith "1". (MW f ) i,n = Molecular w eight 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 ,n/MVC is replaced with "1". (MWp ) i,n = Molecular we ight of gaseous product i in mo nth "n" (kg/kg

- mo le). See proposal preamble 19802 )

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

off

- gas, use the emission factors for "Petroleum" in (i) For all gaseous fuels that contain ethylene process off

- gas, use the emission factors for "Fuel Gas" in See proposal preamble 19802 )

### 39

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  Table C

–2 of subpart C of this part (General Stationary Fuel Combustion Sources). Table C

–2 of subpart C of this part (General Stationary Fuel Combustion Sources). X 98.244(b)(4) (4) Beginning January 1, 2010, use any applicable methods specified in paragraphs (b)(4)(i) through (b)(4)(xiv) of this section to determine the carbon content or composition of feedstocks and products and the average molecular weight of gaseous feedstocks and products. Calibrate instruments in accordance with paragraphs (b)( 4)(i) through (b)(4)(xvi), as applicable. ...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) Beginning January 1, 2010, use any applicable methods specified in paragraphs (b)(4)(i) through (b)(4)(xv) of this section to determine the carbon content or composition of feedstocks and products and the average molecular weight of gaseous feedstocks and products. Calibrate instruments in accordance with paragraphs (b)(4)(i) through (b)(4)(xv), of this section, as applicable.

... 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, by the supplier of a feedstock, or by a product customer. Yes Harmonizing change with 40 CFR 98.243(c)(3) and correction to reference

.

X 98.244(b)(4)( xiii) (xiii) The results of chr omatographic 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 proposal preamble 19802 )

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 feedstock or product, provided that the mass spectrometer is operated, maintaine d, and calibrated according to the manufacturer's instructions. See proposal preamble 19802 )

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

feedstock oils 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. 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 20 036, (202) 293

- 8020, http://www.ansi.org ), the American Gas Association (AGA, 400 North Capitol Street, See proposal preamble 19802 )

### 40

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 Board (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 mo nitoring and QA/QC for flares in accordance with §98.254 (b) through (e) for each flare gas flow meter, gas composition meter, and/or heating value monitor that you use to comply with § 98.253(b)(1) through (b)(3). You must implement all appli cable QA/QC requirements specified in this paragraph (c) beginning no later than January 1, 2015

. Yes See final preamble text for explanation

X 98.245 Introductory paragraph For missing feedstock flow rates, product flow rates, and carbon contents, use the same 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 same 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 procedure s in §98.255(b) and (c). See proposal preamble 19802 )

X 98.246(a)(6) (6) Name of each method 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); (ii) Description of each type of device (e.g., flo w meter, weighing device) used to determine flow or mass in accordance with § 98.244(b)(1) through (3). Yes See proposal preamble 19802 ). Final rule corrects typo.

### 41

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  (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 proposal preamble 19802 )

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) T he number of days during which off

specification product was produced i f the alternative to sampling and analysis specified in §98.243(c)(4) is used for a product, and , if applicable, the date of any process change that reduced the mo nthly average composit ion to less than 99.5 percent for each product or feedstock for which you comply with the alternative to sampling and analysis specified in § 98.243(c)(4)

. Yes See final pream ble text for explanation

X 98.246(a)(11) (11) If you determine carbon content or com position 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 the information listed in paragraphs (a)(11)(i) through (a)(11)(iii) of this section. Include the information in paragraph (a)(11)(i) of this section in each annual report. Include the information in paragraphs (a)(11)(ii) and (a)(11)(iii) of this section only in the first applicable annual report, and provide any changes to this information in subsequent annual reports. Corrects cross

- reference.

X 98.246(a)(11) (iii) (iii) An explanation of why an alternative to the

methods listed in §§98.244(b)(4)(i) through (xii) is needed. (iii) An explanation of why an alternative to the methods listed in §§98.244(b)(4)(i) through (xiv) is needed. Yes Corrects reference

### 42

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 the relevant information required under §98.36(c)(2) and (e)(2)(vi) for the Tier 4 calculation methodology. Sections 98.36(c)(2)( ii) and (c)(2)(ix) do not apply for the purposes of this subpart. Yes Clarifies CEMS reporting requirement to align more closely with procedures in e corrects cross
- reference. corrects typo.

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 (e)(2)(vi). Yes Clarifies CEMS reporting requirement to align more closely with procedures in e rule corrects typo. 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 units 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) For each CEMS mo nitoring 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 results from CO 2 directly emitted by the petrochemical process unit plus CO 2 generated by the combustion of off

- gas from the petrochemical process unit

. Yes See final pream ble 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 informati on 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 (5) For each CEMS mo nitoring 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 engineeri ng judgment of the fraction of the total CH 4 and N 2 O See proposal preamble 19802 )

### 43

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 combustio n units, expressed in metric 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 fuels, gallons for liquid fuels, and scf for gaseous fuels. (iv) The HHV (either default or annual average from measured data) used in Equation C

– 8 in §98.33(c) for each stationary combustion unit or group of combustion units (as ap plicable). emissions that is attributable to combustion of off

gas from the petrochemical process unit. (i)[Reserved] (ii)[Reserved] (iii)[Reserved] (iv)[Reserved]

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

gas. (6) [Reserved] See proposal preamble 19802 ) 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) thro ugh (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 yo u comply with the alternative methodology in §98.243(c)(4) for determining carbon content of feedstock or product. (3) A part of the monitoring plan required under §98.3(g)(5), record the estimated accuracy of (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. (3) As part of the mo nitoring plan required under §98.3(g)(5), record the estimated accuracy of measurement devices and the technical basis for Yes Corrects a reference and reduces recordkeeping requirements when the alternative methodology in 98.234 (c)(4) is used. corrects typo in 98.247(b)(3).

### 44

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  measurement devices and the technical basis fo r these estimates. these estimates. X 98.248 Product , as used in §98.243, means each of the following carbon

- containing outputs fr om 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 c arbon

- 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 be 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 the 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 proposal preamble 19802 )

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 recordkeeping 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, missing data procedures, reporting requirements, and reco rdkeeping requirements of subpart P of this part. Clarifies requirement

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 Stationary Fuel Combus tion 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 Stationary Fuel Combus tion Sources) (kg CH 4/MMBtu) See proposal preamble 19802 )

Y 98.253(b)(3) EmFN 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 proposal preamble 19802 )

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 monit or is operational to calculate the sour gas flow rate. If you do not have a continuous flow mo nitor 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 monitor 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 monitor 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 Clarifies requirement

### 45

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  calculations, company records, or similar estimates of volumetric sour gas flow. 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 carbon 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 sulfur recovery, or if you monitor gas composition for carbon content on a routin e basis, you must use the measured carbon 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. Yes Clarifies requirement c orrects typo.

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

- mo le C/kg

- mo le 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 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 off

- site for sulfur recovery (kg

- mo le C/kg

- mole gas); default = 0.20. See proposal pre amble 19802 )

Y 98.253(j) (j) For each process vent not covered in paragraphs (a) through (i) of this section that can reasonably be expected to contain greater than 2 percent by volume 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 section to calculate CH 4 emissions for catalytic reforming unit depressurization and purge vents wh en 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 process vent not covered in paragraphs (a) through (i) of this section that can reasonably be expected to contain greater than 2 percent by volume CO 2 or greater than 0.5 percent by volume of CH 4 or greater than 0.01 percent by volume (100 parts per million) of N 2 O , calculate GHG emissions using Equation Y

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

– 19 of this section to calculate CH 4 emissions for catalytic reforming unit depressurization and purge vents when methane is used as the purge gas, CH 4 emissions if you elected to use the method in paragraph (i)(1) of this section, and CO 2 and/or CH 4 emissions, as applicable, if you elected this method as an alternative to the methods Yes See proposal preamble 19802 ). Final rule corrects typo.

### 46

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  in paragraphs (f), (h), or (k) of this section. 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 o r 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) 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 Y

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

Y 98.253(m) (m) For storage tanks, except 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 s ection, 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 emissions 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 the applicable subpart (e.g., subpart C of this part in the case of a CO boiler). (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 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 the applicable subpart (e.g., subpart C of this part in the case of a CO boiler). Clarifies reporting requirements

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 proposal preamble 19802 ) 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 rec overy 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, 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)). See proposal preamble 19802 )

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 (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 See proposal preamble 19802 )

### 47

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  off

- site for sulfur recovery, expressed in metric tons. gas sent off

- site for sulfur recovery, expressed in metric tons. Y 98.256(h)(4) (4) If you use Equation Y

– 12 of this subpart, the annua l volumetric 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

- mo le gas). (4) If you use Equation Y

– 12 of this subpart, the annual 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 proposal preamble 19802 )

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 whether 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 wa s 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 mo le fraction of carbon in the tail gas (in kg

- mo le C/kg

- mo le 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 proposal preamble 19802 )

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 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 subpart C of this part (General Stationary Fuel Combustion Sources). (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 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 Combust ion Sources). Clarifies reporting requirements

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 proposal preamble 19802 ) 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 (4) For each set of coking drums that are the same dimensions: The number of coking drums in the set, the h eight 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 Corrects typographical error (CF4 to CH 4 )

### 48

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  vessel), and the mole fraction of methane in coking gas (in kg

- mole CF 4/kg

- mole gas, wet basis). vessel), and the mole fraction of methane in coking gas (in kg

- mole CH 4/kg

- mole gas, wet basis). 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 proposal preamble 19802 )

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 unstabilized 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 t anks 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 year (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)(i i) (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 batch of phosphate rock by origin i obtained during mo nth n (percent by weight, expressed as a decimal fraction). (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 batch of phosphate rock by origin i obtained during mo nth n (percent by weight, expressed as a decimal fraction). See proposal prea 19802 )

Z 98.264(a) (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 yo u 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 Ch emists (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 co nsensus standards organization, or yo u 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 Delete s outdated contact information

### 49

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  (AFPC) (P.O. Box 1645, Bartow , Florida 33831, (863) 534

– 9755, http://afpc.net, paul.mcafee@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 rep resentative sample. (AFPC). 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.

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

inorganic carb on 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 practice methods, including but not l imited 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 practice 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 origin), you must use the appropriate default factor provided in Table Z

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

assured values of inorganic carbon contents of phosphate rock of origin i from samples immediately preceding and imme diately following the missing 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 fa ctor 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 contents 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 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 calculations 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), yo u must use the appropriate default factor provided in Table Z

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

- assured data on ino rganic carbon contents or CO 2 contents of phosphate rock of origin i are available prior to the missing data incident, the substitute data value shall be the first Correction; clarifies the general requirement for missing data, removes a duplicate paragraph, clarifies the data element of inorganic carbon content may also be represented by corrects the e quation reference.

### 50

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  on inorganic carbon contents of phosphate rock of origin i are available prior to the missing data incident, the substitute data va lue shall be the first quality

- assured value for inorganic carbon contents for phosphate rock of origin i obtained after the missing data period. quality

- assured value for inorganic carbon contents or CO 2 contents for phosphate rock of or igin 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 (tons). (a) Annual phosphoric acid production, by origin of the phosphate rock (tons). Removes a reference to 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 proposal preamble 19802 ) Z 98.266(d) (d) Annual phosphate rock consumption from

mo nthly measurement records by origin, (as listed in Table Z

– 1 to this subpart) (tons). (d) Annual phosphate rock consumption from mo nthly 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 which 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, expressed 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 acid 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 phosphate rock (months). (8) Number of times missing data procedures were used to estimate phosphate rock consumption (mo nths), inorganic carbon contents of the phosphate rock (months), and CO 2 contents of the phosphate rock (months). Adds reporting requirement for missing data procedures

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

origin (as listed in Table Z

– 1 of this subpart) (tons). (a) Monthly mass of phosphate rock consumed by origin (tons). Removes a reference to Table Z 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 re ference to Table Z The reporting element could have a place of origin other than those listed in Table Z

- 1

### 51

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 proposal preamble 198 02 )

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) T otal annual production of unbleached virgin chemical 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 bleaching, through all virgin pulping lines. Do not include mechanical pulp or secondary fiber repulped for paper production in the virgin pulp production total. Yes See final pream ble text for explanation

AA Tables AA

- 1 & AA

- 2 See Tables AA

- 1 and AA

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

- 1 and AA

2 See proposal preamble 19802 ) 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 proposal preamble 19802 ) 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 section. 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 proposa l preamble 19802 )

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 (a) Calculate and report under this subpart the combined annual process CO 2 emissions by operating and maintaining CEMS according to the Harmonizing change with 98.283 introductory paragraph.

### 52

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  Methodology specified in §98.33(a)(4) and all associated requirements for Ti er 4 in subpart C of this part (General Stationary Fuel Combustion Sources). 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 Com bustion Sources). BB 98.283(b) (b) Calculate and report under this subpart the proce ss 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 productio n 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 None See proposal preamble 19802 )

BB 98.286(b) (b) If a CEMS is not used to measure process CO 2 emissions, you must report the information listed in this paragraph (b) for all furnaces combined: (b) If a CEMS is not used to measure process CO 2 emissions, you must report the information in paragraph (b)(1) through (b)(8) of this section for all sili con carbide process units or production furnaces combined: Correction for consistency with 40 CFR 98.282.

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 cylinders) or have the gas supplier measure it. If the gas suppl ier 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 cylinders returned to the gas supplier are consistently weigh ed 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 amount 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 proposal preamble 19802 )

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 capacity and is periodically recalibrated per the manufa cturer's specifications. All (2) Ensure that cylinders weighed for the beginning and end of year inventory measurements are weighed on a scale that is certified to be accu rate and precise to within 2 pounds of true weight and is periodically recalibrated per the manufacturer's specifications. All See proposal preamble 19802 )

### 53

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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. 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. 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 b oth 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 proposal preamble 19802 )

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 where 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 whe re coal bed gas is emitted, and those where the gas is sold, used onsite, or otherwise destroyed (including by flaring). See proposal preamble 19802 )

FF 98.322(b) (b) You must report CH 4 destruction from systems 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 proposal preamble 19802 )

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) Yo u 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 proposal preamble 19802 )

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 tem perature 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. MCF = Moisture correction factor for the measurement period, volumetric basis. Corrects subscript errors

### 54

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  = 1 w hen 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. = 1 w hen V and C are measured on a dry basis or if both are measured on a wet basis. = 1

- (f H2O ) 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. FF 98.323(a) (f H 2 O ) = Moisture content of the methane emitted during the measurement period, volumetric basis (cubic feet water per cubic feet emitted gas). (f H2O ) = Moisture content of the CH 4 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 proposal preamble 19802 )

FF 98.323(a)(2) (2) Values of V, C, T, P, and (f H2O ), if applicable must be based on measurements taken at l east 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 mo nitoring. (2) 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 continu ous measurements are taken, then use the average value over the time period of continuous mo nitoring. Corrects subscript errors ty pographical error.

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 meter is used and the meter automatically corrects for temperature and pressure, replace “520°R/Ti× Pi/1 atm” with “1”. V i = Measured volumetric flow rate for the days in the week when the degasification system is in operation at that monitoring point, base d on sampling or a flow

rate meter (acfm). If a flow rate 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”. Clarification of equation term

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

... (1) Values of V, C, T, P, and (f H2O ), if applicable

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

### 55

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 each point of offsite transport to a destr uction 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

– 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 destroy ed 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

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 mo nitoring point, or from a combination of the two options. Operators are allow ed flexibility for aggregating emissions from more than one ventilation well or shaft, as long as emissions from all are addressed, and the methodology for calculating total emissions documented. Monitor by (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 mo nitoring point, or from a combination of the two options. Operators are allow ed 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 Clarifies rule text.

### 56

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  one of the following options: following options:
FF 98.324(c)(2) (2) Collect weekly (once e ach 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 degas ification 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 emi ssions 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 th e measurement or collection. (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 co ncentration, 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 si te. Follow the sampling protocols for sampling of methane emissions from ventilation shafts, as described in §98.324(b)(1). You must record the date of sampling, flow, temperature, pressure, and moisture measurements, the methane concentration (percent), the bottle number of samples collected, and the location of the measurement or collection. Clarifies rule text.

FF 98.326(a) (a) Quarterly CH 4 liberated from each ventilation mo nitoring point ( CH 4 Vm), (metric tons CH 4 ). (a) Quarterly CH 4 liberated from each ventilation mo nitoring 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 mo nitoring), 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 repor 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 mo nitoring), used in Equation FF

– 3 of this subpart. (h) Wee kly 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 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 (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.

### 57

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  sampling data) (C). 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 concentration 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 correcti on factor, if Equation FF

– 9 was required. See proposal preamble 19802 )

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 , shaft, and vent hole, including paragraphs (r)(1) through (r)(3) of this section: (1) Indication of whether the well , shaft , or vent hole is monitored individually, or as part of a centralized mo nitoring point. Note which method (sampling or continuous monitoring) was used. (2) Start date and close date of each well , shaft , and vent hole

. (3) Number of days the well , shaft , or vent hole was in operation during the reporting year. See proposal preamble 19802 )

FF 98.326( t) No current requirement ( t) Mine Safety and Health Administration (MSHA) identification for this coal mine See proposal preamble 19802 ) HH 98.340(a) ( a) This source category applies to municipal solid wa ste (MSW) landfills that accepted waste on or after January 1, 1980. (a) This source category applies to municipal solid wa ste (MSW) landfills that accepted waste on or after January 1, 1980 , unless all three of the following conditions apply

. (1) The MSW landfill did not receive waste on or after January 1, 2013. (2) The MSW landfill had CH 4 generation as determined using Equation HH

- 5 and, if applicable, Equation HH

- 7 of this subpart of less than 1,190 metric tons of CH 4 in the 2013 reporting year. (3) The owner or operator of the MSW landfill was not required to submit an annual report under any requirement of this part in the in any reporting year prior to 2013

. Yes See final pream ble text for explanation

HH 98.343(a)(1) DOC = Degradable organic carbon from Table HH

- 1 DOC = Degradable organic carbon from Table HH

- 1 See proposal preamble

### 58

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  Equation HH

1 of this subpart or measurement data, if available

[fraction (metric tons C/metric ton waste)]. of this subpart [fraction (metric tons C/metric ton wa ste)]. 19802 ) HH 98.345 Equation HH

1, F = Fraction 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, corrected to 0 % oxygen); otherwise, use the default of 0.5. See proposal preamble 19802 )

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 mo nitoring 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 mo nitoring system and N=365 (or N = 366 for leap years). Fo r monthly sampling, as provided in paragraph (b)(2) of this section, use N= 1 2. See proposal preamble 19802 )

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 landfill gas each week and the cumulative volume of landfill gas each year that i s 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, mo isture 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 vol ume 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 te mp erature, pressure, or, if necessary, mo isture 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. Harmonizing change to accommodate monthly sampling of CH 4 concentration

HH 98.343(b)(2)(i i) (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 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 represent ative 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)(i ii)(A) (A) Determine the temperature and pressure in the

landfill gas that is collected and routed to a (A) Determine the temperature and pressure in the landfill gas that is collected and routed to a Harmonizing change to accommodate monthly sampling of

### 59

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 m easurements. 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 mo nth, there must be at least fourteen days between measurements. CH 4 concentration

HH 98.343(b)(2)(i ii)(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 mo isture 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 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. (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 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 proposal preamble 19802 ) HH 98.343(c )(3)(i) (Eq. HH

- 6) See proposal preamble 19802 )

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

- 6) (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 mo nitor volumetric flow

and CH 4 concentration of the recovered gas sent to one or multiple destruction devices, then N=1. Harmonizing with Equation HH

- 6 for 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 nth measurement location (metric tons). Harmonizing with Equation HH

- 6 for multiple measur ement locations and/or multiple destruction devices 

#      

Des t CH 

### f DE R R G

   1 4 

#        

 


### 

       



N

n n Dest n n N

n n CH 

### f

DE R R G

1 ,

1 

### 1 4

### 60

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 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 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 DEn as the arithmetic average of the DE values determined for each destruction device associated with that measurement location. Harmonizing with Equation 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 = Fracti on 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 floww as sent to the destruction device as measured at the n th measurement location

. If the gas is transported off

site for destruction, use f Dest,n= 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 device associated with that measurement location. Yes Harmonizing with Equation HH

- 6 for multiple measurement locations and/or multiple destruction devices and clarifies equation term accurately reflect operating hours of the gas collection system. preamble text.

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

- 7) See proposal preamble 19802 ) 

### OX)

- (1 f R CE 1 MG 1 n Rec, n 

###         

 

# 

 N

n

### 61

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  HH 98.343(c )(3)(ii) (Eq. HH

- 8) See proposal preamble 19802 )

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 mo nitor volumetric flow

and CH 4 concentration of the recovered gas sent to one or multiple destruction devices, then N=1. Harmonizing with 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 nth measurement location (metric tons CH 4 ). Harmonizing with 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 nth measurement location was operating (annual operating hours/8760 hours per year or annual operating hours / 8784 per year for a leap year). Harmonizing with Equation HH

- 8 for multiple measurement locations and/or multiple destruction devices HH 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 proposal preamble 19802 )

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 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 Harmonizing with Equation HH

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

#     Dest c 

# f DE R f CE R


 

      

  1 Re 

# R  

#         

 





### 
  

      



          

      

N

n n Des t n n N

n n N

n n

c n 

### f DE R R f R CE

1 , 1 1 , Re 

### 1 1

### 62

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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. 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 nth measurement location was operating during active gas flow calculated as the annual operating hours for the destruction device divided by the annual hours flow w as sent to the destruction device as measured at the nth measurement location

. If the gas is transported off

site for destruction, use f Dest,n = 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 device associated with that measurement location. Yes Harmonizing with 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. See final preamble text.

HH 98.344(e) (e) The ow ner or op erator 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 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 landf ills 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 pro perly operated, calibrated, and maintained according to the requirements specified in paragraph (b) of this section. You must either use a gas composition monitor that is also capable of measuring the O 2 concentration correcting for excess (infiltration) a ir or you must operate, maintain, and calibrate a second monitor capable of measuring the O 2 concentration on a dry basis according to the Harmonizing change to accommodate the correction to 0 percent o xygen for landfill gas

### 63

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  manufacturer'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 reporting 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, corrected to 0 % oxygen). C CH 4 = Measured CH 4 concentration in landfill gas (volume % , 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 concentration in landfill gas (volume % , 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 inclu de, 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 and the technical basis for these estimates shall be recor ded. Harmonizing chang 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 shall be the average daily waste disposal quantity for that day of the week as mea sured on the week before (c) For missing daily waste disposal quantity data for disposal in the reporting year, the substitute value shall be the average daily waste disposal quantity for that day of the week as meas ured on the week before See proposal preamble 19802 )

### 64

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  and week after the missing daily data. and week after the missing daily 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 capaci ty , 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 fr action of DOC dissimilated (DOC F ) values used in the calculations. See proposal preamble 19802 )

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 wa s determined based on measured values or the default value, and the methane correction factor used in the calculations. If an MCF other than the default o f 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 affe cted by aeration, the total number of hours during the year the aeration blower wa s operated, and other factors used as a basis for the selected MCF value. See proposal preamble 19802 )

### 65

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? 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 collection 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 in 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 considere d 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 indication of whether destruction occurs at the landfill facility, off

- site, or both. If destruction occurs at the landfill facility, also report for each measurement location the number of destruction devices associated with that measurement location and the annual operating hours and the destruction efficiency (percent) for each destruction device associated with that measurement location. Yes Clarification to provide landfills that use both off

- site and on destruction a clear and accurate reporting option.

HH 98.346(i)(6) (6) Annual quantity of recovered CH4 (metric tons CH4) calculated using Equation HH

–4 of this subpart. (6) Annual quantity of recovered CH 4 (metric tons CH 4 ) calculated using Equation HH

–4 of this subpart for each measurement location Yes Clarifies a reporting requirement See final preamble text

### 66

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  HH 98.346(i)(7) (7) A description of the gas collection system (manufacturer, capacity, and num ber of wells), the surface area (square meters) and estimated waste depth (meters) for each area specified in Table HH

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

– 3 to this subpart, the estimated gas collection system efficiency for landfills with th is gas collection system, the annual operating hours of the gas collection system for each measurement location, and an indication of whether passive vents and/or passive flares (vents or flares that are not considered part of the gas collection system as defined in §98.6) are present at the landfill. Yes Clarifies a reporting requirement See final preamble text

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 CH 4 , and the oxidation fraction used in the calculation Harmonizes reporting requirements with calculation method.

HH 98.346(i)(10) (10) Methane generation corrected for oxidation calculated using Equation HH

- 7 of this subpart, reported in metric tons CH4

. (10) Methane generation corrected for oxidation calculated using Equation HH

- 7 of this subpart, reported in metric tons CH4, and the oxi dation fraction used in the calculation Harmonizes reporting requirements with calculation method.

HH 98.346(i)(11) (11) Methane generation corrected for oxidation calculated using Equation HH

- 6 of this subpart, reported in metric tons CH4

. (11) Methane emissions 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) (12) Methane generation corrected for oxidation calculated using Equation HH

- 8 of this subpart, reported in metric tons CH4

. (12) Methane emissions calculated using Equation HH

- 8 of this subpart, reported in metric tons CH4, and the oxidation fraction used in the calculation Harmonizes report with calculation method.

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 Add definition to clarify meaning of term as used in the rule.

### 67

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  to determine its capacity, the calculation must include a site

- spec ific density. 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 methods, 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 te rm as used in the rule.

HH Table HH

- 1 Table HH

- 1 See Appendix A for changes to Table HH

- 1 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 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 Yes See final 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 reflect 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 reflect 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 each quantity measurement s tandard method or other industry standard practice used. For natural gas liquids, quantity shall reflect the individual components of the product. (1) [Reserved.] See proposal preamble 19802 )

LL 98.386(a)(4) (4) Each standard method or other industry standard (4) Each standard method or other industry standard Harmonizing change with 40 CFR

### 68

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  practice used to measure each quantity reported in paragraph (a)(1) of this section. practice used to measure each quantity reported in paragraph (a)(2) of this section. 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 quanti ty

measurement standard method or other industry standard 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 proposal preamble 19802 )

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 p er metric ton of product. Clarifies units of reporting requirement LL 98.386(a)(12) (12) For every non

- solid product reported in paragraph (a)(6) of this section for which Calculation Methodology 2 of subpart MM of this part was used to determine an emissions factor, report: (12) For every non

- solid product reported in paragraph (a)(6) of this section for which Calculation Method 2 of subpart MM of this part was used to determine an emissions factor, report: Harmonizing change with 98.393(f)( 2).

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 proposal preamble 19802 )

LL 98.386(a)(1 4 ) (14) 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 total annual quantity in metric tons or barrels. (14) For each specific ty pe 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. 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 reference

### 69

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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, calculated 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 section, calculated according to §98.393(c). Harmonizing change with 40 CFR 98.386(a)(13) and corrects reference

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 proposal preamble 19802 )

LL 98.38 6(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 98.386 (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 proposal preamble 19802 )

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 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(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 fe edstock. 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, im porters, and exporters must meet the reporting (3) For a product that is produced, imported, or exported that is a blended product, producers, im porters, and exporters must meet the reporting Harmonizing change with 40 CFR 98.386(a)(1), (b)(1), and (c )(1)

### 70

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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. requirements of paragraphs (a)(6), (b)(2), and (c)(2) of this section, as applicable, by reflecting the individual components of the blended product. MM 98.393(a)(1) Producti = Annual volume of product "i" produced, im ported, or exported by the reporting party (barrels). For refiners, this volume only includes products ex refinery gate, and excludes products that entered the refinery but are not r e ported under 98.396(a)(1). For natural gas liquids, volumes shall reflect the individual components of the product as listed in Table MM

- 1 to subpart MM. Producti = Annual volume of product "i" produced, im ported, or exported by the reporting party (barrels). For refiners, this volume only includes products ex refinery gate, and excludes products that 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 l isted in Table MM

- 1 to subpart MM. Updated reference to harmonize with changes to 98.396(a)(1)

MM 98.393(a)(2) Producti = Annual mass of product "i" produced, im ported, or exported by the reporting party (metric tons). For refiners, this mass only inc ludes products ex refinery gate. Producti = Annual mass of product "i" produced, im ported, 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). See proposal preamble 19802 )

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 place 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 assoc iated 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 emissi on 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 biomass, shall be determined as follows: See proposal preamble 19802 )

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 (3) The annual quantity of crude oil received shall be determined according to one of the following See proposal preamble 19802 )

### 71

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  following methods. You may use an appropriate standard method published by a consensus - based standards organization or you may use an industry standard practice. methods. You may use an appropriate standard method published by a con sensus - based standards organization or you may use an industry standard practice. MM 98.394(b) (3) (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 information from com

pany 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 proposal preamble 19802 )

MM 98.394(c) (c) Procedures for Calculation Methodology 2 of this subpart. (c) Procedures 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

. None See proposal preamble 19802 ) 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 gas liquids, types of bioma ss, feedstocks, or crude oil during any period (e.g., if a meter malfunctions), the following missing data procedures shall be used: See proposal preamble 19802 )

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 year. Clarifies metho d

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

- assured values of API gravity or sulfur content i n the batch preceding None See proposal preamble 19802 )

### 72

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 individual components of the product. (1) [Reserved] See proposal preamble 19802 )

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) [Reserved] Yes See final preamble explanation 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 the 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 proposal preamble 19802 )

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) [Reserved] Yes See final preamble explanation 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 ii) (iii) The carbon share test results in percentmass. (iii) The carbon share test results in percent mass. Corrects typographical error

### 73

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 feedstock 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 ology2 of this subpart was used to determine an emissions factor, report: (11) For every petroleum product and natural gas liquid 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 percentmass. (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 measureme nt standard method or other industry standard practice used. (13) [Reserved] See proposal preamble 19802 )

MM 98.396(a)(15) (15) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(13) of this section. (15) [Reserved] Yes See final preamble text for explanation 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 change 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 refinery. (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 cru de oil that enters the refinery, report the annual quantity in barrels. See proposal preamble 19802 )

### 74

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? 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 o f 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 proposal preamble 19802 )

MM 98.396(a)(22) (22) Volume of crude 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 injecte d into a crude oil supply or reservoir. See proposal preamble 19802 )

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 in 40 CFR 98.3 98, 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). None 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 o ther industry standard practice used. For natural gas liquids, quantity shall reflect the individual components of the product. (1) [Reserved] See proposal preamble 19802 )

### 75

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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. Reporting is not l imited to those components listed in Table MM

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) [Reserved] Yes See final preamble text for explanation
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 method

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 proposal preamble 19802 )

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) [Reserved] Yes See final preamble text for explanation

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 (6) For each non

- solid product reported in paragraph Clarifies method

### 76

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  (c)(2) of this section for which Calculation Methodology 2 of this subpart used was used to determine an emissions factor, report: (c)(2) of this section f or which Calculation Method 2 of this subpart used was used to determine an emissions factor, report: 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 paragraph (a)(2) of this section by reflecting the individual components of the blended non

- crude feedstock. Harmonizing change with 40 CFR 9 8.396 (a)(1)

MM 98.396(d)(3) (3) For a product that is produced, imported, or exported that is a blended product, refiners, im porters, 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, refiners, im porters, and exporters must meet the reporting requirements of par agraphs (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 98.396 (a)(1), (b)(1), and (c )(1)

MM 98.397(b) (b) Reporters shall maintain records to supp ort 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 petr oleum products, natural gas liquids, 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 initial 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 number 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 maintained 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) 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 Method 2. Clarifies method

### 77

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 proposal preamble 19802 )

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 differentiated product. Generally, such liquids consist of ethane, propane, butanes, or pentanes plus. See proposal preamble 19802 )

MM 98.398 Batch means either a volume of crude oil that enters a refinery or the components of such volume (e.g., the volumes 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 are kno wn 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) See proposal preamble 19802 )

MM Table MM

- 1 Table MM

- 1 See Appendix A for changes to Table MM

- 1 See proposal preamble 19802 ) NN 98.400(a) (a) Natural gas liquids fractionators are installations that fractionate natural gas liquids (NGLs) into their (a) Natural gas liquids fractionators are installations that fractionate natural gas liquids (NGLs) into their Clarifies rule text.

### 78

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  consitutent liquid products (ethane, propane, normal butane, isobutane or pentanes plus) for supply to dow nstream facilities. constituent liquid products or mixtures of products (ethane, propane, normal butane, isobutane or pentanes plus) for s upply to downstream facilities. 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 distributi on pipelines, not interstate pipelines 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 in dependent municipally

- owned distribution systems. LDCs do not include pipelines (both interstate and intrastate) delivering natural gas directly to major industrial users and farm taps upstream of the local distribution company inlet. See proposal preambl 19802 )

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 dow nstream 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 dow nstream 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 typographical 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 large end

- users, 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. A large end

- user means any end

- user facility receiving greater than or equal to 460,000 Mscf of natural gas per year. If the LDC does not know the total quantity of gas delivered to the end

- user facility based on readily available information in the LDCs possession, then large e nd

user means any single meter at an end

- user facility to which the LDC delivers equal to or greater than 460,000 Mscf per year. Yes See final pream ble text for explanation

NN 98.403(b)(2)(i i) CO 2 k = Annual CO 2 mass emissions that would

result from the combustion or oxidation of natural CO 2 k = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural Yes Clarifies rule text. revised to replace the term “end

### 79

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  gas received by end

- users that receive a supply equal to or greater than 460,000 Mscf per year (metric tons). gas delivered to each large end

- user k, as defined in paragraph (b)(2)(i) of this section (metric tons). user” with “large end

NN 98.403(b)(2)(i i) Fuel = Total annual volume of natural gas supplied

(Mscf per year). Fuel = Total annual volume of natural gas supplied to each large end

- user k, as defined in paragraph (b)(2)(i) of this section (Mscf per year). Yes Clarifies the definition of the equation term

“Fuel” in Equation NN

- 4” . The input for the total annual volume of natural gas must be the total annual volume of natural gas supplied to the end if known. Final rule is revised to replace the term “end “large end

- user”. 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 Equation 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 ma ss emissions that would result from the combustion or oxidation of the net natural gas that is liquefied and/or stored and not used for deliveries by the LDC within the reported year (metric tons). Fuel1 = Total 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 by (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 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 ma ss emi ssions 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 added 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 Harmonize with changes to equations

- see proposal ( 77 FR 19802 ) for a complete explanation of the changes.

### 80

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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). 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). NN 98.403(b)(3)(i i) (None) (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 production, received as a liquid and vapori zed 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 emission factor may be used, provided it is developed using methods outlined in §98.404. CO 2 n = Fuel z * EF z (Eq. NN

- 5b) Where: CO 2 n = Annual CO 2 ma ss 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 received that was not otherwise accounted for by Equation NN

- 1 or NN

- 2 of this section (natural gas from produce rs and natural gas processing plants from local production, or natural gas that was received as a liquid, vaporized and delivered, and any other source that bypassed the city gate) (Mscf per year). EF z = Fuel

- specific CO 2 emission factor (MT CO 2 /Mscf). Harmonize with changes to equations

. See proposal ( 77 FR 19802 ) for a complete description of the changes.

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. (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 Yes Harmonize with changes to equations

- see proposal ( 77 FR 19802 ) for a complete explanation . Final rule revises text

### 81

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  CO 2 = Sum ( CO 2 i )

- Sum( CO 2 j )

- Sum( CO 2 k)

- Sum( CO 2 l ) Where: CO 2 = Annual CO 2 ma ss emissions that would result 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 ma ss emissions that would result from the combustion or oxidation o f natural gas delivered to transmission 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 calculated in paragraph (b)(1) of this section (metric tons). CO 2 k = Annual CO 2 ma ss 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 4 60,000 Mscf per year as calculated in paragraph (b)(2) of this section (metric tons). CO 2 l = Annual CO 2 ma ss 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 delive ries within the reported year as calculated in paragraph (b)(3) of this section (metric tons). 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) Where CO 2 = Annual CO 2 ma ss 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 ma ss emissions that would result from the combustion 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 ma ss emissions that would result from the combustion or oxidation of natural gas delivered to transmission pipelines or other LDCs as calculated in paragraph (b)(1) of this section (metric tons). CO 2 k = Annual CO 2 ma ss emissions that would result from the combustion or oxidation of natural gas delivered to each large end

- user as calculated in paragraph (b)(2) of this section (metric tons). CO 2 l = Annual CO 2 ma ss emissions that would result from the combustion or ox idation of the net change in natural gas stored by the LDC within the reported year as calculated in paragraph (b)(3)(i) of this section (metric tons). CO 2 n = Annual CO 2 ma ss emissions that would result from the combustion or oxidation of natural gas that was received by the LDC directly from sources bypassing the city gate, and is not otherwise accounted for in Equation NN

- 1 or NN

- 2 of this section, as calculated in paragraph (b)(3)(ii) of this section (metric tons). to add term “large end user”.

NN 98.403( c)(2) (2) Calculate the total CO 2 equivalent emissions that wo uld result from the combust ion 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 wo uld 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 ma ss emissions that would result CO 2 = Annual CO 2 ma ss emissions that would result Clarifies calculation result

### 82

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  from the combustion or oxidation of fractionated NGLs delivered to customers or on behalf of customers (metric tons). from the combustion or oxidation of fractionated NGLs delivered to customers or on behalf of customers less the quantity received from other fractionato rs (metric tons). 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 the 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 particul ar 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 large end

- user’s meter(s). Where a large end

- user is known to have mo re than one meter located at their facility, based on readily available information in the LDCs possession, 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 large end

- user. Otherwise, the reporter shall consider the total annual volume delivered through each single meter at a single particular location to be the volume delivered to an individual large end

- user. Yes Clarifies rule text. revised to replace the term “end user” with “large end

NN 98.404(a)(8) (8) An LDC using Equation NN

– 5 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. (ii) Fuel 2 shall be measured at the meters used for measuring on

- system storage withdrawals and/or LNG vapori zation injection. If Fuel 2 is from a source other than storage, the appropriate meter shall be used to measure the quantity. (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. (ii) Fuel 2 shall be measured at the meters used for measuring on

- system storage withdrawals and/or LNG vaporization injection. (iii) Fuel z shall be measured using established business practices. Harmonize with changes to equations

. S ee proposal ( 77 FR 19802 ) for a complete explanation

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 following standard indu stry 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.

### 83

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 calculate 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

. S ee proposal ( 77 FR 19802 ) 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 according 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 method publis hed by a consensus based standards organization or according to the equipment manufacturer's directions. Harmonize with changes to equations

- see proposal ( 77 FR 19802 ) for a complete explanation

NN 98.404(d)(2) (2) Equipment used to measure quantities 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 this subpart shall be recalibrated at the frequency specified by the standard method used or by the manufacturer's directions. Harmonize with changes to equations

. S ee proposal ( 77 FR 19802 ) 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 98.405( c)(3) (3) Whenever a NGL fractionator cannot follow the quality assurance procedures for developing a reporter
- specific HHV, as specified in §98.404, 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. (3) [Reserved] Deleted duplicate requirement

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 proposal preamble 19802 )

NN 98.406(a)(7) (7) Annual CO 2 mass emissions (metric tons) that wo uld 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 tons) that wo uld 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 report er shall report the value Corrects regulatory text resolves potential for negative calculation result due to rounding of emission factors.

### 84

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  as zero. 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 liqu e fied 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) produce d 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) withdrawn from storage for delivery on the distribution system (Fuel 2 in Equation NN

- 5a). Harmonize reporting requirements with calculation changes preamble rationale for a complete explanation NN 98.406(b)(4) (4) Annua l 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 need for this reporting 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 bypassed the city gate ( Fuel z in Equation NN

- 5b). Harmonize reporting requirements with calculation changes 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 registering 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 large end

- user as defined in § 98.403(b)(2)(i) of this section

. Yes See final pream ble text for explanation 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 (m etric 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 the value as zero. Corrects typographical error 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 paragraph (b)(7) of this section. (12) The customer name, address, and meter number of each large end

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

- user ’s facility , or the quantity delivered to a specific meter located at the facility

. Yes Clarifies rule text. revised to replace the term “end user” with “large end

NN 98.407 98.407 Records that must be retained. 98.407 Records that must be retained

. Corrects requirement.

### 85

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  Introductory Paragraph In addition to the information required by §98.3(g),

each annual report must contain the following information: In addition to the information required by §98.3(g), the reporter shall retain the following records: NN 98.408

- Table NN

- 1 Table NN

– 1 to Subpart HH of Part 98

—Default

Factors for Calculation Methodology 1 of This Subpart See Appen dix A for changes to Table NN

- 1 Corrects title of table harmonizes values with Table C 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 harmonizes values with Table C PP 98.423(a)(3)(i ) (3) To aggregate data, use either Equation PP

–3a or

PP

– 3b in this paragraph, as appropriate. (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 Equation 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 proposal preamble 19802 )

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. (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. (4) Report 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. (ii) Quarterly density of CO 2 in metric tons per standard cubic meter if you report the concentratio n of the CO 2 stream in paragraph (b)(3) of this section in volume percent. Clarifies reporting requirement

PP 98.426(f)(10) (10) Enhanced oil and natural gas recovery (10) Injection of carbon dioxide for enhanced oil and natural gas recovery that is covered by subpart UU of this part. See proposal preamble 19802 ) 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 proposal preamble 19802 ) QQ 98.433(a) S t = Mass of fluorinated GHG per unit of equipment ty pe 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 ty pe 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 proposal preamble 19802 )
QQ 98.433(b) 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 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 C larifies equation term.

### 86

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  cubic foot). 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 ac curately 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 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 quantitie s 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 fluori nated GHG contained in the foam, the mass of the fluorinated GHG contained in the foam in each piece of equipment , and the number of pieces of equipment im ported with each unique combination of mass and identity of fluorinated GHG within the closed

- cell fo ams. See proposal preamble 19802 )

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 of closed

- cell foam with a unique combination of fluorinated GHG density and identity. (4) For closed cell

- foams that are not imported inside of equipment, the identity of the fluorinated GH G 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 of closed

- cell foam with a unique combination of fluorinated GHG density and identity. See proposal p reamble 19802 )

QQ 98.436(a)(5) (5) Dates on which the pre

- charged equipment or closed

- cell foams were imported. (5) [Reserved] See proposal preamble 19802 ) 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 GHG s in CO2e contained in the foam in each piece of equipment and the number of pieces of equipment im ported for each equipment type. See proposal preamble 19802 )

QQ 98.436(a)(6)(i ii) (iii) For closed

- cell foams that are not imported

inside of appliances, the mass in CO 2 e of the fluorinated GHGs in the foam (kg CO 2 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 imported inside of equipment, the density in CO 2 e of the fluorinated GHGs in the foam (kg CO 2 e/cubic foot) and the volume of foam imported (cubic feet) for each type of closed

- cell foam. See proposal preamble 19802 )

QQ 98.436(a)(6)(i (iv) Dates on which the closed

- cell foams were (iv) [Reserved] See proposal preamble

### 87

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  v) im

ported. 19802 ) 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 GHG 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 flu orinated 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 identity of fluorinated GH G within the closed

- cell foams. See proposal preamble 19802 )

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 equipment, 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 ide ntity. See proposal preamble 19802 )

QQ 98.436(b)(5) (5) Dates on which the pre

- charged equipment or closed

- cell foams were exported. (5) [Reserved] See proposal preamble 19802 ) QQ 98.436(b)(6)(i i) (ii) For closed

- cell foams that are exported inside of

appliances, the mass of the fluorinated GHGs in CO 2 e 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 exported inside of equipment, the mass of the fluorinated GHGs in CO 2 e contained in the foam in each piece of equipment and the number of pieces of equipment im ported for each equipment type. See proposal preamble 19802 )

QQ 98.436(b)(6)(i ii) (iii) For closed

- cell foams that are not exported

inside of appliances, the mass in CO 2 e of the fluorinated GHGs in the foam (kg CO 2 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 CO 2 e of the fluorinated GHGs in the foam (kg CO 2 e/cubic foot) and the volume of foam imported (cubic feet) for each type of closed

- cell foam. See proposal preamble 19802 )

QQ 98.436(b)(6)i v) (6)(iv) Dates on which the closed

- cell f oams were exported. (6)(iv) [Reserved] See proposal preamble 19802 ) 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 Closed

- cell foam means any foam product, 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 continuou s and discontinuous panel foam, PU one component foam, PU spray foam, See proposal preamble 19802 )

### 88

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  polystyrene (XPS) boardstock foam, and XPS sheet foam. Packaging foam means foam used exclusively during shipment or storage to temporarily enclose items. extruded polystyrene (XPS) boardstock foam, and XPS sheet foam. Packaging foam means foam used exclusively during shipment or storage to tem porarily enclose items. QQ 98.438 Pre

- charged electrical equipment component 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 e quipment 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 proposal preamble 19802 )

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 bein g injected into your well in quarter p (standard cubic meters) 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 your approved 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(d)(5). (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 your approv ed 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 r einjection 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). Corrects reference.

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 CO 2 FI = Tota l 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 Harmonizing change to conform the variable definitions in RR RR

- 12

### 89

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  the injection wellhead. the injection wellhead, for which a calculation procedure is provid ed in subpart W of this part. 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 proposal preamble 19802 ) SS 98.453(d) (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 ne w equipment or cylinders using a flowmeter or by weighing containers before and after gas from containers is used to f ill 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 ne w 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 proposal preamble 19802 )

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. Calculate the partial shipping charge by multiplyi ng 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 capacities of a representative sample of each make and mo del and take the average for each make and model as specified at §98.454(f). (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 measuring the nameplate capacities of a representati ve sample of each make and model and calculating the mean value 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. See proposal preamble 19802 )

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 combination and the associated valve fitting sizes and hose (m) The values for EF Ci of Equation SS

- 5 of this subpart for each hose and valve combination and the Clarifies a reporting requirement.

### 90

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  diameters. associated valve fitting sizes and hose diame ters. 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 equa l 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 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. (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 conditions. (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 r equired in §98. 45 3(h), report the number of samples and the upper and lower bounds on the 95 percent 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 biodegradation 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) Eq. TT

- 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 98.464(b)(4)(i), use a default value of 1.0. See proposal preamble 19802 )

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 for the current reporting year; otherwise, use the default value of 0.5. F = Fraction by vol ume 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 ty pographical error in Equation TT

- 4b. The summation should start with "n=1" rather than "n

- 1" 

# 

 NYrData

n n meas 

# W 1 , 

# 

 NYr Data

n n meas 

# W 1 ,

### 91

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change** 
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 proposal preamble 19802 ) 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 concentrati on 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 concentration and/or a wa ste stream
- specif

ic 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 proposal preamble 19802 )

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 waste stream sample in Year X as determi ned in paragraph (b)(4)(i)(C) of this 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 control 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). 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 degradation test in Year X (mg, wet bas is). See proposal preamble 19802 )

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 wa s historically managed in the landfill but was not (c) For each waste stream that was historically managed in the landfill for which you choose to determine volatile solids concentration and/or a wa ste stream
- specific DOC X , you must determine Yes See final pream ble text for explanation 

###                        


co ntrol co ntrol

x sample x sample
F X 

### MC

MC D M MC D DOC DOC

, , 

### 1

x sample x sam ple X 

# M MC D Do c

, , 

# 

### 92

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  received during the first reporting year, you must de termine 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. 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. TT 98.464(c)(1) (1) If you can identify a similar waste stream to the wa ste 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 wa ste stream to the wa ste 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. S ee proposal preamble 19802 )

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 s tream using process knowledge. You must document the basis for volatile solids concentration as determined through process knowledge. (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 or DOC X of the historically managed wa ste stream using process knowledge. You must document the basis for the volatile solids concentration or DOC X value as determined through process knowledge. See proposal preamble 19802 )

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 (i ncluding “Other Industrial Solid Waste (not otherwise listed)” and “Inerts ”) for which Equation TT

– 1 of this subpart is used to calculate modeled CH 4 generation. See proposal preamble 19802 )

TT 98.466(b)(5) (None) (5) For each waste stream, the decay rate (k) value used in the calculations. See proposal preamble 19802 ) 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. (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). (c) Report the followi ng historical waste information : (1) [Reserved] (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 produc tion data are both available. (ii) The year, the waste disposal quantity and See proposal preamble 19802 )

### 93

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  (iii) The average waste disp osal factor (WDF) calculated for the waste stream. production quantity for each year used in Equation TT

–2 of this subpart to calculate the average waste disposal factor (WDF). (iii) The average waste disposal factor (WDF) calculated for the waste stream.
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, provi de: (i) The value of landfill capacity (LFC). (ii) YrData. (iii) YrOpen. See proposal preamble 19802 )

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 disposal quantities are available from company record or from Equation TT

- 3 of this part; (iii) YrLast; (iv) YrOpen; and (v) NYrData. See proposal preamble 19802 )

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 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 wa s determined by a 60

- day anaerobic biodegradation test, specify the test method used. (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 wa s the default value from Table TT

– 1 to this 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 wa s determined by a 60

- day anaerobic biodegradation test, specify the test method used. See proposal preamble 19802 )

TT 98.466(h) (h) For landfills with gas collection systems, in addition t o the reporting requirements in paragraphs (a) through (f) of this section, you must report (h) For landfills with gas collection systems, in addition to the reporting requirements in paragraphs (a) through (f) of this section, pr ovide: See proposal preamble 19802 )

### 94

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  according to §98.346(i). (1) The annual methane generation, adjusted for oxidation, calculated using Equation TT

- 6 of this subpart, reported in metric tons CH 4 . (2) The oxidation factor used in Equation TT

- 6 of this subpart

. (3) All information required under 40 CFR 98.346(i)(1) through (i)(7) and 40 CFR 98.346(i)(9) through (i)(12). TT 98.467 In addition to the information required by §98.3(g), yo u must retain the calibration records for all mo nitoring 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), yo u must retain the calibration records for all mo nitoring 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 was te stream
- specific DOC X values for use in Equation TT

- 1 of this subpart. See proposal preamble 19802 )

TT 98.468 None Industrial s ludge means the residual, semi

- solid material left from industrial wastewater treatment processes or wet air pollution control devices (e.g., wet scrubbers). Industrial sludge includes underflow material collected in primary or secondary clarifiers, settling basins, or precipitation tanks as well as dredged materials from wastewater tanks or im poundments. Industrial slu dge also includes the semi

- solid materials remaining after these materials are dewatered via a belt process, centrifuge, or similar dewatering process. Yes See final preamble text for explanation

TT Table TT

- 1 Table TT

- 1 See Appendix A for changes to Table TT

- 1 See proposal preamble 19802 ) 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.

### 95

**Subpart Requirement**  **Current Rule Text Final**  **Rule Text Revised from**  **Proposal? Rationale for Change**  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 proposal preamble 19802 ) UU 98.476(e) (None) (e) Report the following: (1) Whether the facility received a Research and Development project exemption from reporting under 40 CFR p art 98 , subpart RR , for this reporting year. If you received an exemption, report the start and end dates of the exemptio n 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 o f 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 geolog ic 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 paragraphs (e)(1) through (4) of this section. If you injected CO 2 for another purpose, report the purpose of the injection. See proposal preamble 19802 )

# Attachment A

**1. Am**  **endments 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 

### 25 a 

### Nitrous oxide 10024

– 97

–2 N 2 

### O 298 a 

### HFC

–23 75

–46

– 7 CHF 3 

### 14,800 a 

### HFC

– 32 75

– 10

– 5 CH 2 

### F 2 

### 675 a 

### HFC

–41 593

– 53

– 3 CH 3 

### F 92 a 

### HFC

– 125 354

– 33

– 6 C 2 

### HF 5 

### 3,500 a 

### HFC

– 134 359

– 35

– 3 C 2 

### H 2 

### F 4 

### 1, 100 a 

### HFC

– 134a 811

– 97

–2 CH 2 

### FCF 3 

### 1, 430 a 

### HFC

– 143 430

– 66

– 0 C 2 

### H 3 

### F 3 

### 353 a 

### HFC

– 143a 420

–46

–2 C 2 

### H 3 

### F 3 

### 4,470 a 

### HFC

– 152 624

– 72

– 6 CH 2 

### FCH 2 

### F 53 HFC

– 152a 75

– 37

– 6 CH 3 

### CHF 2 

### 124 a 

### HFC

– 161 353

– 36

– 6 CH 3 

### CH 2 

### F 12 HFC

–227ea 431

– 89

– 0 C 3 

### HF 7 

### 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 a 

### HFC

–245ca 679

– 86

– 7 C 3 

### H 3 

### F 5 

### 693 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, 640 a 

### Sulfur hexafluoride 2551

– 62

–4 SF 6 

### 22,800 a 

### Trifluorometh ylsulphur 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 

### 7,390 a 

### PFC

– 116 (Perfluoroethane) 76

– 16

–4 C 2 

### F 6 

### 12,200 a 

### PFC

–218 (Perfluoropropane) 76

– 19

– 7 C 3 

### F 8 

### 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 

### 8,860 a 

### Perfluorocyclobutane 115

–25

– 3 C

- C 4 

### F 8 

### 10,300 a 

### PFC

–4

– 1

– 12 (Perfluoropentane) 678

–26

–2 C 5 

### F 12 

### 9,160 a 

### PFC

– 5

– 1

– 14 (Perfluorohexane) 355

–42

– 0 C 6 

### F 14 

### 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 (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 (Octafluorotetrameth ylene)h ydrox ym eth ylgroup NA X

- (CF 2 

### ) 4 

### CH(OH)

- X 73
HFE

– 347mm y1 22052

– 84

–2 CH 3 

### OCF(CF 3 

### ) 2 

### 343 Bis(trifluorometh yl )

- 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

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. NA

– Not available

### 3 **. 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 Equat**  **ions 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. 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.

### 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)**  FF 98.326(f) Only quarterl y volumetric flow rate. FF 98.326(g) Only quarterl y CH 4 

### concentration. FF 98.326(h) Only weekl y volumetric flow used to calculate CH 4 

### liberated from degasification s ys tems. 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 Equation 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 determined using the methods in §98.343(a)(3)(ii), population served b y 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, 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 destruction device s located at the landfill facility , and the destruction efficiency for the destruction device s associated with that measurement location. HH 98.346(i)(6 ) All. HH 98.346(i)(7) Only surface area specified in Table HH

– 3, estimated gas collection sy stem efficiency , and annual operating hours of the gas collection sy stem for each measurement location

.

### 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)**  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. 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 estimate

### 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)**  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(b)(3) Only fraction of CH 4 

### in landfill gas TT 98.466(b)(4) Only the methane correction factor (MCF) value used in the calculations 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)(2) All. TT 98.466(d)(3) Only degradable organic carbon (DOCx) value for each waste stream used in calculations. TT 98.466(e)(2) Only surface area (in square meters) at the start of the reporting ye ar for the landfill sections that contain waste and that are associated with the selected cover typ e (for facilities using a landfill gas collection s ys tem). TT 98.466(f) All.

4. **Am endments to Table A** 
**- 7**  **to 40 CFR part 98, subpart A:**
**Table A –**  **7 to Subpart A of Part 98**  **— Data Elements That Are Inputs**  **to Emission Equations and for Which the Reporting Deadline Is March 31, 2015** 

**Subpart Rule citation** 

**(40 CFR part 98) Specific data elements for which reporting date is March 31,** 

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  A 98.3(d)(3)(v) All. C 98.36(b)(9)(iii) Only estimate of the heat input.

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  C 98.36(c)(2)(ix) Only estimate of the heat input from each type of fuel listed in Table C

–2. C 98.36(e)(2)(i) All. C 98.36(e)(2)(ii)(A) All. C 98.36(e)(2)(ii)(C) Only HHV value for each calendar month in which HHV determination is required. C 98.36(e)(2)(ii)(D) All. C 98.36(e)(2)(iv)(A) All. C 98.36(e)(2)(iv)(C) All. C 98.36(e)(2)(iv)(F) All. C 98.36(e)(2)(ix)(D) All. C 98.36(e)(2)(ix)(E) All. C 98.36(e)(2)(ix)(F) All. E 98.56(b) All. E 98.56(c) All. E 98.56(g) All. E 98.56(h) All. E 98.56(j)(1) All. E 98.56(j)(3) All. E 98.56(j)(4) All. E 98.56(j)(5) All. E 98.56(j)(6) All. E 98.56(l) All. F 98.66(a) All. F 98.66(c)(2) All. F 98.66(c)(3) Only smelter

- specific slope coefficients and overvoltage emission factors. F 98.66(e)(1) Only annual anode consumption (No CEMS). F 98.66(f)(1) Only annual paste consumption (No CEMS).

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  F 98.66(g) All. G 98.76(b)(2) All. G 98.76(b)(7) All. G 98.76(b)(8) All. G 98.76(b)(9) All. G 98.76(b)(10) All. G 98.76(b)(11) All. H 98.86(b)(2) All. H 98.86(b)(5) All. H 98.86(b)(6) All. H 98.86(b)(8) All. H 98.86(b)(10) All. H 98.86(b)(11) All. H 98.86(b)(12) All. H 98.86(b)(13) All. H 98.86(b)(15) Only monthly kiln

- specific clinker factors (if used) for each kiln. I 98.96(f)(1) All. I 98.96(g) Only annual consumption of the gas (excluding annual consumption of gases for which the reporter did not calculate emissions using Equations I

– 6, I

– 7, I

– 8, I

– 9, and I

– 10 of subpart L). I 98.96(h) All. I 98.96(i) All. I 98.96(j) All. I 98.96(k) All. I 98.96(l) All. I 98.96(n) All. I 98.96(o) All. I 98.96(q)(2) Only inputs and results of calculations made accounting for the

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  uptime of abatement s ys tems used during the reporting year. I 98.96(q)(3) All. I 98.96(q)(5)(iv) Only inputs used to calculate the class average. I 98.96(r) All. I 98.96(s) Only estimates of inputs into the heat transfer fluid mass balance equation. K 98.116(b) Only annual production by

product from each EAF (No CEMS). K 98.116(e)(4) All. K 98.116(e)(5) All. L 98.126(b)(1) Only data used in calculating the absolute errors and data used in calculating the relative errors. L 98.126(b)(2) All. L 98.126(b)(6) Only mass of each fluorine

- containing reactant fed into the process. L 98.126(b)(7) Only mass of each fluorine

- containing product produced by the process. L 98.126(b)(8)(i) Only mass of each fluorine

- containing product that is removed from the process and fed into the destruction device. L 98.126(b)(8)(ii) Only mass of each fluorine

- containing b y- product that is removed from the process and fed into the destr uction device. L 98.126(b)(8)(iii) Only mass of each fluorine

- containing reactant that is removed from the process and fed into the destruction device. L 98.126(b)(8)(iv) Only mass of each fluorine

- containing b y- product that is removed from the process and recaptured. L 98.126(b)(8)(v) All. L 98.126(b)(9)(i) All. L 98.126(b)(9)(ii) All. L 98.126(b)(9)(iii) All. L 98.126(b)(10) All. L 98.126(b)(11) All.

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  L 98.126(b)(12) All. L 98.126(c)(1) Only quantity of the process activity used to estimate emissions. L 98.126(c)(2) All. L 98.126(d) Only estimate of missing data. L 98.126(f)(1) All. L 98.126(g)(1) All. L 98.126(h)(2) All. N 98.146(b)(2) Only annual quantity

of carbonate based

- raw material charged to each continuous glass melting furnace. N 98.146(b)(4) All. N 98.146(b)(6) All. O 98.156(a)(2) All. O 98.156(a)(7) All. O 98.156(a)(8) All. O 98.156(a)(9) All. O 98.156(a)(10) All. O 98.156(b)(1) All. O 98.156(b)(2) All. O 98.156(d)(1) All. O 98.156(d)(2) All. O 98.156(d)(3) All. O 98.156(d)(4) All. O 98.156(d)(5) All. O 98.156(e)(1) All. P 98.166(b)(2) All. P 98.166(b)(5) All. P 98.166(b)(6) All. Q 98.176(b) Only annual quantity

taconite pellets, coke, iron, and raw steel (No

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  CEMS). Q 98.176(e)(1) All. Q 98.176(e)(3) All. Q 98.176(e)(4) All. Q 98.176(f)(1) All. Q 98.176(f)(2) All. Q 98.176(f)(3) All. Q 98.176(f)(4) All. Q 98.176(g) All. R 98.186(b)(6) All. R 98.186(b)(7) All. S 98.196(b)(2) All. S 98.196(b)(3) All. S 98.196(b)(5) All. S 98.196(b)(6) All. S 98.196(b)(8) All. S 98.196(b)(10) All. S 98.196(b)(11) All. S 98.196(b)(12) All. U 98.216(b) All. U 98.216(e)(1) All. U 98.216(e)(2) All. U 98.216(f)(1) All. U 98.216(f)(2) All. V 98.226(c) All. V 98.226(d) All. V 98.226(i) All. V 98.226(j) All.

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  V 98.226(m)(1) All. V 98.226(m)(3) All. V 98.226(m)(4) All. V 98.226(m)(5) All. V 98.226(m)(6) All. V 98.226(p) All. W 98.236(c)(1)(i) All. W 98.236(c)(1)(ii) All. W 98.236(c)(1)(iii) All. W 98.236(c)(2)(i) All. W 98.236(c)(3)(i) All. W 98.236(c)(3)(ii) Only Calculation Methodology 2 W 98.236(c)(3)(iii) All. W 98.236(c)(3)(iv) All. W 98.236(c)(4)(i)(A) All. W 98.236(c)(4)(i)(B) All. W 98.236(c)(4)(i)(C) All. W 98.236(c)(4)(i)(D) All. W 98.236(c)(4)(i)(E) All. W 98.236(c)(4)(i)(F) All. W 98.236(c)(4)(i)(G) All. W 98.236(c)(4)(i)(H) All. W 98.236(c)(4)(ii)(A) All. W 98.236(c)(5)(i)(D) All. W 98.236(c)(5)(ii)(C) All. W 98.236(c)(6)(i)(B) All. W 98.236(c)(6)(i)(D) All. W 98.236(c)(6)(i)(E) All.

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  W 98.236(c)(6)(i)(F) All. W 98.236(c)(6)(i)(G) Only the amount of natural gas required. W 98.236(c)(6)(i)(H) Only the amount of natural gas required. W 98.236(c)(6)(ii)(A) All. W 98.236(c)(6)(ii)(B) All. W 98.236(c)(7)(i)(A) Only for Equation W

- 14A. W 98.236(c)(8)(i)(F) All. W 98.236(c)(8)(i)(K) All. W 98.236(c)(8)(ii)(A) All. W 98.236(c)(8)(ii)(H) All. W 98.236(c)(8)(iii)(A) All. W 98.236(c)(8)(iii)(B) All. W 98.236(c)(8)(iii)(G) All. W 98.236(c)(12)(ii) All. W 98.236(c)(12)(v) All. W 98.236(c)(13)(i)(E) All. W 98.236(c)(13)(i)(F) All. W 98.236(c)(13)(ii)(A) All. W 98.236(c)(13)(ii)(B) All. W 98.236(c)(13)(iii)(A) All. W 98.236(c)(13)(iii)(B) All. W 98.236(c)(13)(v)(A) All. W 98.236(c)(14)(i)(B) All. W 98.236(c)(14)(ii)(A) All. W 98.236(c)(14)(ii)(B) All. W 98.236(c)(14)(iii)(A) All. W 98.236(c)(14)(iii)(B) All. W 98.236(c)(14)(v)(A) All.

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  W 98.236(c)(15)(ii)(A) All. W 98.236(c)(15)(ii)(B) All. W 98.236(c)(16)(vii) All. W 98.236(c)(16)(viii) All. W 98.236(c)(16)(ix) All. W 98.236(c)(16)(x) All. W 98.236(c)(16)(xi) All. W 98.236(c)(16)(xii) All. W 98.236(c)(16)(xiii) All. W 98.236(c)(16)(xiv) All. W 98.236(c)(16)(xv) All. W 98.236(c)(16)(xvi) All. W 98.236(c)(17)(ii) All. W 98.236(c)(17)(iii) All. W 98.236(c)(17)(iv) All. W 98.236(c)(18)(i) All. W 98.236(c)(18)(ii) All. W 98.236(c)(19)(iv) All. W 98.236(c)(19)(vii) All. X 98.246(a)(4) Only monthly volume values, monthly

mass values, monthly carbon content values, molecular weights for gaseous feedstocks, molecular weights for gaseous products, and indication of whether the alternative method in §98.243(c)(4) was used. X 98.246(b)(5)(iii) All. X 98.246(b)(5)(iv) All. Y 98.256(e)(6) Only molar volume conversion factor for each flare. Y 98.256(e)(7) Only molar volume conversion factor for each flare. Y 98.256(e)(7)(ii) All. Y 98.256(e)(9) Only annual volume of flare gas combusted, annual average higher

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  heating value of the flare gas, volume of gas flared, average molecular weight, carbon content of the flare, and molar volume conversion factor if using Eq. Y

– 3. Y 98.256(e)(10) Only fraction of carbon in the flare gas contributed by methane. Y 98.256(f)(7) Only molar volume conversion factor. Y 98.256(f)(10) Only coke burn

- off fac tor, annual throughput of unit, and average carbon content of coke. Y 98.256(f)(11) Only units of measure for the unit

- specific CH 4 

### emission factor, activity data for calculating emissions, and unit

- specific emission factor for CH 4 

### . Y 98.256(f)(12) Only unit

- specific emission factor for N 2 

### O, units of measure for the unit

- specific N 2 

### O emission factor, and activity data for calculating emissions. Y 98.256(f)(13) Only average carbon content of coke. Y 98.256(h)(4) All. Y 98.256(h)(5) Only value of the cor

rection, annual volume of recycled tail gas (if used to calculate recycling correction factor), and annual average mole fraction of carbon in the tail gas (if used to calculate recycling correction factor). Y 98.256(i)(5) Only annual mass of green coke fed, carbon content of green coke fed, annual mass of marketable coke produced, carbon content of marketable coke produced, and annual mass of coke dust removed from the process. Y 98.256(i)(7) Only the unit

- specific CH 4 

### emission factor, units of measure for unit

- specific CH 4 

### emission factor, and activity data for calculating emissions. Y 98.256(i)(8) Only units of measure for the unit

- specific factor, activity data used for calculating emissions, and site

- specific emissions factor. Y 98.256(j)(2) All. Y 98.256(j)(5) Only CO 2 

### emission factor. Y 98.256(j)(6) Only CH 4 

### emission factor. Y 98.256(j)(7) Only carbon emission factor. Y 98.256(j)(8) Only CO 2 

### emission factor and carbon emission factor.

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  Y 98.256(j)(9) Only CH 4 

### emission factor. Y 98.256(k)(3) Only dimensions of coke drum or vessel, t ypical gauge pressure of the coking drum, ty

pical void fraction of coke drum or vessel, annual number of coke

- cutting cycles of coke drum or vessel, and molar volume conversion factor for each coke drum or vessel. Y 98.256(k)(4) Only height and diameter of the coke drums, cumulative number of vessel openings for all delayed coking drums, ty pical venting pressure, void fraction, mole fraction of methane in coking gas. Y 98.256(l)(5) Only molar volume conversion fact or. Y 98.256(m)(3) Only total quantity of crude oil plus the quantity of intermediate products received from off

- site, CH 4 

### emission factor used, and molar volume conversion factor. Y 98.256(n)(3) All (if used in Equation Y

–21 to calculate emissions from equipment leaks). Y 98.256(o)(2)(ii) All. Y 98.256(o)(4)(ii) All. Y 98.256(o)(4)(iii) All. Y 98.256(o)(4)(iv) All. Y 98.256(o)(4)(v) All. Y 98.256(o)(4)(vi) Only tank

- specific methane composition data and annual gas generation volume

. Y 98.256(p)(2) Only quantity of materials loaded that have an equilibrium vapor

phase concentration of CH 4 

### of 0.5 volume percent or greater. Z 98.266(f)(5) All. Z 98.266(f)(6) All. AA 98.276(b) All. AA 98.276(c) Only annual mass of the spent liquor solids combusted. AA 98.276(d) All. AA 98.276(e) All. AA 98.276(f) All. AA 98.276(g) All.

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  AA 98.276(h) All. AA 98.276(i) All. BB 98.286(b)(1) All. BB 98.286(b)(4) All. BB 98.286(b)(6) All. CC 98.296(b)(5) Only monthly consumption of trona or liquid alkaline feedstock (for facilities using Equation CC

– 1). CC 98.296(b)(6) Only monthly production of soda ash for each manufacturing line(for facilities using Equation CC

–2). CC 98.296(b)(7) All. CC 98.296(b)(10)(i) All. CC 98.296(b)(10)(ii) All. CC 98.296(b)(10)(iii) All. CC 98.296(b)(10)(iv) All. CC 98.296(b)(10)(v) All. CC 98.296(b)(10)(vi) All. EE 98.316(b)(6) All. EE 98.316(b)(9) All. GG 98.336(b)(6) All. GG 98.336(b)(7) All. GG 98.336(b)(10) All. II 98.356(d)(2) All (if conducting weekly sampling). II 98.356(d)(3) All (if conducting weekly sampling). II 98.356(d)(4) Only weekl y average temperature (if conducting weekl y sampling). II 98.356(d)(5) Only weekl y average moisture content (if conducting weekl y sampling). II 98.356(d)(6) Only weekl y average pressure (if conducting weekly sampling). TT 98.466(c)(3)(i) All.

### Subpart **Rule citation (40 CFR part 98)**  **Specific data elements for which reporting date is March 31,**

**2015 (“All” means**  **all data elements in the cited paragraph are not required to be reported until March 31, 2015)**  TT 98.466(c)(3)(ii) Only waste disposal quantity

and production quantity

. TT 98.466(c)(3)(iii) All.

### 5 **. Am**  **endments to Table C** 
**- 1**  **to 40 CFR part 98, subpart C**  **:**

**Table C –**  **1 to Subpart C —**  **Default 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. 69 Bituminous 24.93 93. 28 Subbituminous 17.25 97. 17 Li gnite 14.21 97.72 Coal Coke 24.80 113.67 Mixed (Commercial sector) 21.39 94.27 Mixed (Industrial coking) 26.28 93. 90 Mixed (Industrial sector) 22.35 94.67 Mixed (Electric Power sector) 19.73 95.52

Natural gas mmBtu/scf kg CO 2 

### /mmBtu (Weighted U.S. Average) 1. 026 × 10 −3 

### 53.0 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. 138 74.00 Kerosene 0.135 75.20 Liquefied petroleum gases (LPG) 1 

### 0.092 61.71 Propane 1 

### 0.091 62.87 Ethane 1 

### 0. 068 59.60 Ethanol 0.084 68.44 Ethylene 2 

### 0. 058 65.96 Isobutane 1 

### 0. 099 64.94

### Fuel type **Default high heat value Default**  CO 2 

### emission factor Isobutyl ene 1 

### 0.103 68.86 Butane 1 

### 0. 103 64.77 Butylene 1 

### 0. 105 68.72 Naphtha (<401 deg F) 0.125 68.02 Natural Gasoline 0.110 66.8 8 Other Oil (>401 deg F) 0.139 76.22 Pentanes Plus 0.110 70.02 Petrochemical Feedstocks 0. 125 71.02 Petroleum Coke 0.143 102.41 Special Naphtha 0.125 72.34 Unfinished Oils 0.139 74. 54 Heav y Gas Oils 0.148 74.92 Lubricants 0.144 74.27 Motor Gasoline 0.125 70.22 Aviation Gasoline 0.120 69.25 Kerosene

- Ty

pe Jet Fuel 0.135 72.22 Asphalt and Road Oil 0.158 75.36 Crude Oil 0.138 74. 54

Other fuels

- solid mmBtu/short ton kg CO 2 

### /mmBtu Municipal Solid Waste 9.95 3 

### 90.7 Tires 28.00 85.97 Plastics 38.00 75.00 Petroleum Coke 30.00 102.41

Other fuels

— gaseous mmBtu/scf kg CO 2 

### /mmBtu Blast Furnace Gas 0.092 × 10 −3 

### 274.32 Coke Oven Gas 0.599 × 10 −3 

### 46.85 Propane Gas 2.516 × 10 −3 

### 61.46 Fuel Gas 4 

### 1.388 × 10 −3 

### 59.00

### Fuel type **Default high heat value Default**  CO 2 

### emission factor Biomass fuels

— solid mmBtu/short ton kg CO 2 

### /mmBtu Wood and Wood Residuals (dry basis) 5 

### 17.48 93.80 Agricultural By

products 8.25 118.17 Peat 8.00 111.84 Solid By products 10.39 105.51 Biomass fuels

— gaseous mmBtu/scf kg CO 2 

### /mmBtu Landfill Gas 0. 485 × 10 −3 

### 52.07 Other Biomass Gases 0.655 x 10 - 3 

### 52.07

Biomass Fuels

—Li quid mmBtu/gallon kg CO 2 

### /mmBtu Ethanol 0.084 68.44 Biodiesel (100%) 0.128 73.84 Rendered Animal Fat 0.125 71.06 Vegetable Oil 0.120 81.55
1 

### The HHV for c omponents of LPG determined at 60 o F and saturation pressure with the exception of ethylene.

2 

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

3 

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

4 

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

5 

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

- 1: HHV w 

### =((100

- M)/100)* HHV d 

### where HHV w 

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

### =dry basis HHV from Table C

- 1. 

### 6 **. Am**  **endments to Table C** 
**- 2**  **to 40 CFR part 98, subpart C**  **:**

### Table C **– 2 to Subpart C** **— Default CH**  **4** 

### and N **2** 

### O Emission Factors for **Various Types of Fuel**

**Fuel type Default CH**  **4** 

### emission **factor (kg CH 4**  

### /mmBtu) **Default N 2**  

### O **emission factor (kg N**  **2** 

### O/mmBtu) Coal and Coke (All fuel ty pes in Table C

– 1) 1.1 × 10 −02 

### 1.6 × 10 −03


### Natural Gas 1.0 × 10 −03 

### 1.0 × 10 −04 

### Petroleum (All fuel ty

pes 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 ty pes in Table C

– 1 , except wood and wood residuals) 3.2 × 10 −02 

### 4.2 × 10 −03



### Wood and wood residuals 7.2 x 10 - 0 3 

### 3.6 x 10 - 0 3 

### Biomass Fuels

- Gaseous (All fuel ty pes in Table C

- 1) 3.2 × 10 −03 

### 6.3 × 10 −04


### Biomass Fuels

—Li quid (All fuel ty pes in Table C

– 1) 1.1 × 10 −03 

### 1.1 × 10 −04



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

### /mmBtu.

### 7 **. Am**  **endments 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 0.0019 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.



### 8 **. Am**  **endments 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 CH**  **4** 

### and **N 2**  

### O

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

**Kraft lime kilns Kraft calciners**  CH 4 

### N 2 

### O CH 4 

### N 2 

### O Residual Oil (any ty pe) 0.0027 0 0.0027 0.0003
Distillate Oil (an y typ e) 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 s 

### 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.

### 9 **. Am**  **endments 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**  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.

### Factor **Default value Units** 

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, plastics, metal, concrete) 0.00 yr−1 **Other parameters**

**—**

**All MSW landfills** MCF 1. DOC F 

### 0.5 F 0.5 OX 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.

### Alternativel y, landfills that use leachate recirculation can

elect to use the k value of 0.057 rather than calculating the recirculated leachate rate. b 

### Use the lesser value when precipitation plus recirculated leachate is less than 20 inches/year. Use the greater valu e when precipitation plus recirculated leachate is greater than 40 inches/year. Use the average of the range of values when precipitation plus recirculated leachate is 20 to 40 inches/year (inclusive). Alternatively, landfills that use leachate recirculati on 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 leachate. Alternatively, landfills that use leachate recirculation can elect to use the greater value rather than assess ing the potential evapotranspiration rate or recirculated leachate rate.
**10 .**  **Am endments 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 1950 0.63 1951 0.63 1952 0.63 1953 0.63 1954 0.63 1955 0.63 1956 0.63 1957 0.63 1958 0.63 1959 0.63 1960 0.63 1961 0.64 1962 0.64 1963 0.65 1964 0.65 1965 0.66 1966 0.66 1967 0.67 1968 0.68 1969 0.68

### Year **Waste per capita** ton/cap/yr 1970 0.69 1971 0.69 1972 0.70 1973 0.71 1974 0.71 1975 0.72 1976 0.73 1977 0.73 1978 0.74 1979 0.75 1980 0.75 1981 0.76 1982 0.77 1983 0.77 1984 0.78 1985 0.79 1986 0.79 1987 0.80 1988 0.80 1989 0. 83 1990 0. 8 2 1991 0. 7 6 1992 0. 7 4 1993 0. 7 6 1994 0. 7 5 1995 0. 7 0 1996 0. 68 1997 0. 69 1998 0. 75 1999 0. 75 2000 0. 8 0 2001 0. 9 1 2002 1. 0 2 2003 1. 0 2 2004 1. 0 1 2005 0.98 2006 0.95 2007 0.95 2008 0.95 2009 and all later years 0.95

### 1 **1 .**  **Table HH** 
**- 4**  **to 40 CFR part 98, subpart H**  **H :** 

**Table HH**

**– 4**  **to Subpart HH of Part 98**

**— Landfill**  **Methane Oxidation Fractions**
**Under these conditions: Use this landfill methane**  **oxidation fraction:** I. For all reporting ye ars prior to the 2013 reporting ye ar C1: For all landfills regardless of cover typ e or methane flux 0.10 II. For the 2013 reporting ye ar and all subsequent years

 C2: For landfills that have a geomembrane (sy nthetic) cover with less than 12 inches of cover soil for the majority of the landfill area containing waste  0.0

C3: For landfills that do not meet the conditions in C2 above, and for which you elect not to determine methane flux 0.10
C4: For landfills that do not meet the conditions in C2 above and that do not have a soil cover of at least 24 inches for a majority of the landfill area containing waste 0.10

C5: For landfills that have a soil cover of at least 24 inches for a majority of the landfill area containing waste and for which the methane flux rate is less than 10 grams per square meter per day (g/m 2 

### /d) 0.35

C6: For landfills that have a soil cover of at least 24 inches for a majority of the landfill area containing waste and for which the methane flux rate is 10 to 70 g/m2 

### /d 0.25

C7: For landfills that have a soil cover of at least 24 inches for a majority of the landfill area containing waste and for which the methane flux rate is greater than 70 g/m 2 

### /d 0.10

a

### Methane flux rate (in grams per square meter per day ; g/m 2 

### /d) is the m ass 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, 

## SArea G K MF CH4 

##   For Equation HH

- 6 of this subpart, SArea R

- G K MF 1 n

CH4 

### 

       

# 

 N

n 

### For Equations HH

- 7 of this subpart,

### SArea f R CE 1 K MF 1 n Rec, n 

###         

         

# 

 N

n 

### For Equation HH

- 8 of this subpart, SArea R f R CE 1 K MF 1 n 1 n Rec, n 

### 

      



          

         

#  

  N

n N

n 

### Where: MF = Methane flux rate from the landfill in the reporting year ( grams per square meter

per day , g/m 2 

### /d). K = unit conversion factor = 10 6 

### /365 (g/metric ton per days/ye ar) or 10 6 

### /366 for a leap

ye ar. SArea = The surface area of the landfill containing waste at the beginning of the reporting

ye ar (square meters, m 2 

### ). G CH 4 

### = Modeled methane generation rate in reporting year from Equation HH

– 1 of this

subpart or Equation TT

- 1 of subpart TT of this part, as applicable, except for application with Equation HH

- 6 of this subpart (metric tons CH 4 

### ). For application with Equation HH

- 6 of this subpart, the greater of the modeled methane generation rate in reporting ye ar from Equation HH

– 1 of this subpart or Equation TT

- 1 of this part, as applicable, and the quantity of recovered CH 4 

### from Equation HH

–4 of this subpart (metric tons CH 4 

### ). CE = C ollection efficiency estimated at landfill, taking into account s ys tem coverage, operation, and cover s ys tem materials from Table HH

– 3 of this subpart. If area b y soil cover ty

pe 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 sy stem. 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 destruction devices, then N=1. R n 

### = Quantity

of recovered CH 4 

### from Equation HH

–4 of this subpart for the nth 

### measurement location (metric tons). f Rec , n 

### = Fraction of hours the recovery s ys tem associated with the nth 

### measurement location was operating (annual operating hours/8760 hours per ye ar or annual operating hours/8 784 hours per year for a leap year).

### 1 **2 .**  **Am endments 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**  **1 2** 



### 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

### Products **Column A: density**  **(metric tons/bbl)**  **Column B:**

**carbon share**  **(% of mass)**  **Column C:**

**emission factor (metric tons**  CO 2 

### / **bbl)** CBOB

—Winter

Regular 0.1155 86.50 0.3663 Midgrade 0.1161 86.55 0.3684 Premium 0.1167 86.59 0.3705 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

### Products **Column A: density**  **(metric tons/bbl)**  **Column B:**

**carbon share**  **(% of mass)**  **Column C:**

**emission factor (metric tons**  CO 2 

### / **bbl)** 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 (a.k.a. Bunker C) 0.1528 84.67 0.4744

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. 0579 79.89 0. 170 Ethylene 4 

### 0. 0492 85.63 0. 154 Propane 3 

### 0. 0806 81.71 0. 241 Propylene 3 

### 0. 0827 85.63 0. 260 Butane 3 

### 0. 0928 82.66 0. 281 Butylene 3 

### 0. 0972 85.63 0. 305

### Products **Column A: density**  **(metric tons/bbl)**  **Column B:**

**carbon share**  **(% of mass)**  **Column C:**

**emission factor (metric tons**  CO 2 

### / **bbl)** Isobutane 3 

### 0. 0892 82.66 0. 270 Isobutylene 3 

### 0. 0949 85.63 0. 298 Pentanes Plus 0.1055 83.63 0.3235 Miscellaneous Products 0.1380 85.49 0.4326 1 

### 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 bi omass should not be reported, but products that were derived from both biomass 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 density and emission factor for ethylene determined at 41oF and saturation pressure.

**1 3**  **. Am**  **endments to Table NN** 
**- 1**  **to 40 CFR part 98, subpart NN**  **: Table NN**  **– 1 to Subpart**  **NN of Pa**  **rt 98 —**  **Default Factors for Calculation Methodology 1 of This Subpart** 

**Fuel Default**  **high er**  **heating value**  1 

### Default CO 2 

### emission **factor (kg**  CO 2 

### / **MMBtu)** Natural Gas 1. 02 6 MMBtu/Mscf 53. 0 6 Propane 3.84 MMBtu/bbl 62.87 Normal butane 4.34 MMBtu/bbl 64.77

Ethane 2.8 5 MMBtu/bbl 59.60 Isobutane 4. 1 6 MMBtu/bbl 64.94 Pentanes plus 4.62 MMBtu/bbl 70.02
1 

### Conditions for higher heating values presented in MMBtu/bbl are 60oF and saturation pressure.

### 1 **4 . Amendments to Table NN** 
**- 2 to 40 CFR part 98, subpart NN:** 

**Table NN –**  **2 to Subpart NN**  **of Part 98 —**  **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. 054 4 Propane Barrel 0. 241 Normal butane Barrel 0. 281 Ethane Barrel 0. 170 Isobutane Barrel 0. 270 Pentanes plus Barrel 0.324 1 

### Conditions for emission value presented in MT CO 2 

### /bbl are 60oF and saturation pressure.

**1 5**  **. Am**  **endments 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 industrial sludge) 0.22 0.06 0.12 0.18 Pulp and Paper (other than industrial sludge) 0.20 0.02 0.03 0.04

Wood and Wood Product (other than industrial sludge) 0.43 0.02 0.03 0.04

Construction and Demolition 0.08 0.02 0.03 0.04 Industrial Sludge 0.09 0.02 0.04 0.06 In ert 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 0.06a 

### 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 engi neering estimates and applied to the landfill divided by the area of the portion of the landfill containing waste [with appropriate unit conversions]. (1) Dry climate = precipitation plus recirculated leachate less than 20 inches/year (2) Moderate climate = precipitation plus recirculated leachate from 20 to 40 inches/year (inclusive) (3) Wet climate = precipitation plus recirculated leachate greater than 40 inches/year Alternatively, landfills that use leachate recirculation can elect to use the k value fo r wet climate rather than calculating the recirculated leachate rate.