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MEMORANDUM

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

TO : Docket EPA-HQ-OAR-2012-0934

DATE: March 1, 2013

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

1.0 INTRODUCTION

The 2009 final GHG reporting rule (2009 final rule) was signed by EPA Administrator

Lisa Jackson on September 22, 2009 and published in the Federal Register on October 30, 2009

(74 FR 56260, October 30, 2009). The 2009 final rule, which became eff ective on December 29,

2009, included reporting of GHGs from various facilities and supp liers, consistent with the 2008

Consolidated Appropriations Act. Subsequent notices were publi shed in 2010 finalizing the

requirements for subparts T, FF, II, and TT (75 FR 39736, Jul y 12, 2010), subpart W (75 FR

74458, November 20, 2010), subparts I, L, DD, QQ, and SS (75 FR 74774, December 1, 2010),

and subparts RR and UU (75 FR 75060, December 1, 2010). These requ irements are contained

in 40 CFR part 98.The rule does not require control of GHGs, r ather it only requires that sources

above certain threshold levels monitor and report emis sions and other related data.

Since promulgation of the rule, the EPA has identifie d a number of technical issues that

need to be corrected and specific portions of the Mandato ry Greenhouse Gases Reporting Rule

(hereafter referred to as “Part 98”) that need to be cla rified. The EPA is proposing to amend

specific provisions in the Mandatory Reporting of Greenho use Gases Rule to better reflect

industry practices and improvements in climate research, correct technical and editorial errors

that have been identified since promulgation, and to clarif y or update certain provisions that have

been the subject of questions from reporting entities.

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

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

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the current requirement, and the proposed language. A brie f explanation of the reason for the

change is included for those items that are not specifica lly addressed in the preamble for this

proposal. These changes are minor clarifications of the requirements text to better reflect EPA’s

intent, simple corrections to calculation terms or c ross-references that do not revise the output of

the calculations, harmonizing changes within a subpart (such as changes to terminology), simple

editorial and minor error corrections, or removal of redundant text. In total, these changes do not

represent a change in reporting burden. Also available in the docket for this action is a set of

documents in redline strikeout format for each section o f Part 98 for which EPA is proposing

changes.

2.0 SUMMARY OF CHANGES INCLUDED

EPA is proposing changes for the subparts identified in th e table below. Significant

changes that are not detailed in this memorandum include c hanges to tables for several subparts.

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

attachments to this memorandum. Tables that have been changed include: Table A-1, A-6, C-1,

C-2, AA-1, AA-2, HH-1, HH-2, new Table HH-4, MM-1 NN-1, NN-2 , and TT-1.

Subpart

A- General Provision

C- General Stationary Fuel Combustion Sources

E - Adipic Acid Production

G – Ammonia Manufacturing

H – Cement production

K –Ferroalloy Production

L –Fluorinated Gas Production

N – Glass Production

O - HCFC-22 Production and HFC-23 Destruction

P – Hydrogen Production

Q - Iron & Steel Production

S – Lime Manufacturing

V- Nitric Acid Production

X – Petrochemical Production

Y – Petroleum Refineries

Z - Phosphoric Acid Production

AA - Pulp & Paper Manufacturing

BB - Silicon Carbide Production

DD - Electrical Transmission and Distribution Equipment Use

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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 G ases Contained in PreCharged Equipment or Closed Cell Foams

RR - Geologic Sequestration of Carbon Dioxide

SS - Electrical Equipment Manufacture or Refurbishment

TT - Industrial Waste Landfills

UU - Injection of Carbon Dioxide



# 3.0 SUMMARY OF TECHNICAL CORRECTIONS AND OTHER AMEND MENTS

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

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

Rule.4SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeA98.3(c)(1)98.3(c)(1) Facility name or supplier name (asappropriate), and physical street address of thefacility or supplier, including the city, State, and zipcode.98.3(c)(1) Facility name or supplier name (asappropriate), and physical street address of thefacility or supplier, including the city, State, and zipcode. If the facility does not have a physical streetaddress, then the facility must provide the latitudeand longitude representing the location of facilityoperations in decimal degree format. This must beprovided in a comma-delimited “latitude, longitude”coordinate pair reported in decimal degrees to atleast four digits to the right of the decimal.See preamble text for explanationA98.3(c)(11)(None)(viii)The facility or supplier must refer to thereporting instructions of the electronic GHGreporting tool regarding standardized conventions forthe naming of a parent company.See preamble text for explanationA98.3(c )(13)(None)(13) ORIS code for each power generation unit thathas been assigned an ORIS code by the EnergyInformation Administration.See preamble text for explanationA98.3(h)(4)(4) Notwithstanding paragraphs (h)(1) and (h)(2) ofthis section, upon request by the owner or operator,the Administrator may provide reasonable extensionsof the 45-day period for submission of the revisedreport or information under paragraphs (h)(1) and(h)(2) of this section. If the Administrator receives arequest for extension of the 45-day period, by e-mailto an address prescribed by the Administrator, atleast two days prior to the expiration of the 45-dayperiod, and the Administrator does not respond to therequest by the end of such period, the extensionrequest is deemed to be automatically granted for 30more days. During the automatic 30-day extension,the Administrator will determine what extension, ifany, beyond the automatic extension is reasonableand will provide any such additional extension.(4) Notwithstanding paragraphs (h)(1) and (h)(2) ofthis section, upon request by the owner or operator,the Administrator may provide reasonable extensionsof the 45-day period for submission of the revisedreport or information under paragraphs (h)(1) and(h)(2) of this section. If the Administrator receives arequest for extension of the 45-day period, by e-mailto an address prescribed by the Administrator priorto the expiration of the 45-day period, the extensionrequest is deemed to be automatically granted for 30days. The Administrator may grant an additionalextension beyond the automatic 30-day extension ifthe owner or operator submits a request for anadditional extension and the request is received bythe Administrator at least 5 business days prior to theexpiration of the automatic 30-day extension,provided the request demonstrates that it is notpracticable to submit a revised report or informationunder paragraphs (h)(1) and (h)(2) with 75 days. TheSee preamble text forexplanation5SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeAdministrator will approve the extension request ifthe request demonstrates that it is not practicable tocollect and process the data needed to resolvepotential reporting errors identified pursuant toparagraphs (h)(1) or (h)(2) of this section within 75days.A98.3(j)(3)(ii)(ii) Any subsequent extensions to the original requestmust be submitted to the Administrator within 4weeks of the owner or operator identifying the needto extend the request, but in any event no later than 4weeks before the date for the planned processequipment or unit shutdown that was provided in theoriginal request.(ii) Any subsequent extensions to the original requestmust be submitted to the Administrator within 4weeks of the owner or operator identifying the needto extend the request, but in any event no later than 4weeks before the date for the planned processequipment or unit shutdown that was provided in theoriginal or most recently approved request.Clarifies BAMM requirement.A98.3(k)(1)(None)(k) Revised Global Warming Potentials.(1) General. Starting with reporting year 2013,facilities and suppliers must use the revised GWPs inTable A-1 of this subpart, Global WarmingPotentials (revised 2013), for calculating CO2eemissions for determining applicability to this partand for calculating CO2e emissions in annual GHGreports.See preamble text for explanationA98.3(k)(2)(None)(2) Special provision for reporting year 2013. Afacility or supplier that was not subject a subpart ofpart 98 for reporting year 2012, but becomes subjecta subpart due to a change in the GWP for one ormore compounds in Table A-1 of this subpart,Global Warming Potentials (revised 2013), is notrequired to submit an annual GHG for reporting year2013. Such facilities or suppliers must startmonitoring and collecting GHG data in compliancewith this part starting on January 1, 2014, and submitan annual greenhouse gas report for reporting year2014 by March 31, 2015.See preamble text for explanationA98.3(l)(None)(l) Special provision for best available monitoringSee preamble text for explanation6SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangemethods in 2014. This paragraph applies to ownersor operators of facilities or suppliers that firstbecome subject to any subpart of part 98 due to anamendment to Table A-1 of this subpart, GlobalWarming Potentials (revised 2013).A98.3(l)(1)(None)(1) Best available monitoring methods. FromJanuary 1, 2014 to March 31, 2014, owners oroperators subject to this paragraph may use bestavailable monitoring methods for any parameter(e.g., fuel use, feedstock rates) that cannotreasonably be measured according to the monitoringand QA/QC requirements of a relevant subpart. Theowner or operator must use the calculationmethodologies and equations in the “CalculatingGHG Emissions” sections of each relevant subpart,but may use the best available monitoring method forany parameter for which it is not reasonably feasibleto acquire, install, and operate a required piece ofmonitoring equipment by January 1, 2014. Startingno later than April 1, 2014, the owner or operatormust discontinue using best available methods andbegin following all applicable monitoring andQA/QC requirements of this part, except as providedin paragraph (l)(2) of this section. Best availablemonitoring methods means any of the followingmethods:See preamble text for explanationA98.3(l)(1)(i)-(iv)(None)(i) Monitoring methods currently used by the facilitythat do not meet the specifications of a relevantsubpart.(ii) Supplier data.(iii) Engineering calculations.(iv) Other company records.See preamble text for explanationA98.3(l)(2)(None)(2) Requests for extension of the use of bestavailable monitoring methods. The owner or operatormay submit a request to the Administrator to use oneor more best available monitoring methods beyondMarch 31, 2014.(i) Timing of request. The extension request must besubmitted to EPA no later than January 31, 2014.See preamble text for explanation7SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChange(ii) Content of request. Requests must contain thefollowing information:A98.3(l)(2)(ii)(A)(None)(A) A list of specific items of monitoringinstrumentation for which the request is being madeand the locations where each piece of monitoringinstrumentation will be installed.See preamble text for explanationA98.3(l)(2)(ii)(B)(None)(B) Identification of the specific rule requirements(by rule subpart, section, and paragraph numbers) forwhich the instrumentation is needed.Seepreamble text for explanationA98.3(l)(2)(ii)(C)(None)(C) A description of the reasons that the neededequipment could not be obtained and installed beforeApril 1, 2014.See preamble text for explanationA98.3(l)(2)(ii)(D)(None)(D) If the reason for the extension is that theequipment cannot be purchased and delivered byApril 1, 2014, supporting documentation such as thedate the monitoring equipment was ordered,investigation of alternative suppliers and the dates bywhich alternative vendors promised delivery,backorder notices or unexpected delays, descriptionsof actions taken to expedite delivery, and the currentexpected date of delivery.See preamble text for explanationA98.3(l)(2)(ii)(E)(None)(E) If the reason for the extension is that theequipment cannot be installed without a process unitshutdown, include supporting documentationdemonstrating that it is not practicable to isolate theequipment and install the monitoring instrumentwithout a full process unit shutdown. Include thedate of the most recent process unit shutdown, thefrequency of shutdowns for this process unit, and thedate of the next planned shutdown during which themonitoring equipment can be installed. If there hasbeen a shutdown or if there is a planned process unitshutdown between [THE DATE OF PUBLICATIONOF THE FINAL RULE IN THE FEDERALREGISTER] and April 1, 2014, include ajustification of why the equipment could not beobtained and installed during that shutdown.See preamble text forexplanationA98.3(l)(2)(ii)(F)(None)(F) A description of the specific actions the facilitywill take to obtain and install the equipment as soonSee preamble text for explanation8SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeas reasonably feasible and the expected date bywhich the equipment will be installed and operating.A98.3(l)(2)(iii)(None)(iii) Approval criteria. To obtain approval, the owneror operator must demonstrate to the Administrator'ssatisfaction that it is not reasonably feasible toacquire, install, and operate a required piece ofmonitoring equipment by April 1, 2014. The use ofbest available methods under this subsection (l) willnot be approved beyond December 31, 2014.See preamble text for explanationA98.6Continuous bleed means a continuous flow ofpneumatic supply gas to the process measurementdevice (e.g. level control, temperature control,pressure control) where the supply gas pressure ismodulated by the process condition, and then flowsto the valve controller where the signal is comparedwith the process set-point to adjust gas pressure inthe valve actuator.Continuous bleed means a continuous flow ofpneumatic supply natural gas to the process controldevice (e.g. level control, temperature control,pressure control) where the supply gas pressure ismodulated by the process condition, and then flowsto the valve controller where the signal is comparedwith the process set-point to adjust gas pressure inthe valve actuator.Clarifies definitionA98.6Degasification systemmeans the entirety oftheequipment that is used to drain gas fromunderground and collect it at a common point, suchas a vacuum pumping station. This includes alldegasification wells and gob gas vent holes at theunderground coal mine. Degasification systemsinclude surface pre-mining, horizontal pre-mining,and post-mining systems.Degasification systemmeans the entirety of theequipment that is used to drain gas fromunderground coal mines. This includes alldegasification wells and gob gas vent holes at theunderground coal mine. Degasification systemsinclude gob and premine surface drainage wells, goband premine in-mine drainage wells, and in-minegob and premine cross-measure borehole wells.See preamble text for explanationA98.6Intermittent bleed pneumaticdevicesmeanautomated flow control devices powered bypressurized natural gas and used for maintaining aprocess condition such as liquid level, pressure,delta-pressure and temperature. These are snapacting or throttling devices that discharge the fullvolume of the actuator intermittently when controlaction is necessary, but does not bleed continuously.Intermittent bleed pneumatic devicesmeanautomated flow control devices powered bypressurized natural gas and used for automaticallymaintaining a process condition such as liquid level,pressure, delta-pressure and temperature. These aresnap-acting or throttling devices that discharge all ora portion of the full volume of the actuatorintermittently when control action is necessary, butdoes not bleed continuously.Clarifies definitionA98.6(None)Fluidized Bed Combustor (FBC)means acombustion technology (e.g., a fluidized bed boiler)where the maximum steady-state temperatureSee preamble text for explanation9SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangereached within the combustor (excluding periods ofstartup, shutdown, and malfunction) during thecombustion of solid fuels (e.g., coal, tire derivedfuel, wood and wood residuals, agriculturalbyproducts, coke, municipal solid waste, or mixturesof such fuels) is less than or equal to 19,900 degreesF.A98.6Ventilation well or shaftmeans a well or shaftemployed at an underground coal mine to serve asthe outlet or conduit to move air from the ventilationsystem out of the mine.Ventilation hole or shaftmeans a vent hole or shaftemployed at an underground coal mine to serve asthe outlet or conduit to move air from the ventilationsystem out of the mine.See preamble text for explanationA98.6Ventilation systemmeans a system that is used tocontrol the concentration of methane and other gaseswithin mine working areas through mine ventilation,rather than a mine degasification system. Aventilation system consists of fans that move airthrough the mine workings to dilute methaneconcentrations. This includes all ventilation shaftsand wells at the underground coal mine.Ventilation systemmeans a system that is used tocontrol the concentration of methane and other gaseswithin mine working areas through mine ventilation,rather than a mine degasification system. Aventilation system consists of fans that move airthrough the mine workings to dilute methaneconcentrations.See preamble text for explanationA98.698.6 No definitionORIS Codemeans the unique identifier assigned toeach power plant in the National Electric EnergyData System (NEEDS). The ORIS code is a 4 digitnumber assigned by the Energy InformationAdministration (EIA) at US Department of Energy topower plants owned by utilities.Definition added for new term used in ruleATable A-1Table A-1See Appendix A for changes to Table A-1See preamble text for explanationATable A-6Table A-6See Appendix A for changes to Table A-6Changed numbering of two data elements forHHC98.33(b)(1)(None)(viii) May be used for the combustion of a fuel listedin Table C-1 if the fuel is combusted in a unit with amaximum rated heat input capacity greater than 250mmBtu/hr (or, pursuant to §98.36(c)(3), in a group ofunits served by a common supply pipe, having atleast one unit with a maximum rated heat inputcapacity greater than 250 mmBtu/hr), provided thatboth of the following conditions apply:(A) The use of Tier 4 is not required.(B) The fuel provides less than 10 percent of theSee preambletext for explanation10SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeannual heat input to the unit, or if §98.36(c)(3)applies, to the group of units served by a commonsupply pipe.(ix) May not be used for the combustion of wastecoal (i.e., waste anthracite (culm) and wastebituminous (gob)).C98.33(b)(3)(ii)(A)(A) The use of Tier 1 or 2 is permitted, as describedin paragraphs (b)(1)(iii), (b)(1)(v), and (b)(2)(ii) ofthis section.(A) The use of Tier 1 or 2 is permitted, as describedin paragraphs (b)(1)(iii), (b)(1)(v), (b)(1)(viii), and(b)(2)(ii) of this section.Harmonizing changewith addition of paragraph98.33(b)(1)(viii).C98.33(e)(1)(ii)(ii) The procedures in paragraph (e)(5) of thissection.(ii) The procedures in paragraph (e)(4) of thissection.CorrectsreferenceC98.33(e)(3)(iv)(B)(B) Multiply the result from paragraph (e)(3)(iv)(A)of this section by the appropriate default factor todetermine the annual biogenic CO2emissions, inmetric tons. For MSW, use a default factor of 0.6 andfor tires, use a default factor of 0.20.(B) Multiply the result from paragraph (e)(3)(iv)(A)of this section by the appropriate default factor todetermine the annual biogenic CO2emissions, inmetric tons. For MSW, use a default factor of 0.55and for tires, use a default factor of 0.20.See preamble text for explanationC98.36(b)(3)(3) Maximum rated heat input capacity of the unit inmmBtu/hr for boilers and process heaters only andrelevant units of measure for other combustion units.(3) Maximum rated heat input capacity of the unit inmmBtu/hr.Standardize units of measure for all reporters.C98.36(c)(3)(3) ...As a second example, in accordance with§98.33(b)(1)(v), Tier 1 may be used regardless ofunit size when natural gas is transported through thecommon pipe, if the annual fuel consumption isobtained from gas billing records in units of therms....(3)...As a secondexample, in accordance with§98.33(b)(1)(v), Tier 1 may be used regardless ofunit size when natural gas is transported through thecommon pipe, if the annual fuel consumption isobtained from gas billing records in units of thermsor mmBtu. ...Consistency across the subpartCTable C-1Table C-1See Appendix A for changes to Table C-1See preamble text forexplanationCTable C-2Table C-2See Appendix A for changes to Table C-2See preamble text for explanationE98.53(b)(3)(3) You must measure the adipic acid production rateduring the test and calculate the production rate forthe test period in metric tons per hour.(3) You must measure the adipic acid production rateduring the test and calculate the production rate forthe test period in tons per hour.Corrects a requirement for consistency throughoutthe subpart.E98.53(d)(d) If anyN2Oabatement technology “N” is locatedafter your test point, you must determine thedestruction efficiency according to paragraphs (d)(1),(2), or (3) of this section.(d) If the adipic acid production unit exhausts to anyN2O abatement technology “N”, you must determinethe destruction efficiency according to paragraphs(d)(1), (d)(2), or (d)(3) of this section.Clarifies requirement.E98.53(e)(e) If anyN2Oabatement technology “N” is locatedafter your test point, you must determine the annual(e) If the adipic acid production unit exhausts to anyN2O abatement technology “N”, you must determineClarifies requirement.11SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeamount of adipic acid produced whileN2Oabatement technology “N” is operating according to§98.54(f). Then you must calculate the abatementfactor for N2O abatement technology “N” accordingto Equation E–2 of this section.the annual amount of adipic acid produced whileN2O abatement technology “N” is operatingaccording to §98.54(f). Then you must calculate theabatement factor for N2O abatement technology “N”according to Equation E–2 of this section.E98.53(e)Equation E-2Harmonizes equation with its definition.E98.53(g)(1)DF = Destruction efficiency ofN2Oabatementtechnology “N” (percent of N2O removed from ventstream).DF = Destruction efficiency ofN2Oabatementtechnology “N” (decimal fraction of N2O removedfrom vent stream).Clarifies a calculation term.E98.53(g)(1)AF = Abatement utilization factor ofN2Oabatementtechnology “N” (percent of time that the abatementtechnology is operating).AF = Abatement utilization factor ofN2Oabatementtechnology “N” (decimal fraction of time that theabatement technology is operating).Clarifies a calculation term.E98.53(g)(2)DF1= Destruction efficiency ofN2Oabatementtechnology 1 (percent of N2O removed from ventstream).DF1 = Destruction efficiency ofN2Oabatementtechnology 1 (decimal fraction of N2O removed fromvent stream).Clarifies a calculation term.E98.53(g)(2)AF1= Abatement utilization factor ofN2Oabatementtechnology 1 (percent of time that abatementtechnology 1 is operating).AF1 = Abatement utilization factor ofN2Oabatement technology 1 (decimal fraction of timethat abatement technology 1 is operating).Clarifies a calculation term.E98.53(g)(2)DF2= Destruction efficiency ofN2Oabatementtechnology 2 (percent of N2O removed from ventstream).DF2= Destruction efficiency ofN2Oabatementtechnology 2 (decimal fraction of N2O removed fromvent stream).Clarifies a calculation term.E98.53(g)(2)AF2= Abatement utilization factor ofN2Oabatementtechnology 2 (percent of time that abatementtechnology 2 is operating).AF2 = Abatement utilization factor ofN2Oabatement technology 2 (decimal fraction of timethat abatement technology 2 is operating).Clarifies a calculation term.E98.53(g)(2)DFN= Destruction efficiency ofN2Oabatementtechnology N (percent of N2O removed from ventstream).DFN= Destruction efficiency ofN2Oabatementtechnology “N” (decimal fraction of N2O removedfrom vent stream).Clarifies a calculation term.E98.53(g)(2)AFN= Abatement utilization factor ofN2Oabatement technology N (percent of time thatabatement technology N is operating).AFN= Abatement utilization factor ofN2Oabatement technology “N” (decimal fraction of timethat abatement technology N is operating).Clarifies a calculation term.E98.53(g)(3)DFN= Destruction efficiency ofN2Oabatementtechnology “N” (percent of N2O removed from ventstream).DFN= Destruction efficiency ofN2Oabatementtechnology “N” (decimal fraction of N2O removedfrom vent stream).Clarifies a calculation term.E98.53(g)(3)AFN= Abatement utilization factor ofN2Oabatement technology “N” (percent of time that theAFN= Abatement utilization factor ofN2Oabatement technology “N” (decimal fraction of timeClarifies a calculation term.12SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeabatement technology is operating).that the abatement technology is operating).E98.53(g)(3)FCN= Fraction control factor ofN2Oabatementtechnology “N” (percent of total emissions from unit“z” that are sent to abatement technology “N”).FCN= Fraction control factor ofN2Oabatementtechnology “N” (decimal fraction of total emissionsfrom unit “z” that are sent to abatement technology“N”).Clarifies a calculation term.E98.54(e)(e) You must determine the monthly amount ofadipic acid produced. You must also determine themonthly amount of adipic acid produced duringwhich N2O abatement technology, located after thetest point, is operating. These monthly amounts aredetermined according to the methods in paragraphs(c)(1) or (2) of this section.(e) You must determine the monthly amount ofadipic acid produced. You must also determine themonthly amount of adipic acid produced duringwhich N2O abatement technology is operating. Thesemonthly amounts are determined according to themethods in paragraphs (c)(1) or (c)(2) of this section.Corrects a requirement for consistency thrthe subpart.E98.54(f)(f) You must determine the annual amount of adipicacid produced. You must also determine the annualamount of adipic acid produced during which N2Oabatement technology located after the test point isoperating. These are determined by summing therespective monthly adipic acid production quantitiesdetermined in paragraph (e) of this section.(f) You must determine the annual amount of adipicacid produced. You must also determine the annualamount of adipic acid produced during which N2Oabatement technology is operating. These aredetermined by summing the respective monthlyadipic acid production quantities determined inparagraph (e) of this section.Corrects a requirement for consistency throughoutthe subpart.G98.73(b)(4)(4) You must calculate the annual processCO2emissions from each ammonia processing unit k atyour facility summing emissions, as applicable fromEquation G–1, G–2, and G–3 of this section usingEquation G–4.(4) You must calculate the annual processCO2emissions from each ammonia processing unit k atyour facility according to Equation G-4 of thissection:Clarifies calculation methodologies.G98.73(b)(4)Equation G-4(Eq. G-4)Corrects a calculation termG98.73(b)(5)Equation G-5(Eq. G-5)Corrects a calculation termG98.73(b)(5)ECO2k= AnnualCO2emissions from each ammoniaprocessing unit (metric tons).ECO2,k= AnnualCO2emissions from eachammoniaprocessing unit k (metric tons).Clarifies a calculation term.G98.73(b)(5)n = Total number of ammonia processing units.j = Total number of ammonia processing units.Corrects a calculation termG98.75(b)(b) For missing feedstock supplyrates or waste(b) For missing feedstock supply rates used toCorrection to missing data procedures to removekSkLkGkCOCOCOCOE,,2,,2,,2,2++=∑==jkkCOECO1,2213SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangerecycle stream used to determine monthly feedstockconsumption or monthly waste recycle streamquantity, you must determine the best availableestimate(s) of the parameter(s), based on all availableprocess data.determine monthly feedstock consumption , youmust determine the best available estimate(s) of theparameter(s), based on all available process data.reference to parameters that are nolonger part of theregulations.G98.76(a)(a) If a CEMS is used to measureCO2emissions,then you must report the relevant informationrequired under §98.36 for the Tier 4 CalculationMethodology and the following information in thisparagraph (a):(a)If a CEMS is used to measureCO2emissions,then you must report the relevant informationrequired under §98.36 for the Tier 4 CalculationMethodology and the information in paragraphs(a)(1) and (a)(2) of this section:Clarifies a requirement.G98.76(b)(b) If a CEMS is not used to measure emissions, thenyou must report the following information:(b) If a CEMS is not used to measure emissions, thenyou must report all of the following information inthis paragraph (b):Clarifies that all informationmust be reported.G98.76(b)(13)(13)CO2from the steam reforming of a hydrocarbonor the gasification of solid and liquid raw material atthe ammonia manufacturing process unit used toproduce urea and the method used to determine theCO2consumed in urea production.(13) AnnualCO2emissions (metric tons) from thesteam reforming of a hydrocarbon or the gasificationof solid and liquid raw material at the ammoniamanufacturing process unit used to produce urea andthe method used to determine the CO2consumed inurea production.Clarifies the units of theCO2emissions.H98.86(a)(2)(2) Monthly cement production from each kiln at thefacility.(2)Annual facility cement production.See preamble text for explanationK98.113(d)(1)Equation K-32000/2205 = Conversion factor to converttons to metric tons.2/2205 = Conversion factor to convert kg CH4/ton ofproduct to metric tons CH4.See preamble text for explanationK98.116(e)(2)No current requirement(2) Annual processCH4emissions (in metric tons)from each EAF used for the production of anyferroalloy listed in Table K–1 of this subpart.See preamble text for explanation14SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeL98.126(j)Introductoryparagraph(j) Special provisions for reporting years 2011 and2012 only. For reporting years 2011 and 2012, theowner or operator of a facility must comply withparagraphs (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, and2013, the owner or operator of a facility mustcomply with paragraphs (j)(1), (j)(2), and (j)(3) ofthis section.See preamble text for explanationL98.126(j)(1)(1)Timing. The owner or operator of a facility is notrequired 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 sectionuntil the later of March 31, 2014 or the date set forthfor 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 notrequired 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 sectionuntil the later of March 31, 2015 or the date set forthfor that data element at §98.3(c)(4)(vii) and Table A–7 of Subpart A of this part.See preamble text for explanationL98.126(j)(3)(i)(i) If you choose to use a default GWP rather thanyour best estimate of the GWP for fluorinated GHGswhose GWPs are not listed in Table A–1 to thissubpart, use a default GWP of 10,000 for fluorinatedGHGs that are fully fluorinated GHGs and use adefault GWP of 2000 for other fluorinated GHGs.(i) If you choose to use a default GWP rather thanyour best estimate of the GWP for fluorinated GHGswhose GWPs are not listed in Table A–1 of subpartA of this part, use a default GWP of 10,000 forfluorinated GHGs that are fully fluorinated GHGsand use a default GWP of 2000 for other fluorinatedGHGs.Correction toreferenced tableN98.143IntroductoryparagraphYou must calculate and report the annual processCO2emissions from each continuous glass meltingfurnace using the procedure in paragraphs (a) and (b)of this section.You must calculate and report the annual processCO2emissions from each continuous glass meltingfurnace using the procedure in paragraphs (a)through (c) of this section.Corrects referenceN98.143(b)(b) For each continuous glass melting furnace that isnot subject to the requirements in paragraph (a) ofthis section, calculate and report the process andcombustion CO2emissions from the glass meltingfurnace 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 asspecified in paragraph (c) of this section.(b) For each continuous glass melting furnace that isnot subject to the requirements in paragraph (a) ofthis section, calculate and report the process andcombustion CO2emissions from the glass meltingfurnace 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 inparagraph (c) of this section.Corrects referenceN98.143(b)(2)(iv)MFi= Annual average mass fraction of carbonate-based mineral i in carbonate-based raw material i(percentage, expressed as a decimal).MFi= Annual average decimal mass fraction ofcarbonate-based mineral i in carbonate-based rawmaterial i.Clarifies the equation termN98.143(b)(2)(iv)Fi= Fraction of calcination achieved for carbonate-based raw material i, assumed to be equal to 1.0(percentage, expressed as a decimal).Fi= Decimal fraction of calcination achieved forcarbonate-based raw material i, assumed to be equalto 1.0.Clarifies the equation termN98.144(b)(b) You must measure carbonate-based mineral massfractions at least annually to verify the mass fraction(b) You must measure carbonate-based mineral massfractions at least annually to verify the mass fractionSee preamble text for explanation15SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangedata provided by the supplier of the raw material;such measurements shall be based on sampling andchemical analysis using ASTM D3682–01(Reapproved 2006) Standard Test Method for Majorand Minor Elements in Combustion Residues fromCoal Utilization Processes (incorporated byreference, see §98.7) or ASTM D6349–09 StandardTest Method for Determination of Major and MinorElements in Coal, Coke, and Solid Residues fromCombustion of Coal and Coke by InductivelyCoupled Plasma—Atomic Emission Spectrometry(incorporated by reference, see §98.7).data provided by the supplier of the raw material;such measurements shall be based on sampling andchemical analysis using consensus standards thatspecify X-ray fluorescence. For measurements madein years prior to the emissions reporting year 2014,you may also use ASTM D3682–01 (Reapproved2006) Standard Test Method for Major and MinorElements in Combustion Residues from CoalUtilization Processes (incorporated by reference, see§98.7) or ASTM D6349–09 Standard Test Methodfor Determination of Major and Minor Elements inCoal, Coke, and Solid Residues from Combustion ofCoal and Coke by Inductively Coupled Plasma—Atomic Emission Spectrometry (incorporated byreference, see §98.7).N98.146(b)(4)(4) Carbonate-based mineral mass fraction(percentage, expressed as a decimal) for eachcarbonate-based raw material charged to acontinuous glass melting furnace.(4) Carbonate-based mineral decimal mass fractionfor each carbonate-based raw material charged to acontinuous glass melting furnace.Clarifies the requirementN98.146(b)(6)(6) The fraction of calcination achieved for eachcarbonate-based raw material, if a value other than1.0 is used to calculate process mass emissions ofCO2.(6) The decimal fraction of calcination achieved foreach carbonate-based raw material, if a value otherthan 1.0 is used to calculate process mass emissionsof CO2.Clarifies the requirementN98.146(b)(7)(7) Method used to determine fraction of calcination.(7) Method used to determine decimal fraction ofcalcination.Clarifies the requirementN98.147(b)(5)(5) The fraction of calcination achieved for eachcarbonate-based raw material (percentage, expressedas a decimal), if a value other than 1.0 is used tocalculate process mass emissions of CO2.(5) The decimal fraction of calcination achievedforeach carbonate-based raw material, if a value otherthan 1.0 is used to calculate process mass emissionsof CO2.Clarifies the requirementO98.153(c)(c) For HCFC–22 production facilities that do notuse a thermal oxidizer or that have a thermal oxidizerthat is not directly connected to the HCFC–22production equipment, HFC–23 emissions shall beestimated using Equation O–4 of this section:(c) For HCFC–22 production facilities that do notuse a destruction device or that have a destructiondevice that is not directly connected to the HCFC–22production equipment, HFC–23 emissions shall beestimated using Equation O–4 of this section:Harmonizing change for consistencyof destructiondevice terminology within subpart.O98.153(d)(d) For HCFC–22production facilities that use athermal oxidizer connected to the HCFC–22production equipment, HFC–23 emissions shall beestimated using Equation O–5 of this section:(Eq. O-5)(d) For HCFC–22 production facilities that use adestruction device connected to the HCFC–22production equipment, HFC–23 emissions shall beestimated using Equation O–5 of this section:(Eq. O-5)Harmonizing change for consistencyof destructiondevice terminology within subpart.16SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeWhere:ED= Mass of HFC–23 emitted annually fromthermal oxidizer (metric tons), calculated usingEquation O–8 of this section.Where:ED= Mass of HFC–23 emitted annually fromdestruction device (metric tons), calculated usingEquation O–8 of this section.O98.154(j)(j) The number of sourcesof equipment type t withscreening values less than 10,000 ppmv shall be thedifference between the number of leak sources ofequipment type t that could emit HFC-23 and thenumber of sources of equipment type t withscreening values greater than or equal to 10,000ppmv as determined under paragraph (h) of thissection.(j) The number of sources of equipment type t withscreening values less than 10,000 ppmv shall be thedifference between the number of leak sources ofequipment type t that could emit HFC-23 and thenumber of sources of equipment type t withscreening values greater than or equal to 10,000ppmv as determined under paragraph (i) of thissection.Correct paragraph reference.O98.156(c)(c) Each HFC-23 destruction facility shall report theconcentration (mass fraction) of HFC-23 measured atthe outlet of the destruction device during thefacility's annual HFC-23 concentrationmeasurements at the outlet of the device.(c) Each HFC-23 destruction facility shall report theconcentration (mass fraction) of HFC-23 measured atthe outlet of the destruction device during thefacility's annual HFC-23 concentrationmeasurements at the outlet of the device. If theconcentration of HFC-23 is below the detection limitof the measuring device, report the detection limitand that the concentration is below the detectionlimit.See preamble text for explanationP98.163(b)(b)Fuel and feedstock material balance approach.Calculate and report CO2emissions as the sum of theannual emissions associated with each fuel andfeedstock used for hydrogen production by followingparagraphs (b)(1) through (b)(3) of this section.(b) Fuel and feedstock material balance approach.Calculate and report CO2emissions as the sum of theannual emissions associated with each fuel andfeedstock used for hydrogen production by followingparagraphs (b)(1) through (b)(3) of this section. Thecarbon content and molecular weight shall beobtained from the analyses conducted in accordancewith §98.164(b)(2), (b)(3), or (b)(4), as applicable, orfrom the missing data procedures in §98.165. If theanalyses are performed annually, then the annualvalue shall be used as the monthly average. If theanalyses are performed more frequently thanmonthly, use the arithmetic average of valuesSee preamble text for explanation17SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeobtained during the month as the monthly average.P98.163(b)(1)Fdstkn= Volume of the gaseous fuel and feedstockused in month n (scf (at standard conditions of 68 °Fand atmospheric pressure) of fuel and feedstock).CCn= Average carbon content of the gaseous fueland feedstock, from the results of one or moreanalyses for month n (kg carbon per kg of fuel andfeedstock). If measurements are taken morefrequently than monthly, use the arithmetic averageof measurement values within the month to calculatea monthly average.MWn= Average molecular weight of the gaseousfuel and feedstock from the results of one or moreanalyses for month n (kg/kg-mole).Fdstkn=Volume of the gaseous fuel or feedstockused in month n (scf (at standard conditions of 68 °Fand atmospheric pressure) of fuel or feedstock).CCn= Average carbon content of the gaseous fueland feedstock for month n (kg carbon per kg of fuelor feedstock).MWn= Average molecular weight of the gaseousfuel or feedstock for month n (kg/kg-mole).Clarifies equation termsP98.163(b)(2)Fdstkn= Volume of the liquid fuel and feedstockused in month n (gallons of fuel and feedstock).CCn= Average carbon content of the liquid fuel andfeedstock, from the results of one or more analysesfor month n (kg carbon per gallon of fuel andfeedstock).Fdstkn=Volume of the liquid fuel or feedstock usedin month n (gallons of fuel or feedstock).CCn= Average carbon content of the liquid fuel orfeedstock, for month n (kg carbon per gallon of fuelor feedstock).Clarifies equation termsP98.163(b)(3)Fdstkn= Mass of solid fuel and feedstock used inmonth n (kg of fuel and feedstock).CCn= Average carbon content of the solid fuel andfeedstock, from the results of one or more analysesfor month n (kg carbon per kg of fuel and feedstock).Fdstkn= Mass of solid fuel or feedstock used inmonth n (kg of fuel or feedstock).CCn= Average carbon content of the solid fuel orfeedstock, for month n (kg carbon per kg of fuel orfeedstock).Clarifies equation termsP98.164(b)(3)(3) Determine the carbon content of fuel oil, naphtha,and other liquid fuels and feedstocks at leastmonthly, except annually for standard liquidhydrocarbon fuels and feedstocks having consistentcomposition, or upon delivery for liquid fuelsdelivered by bulk transport (e.g., by truck or rail).(3) Determine the carbon content of fuel oil, naphtha,and other liquid fuels and feedstocks at leastmonthly, except annually for standard liquidhydrocarbon fuels and feedstocks having consistentcomposition, or upon delivery for liquid fuels andfeedstocks delivered by bulk transport (e.g., by truckor rail).See preamble text for explanationP98.164(b)(4)(4) Determine the carbon content of coal, coke, andother solid fuels and feedstocks at least monthly,except annually for standard solid hydrocarbon fuelsand feedstocks having consistent composition, orupon delivery for solid fuels delivered by bulktransport (e.g., by truck or rail).(4) Determine the carbon content of coal, coke, andother solid fuels and feedstocks at least monthly,except annually for standard solid hydrocarbon fuelsand feedstocks having consistent composition, orupon delivery for solid fuels and feedstocksdelivered by bulk transport (e.g., by truck or rail).See preamble text for explanation18SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeP98.164(b)(5)(5)You must use the following applicable methodsto determine the carbon content for all fuels andfeedstocks, and molecular weight of gaseous fuelsand feedstocks. Alternatively, you may use theresults of continuous chromatographic analysis of thefuel and feedstock, provided that the gaschromatograph (GC) is operated, maintained, andcalibrated according to the manufacturer'sinstructions; and the methods used for operation,maintenance, and calibration of the GC aredocumented in the written monitoring plan for theunit under §98.3(g)(5).(5)You must use the following applicable methodsto determine the carbon content for all fuels andfeedstocks, and molecular weight of gaseous fuelsand feedstocks. Alternatively, you may use theresults of chromatographic analysis of the fuel andfeedstock, provided that the chromatograph isoperated, maintained, and calibrated according to themanufacturer's instructions; and the methods used foroperation, maintenance, and calibration of thechromatograph are documented in the writtenmonitoring plan for the unit under §98.3(g)(5).Seepreamble text for explanationP98.164(c)(c) For units using the calculation methodologiesdescribed in this section, the records required under§98.3(g) must include both the company records anda detailed explanation of how company records areused to estimate the following:(1) Fuel and feedstock consumption, when solid fueland feedstock is combusted and a CEMS is not usedto measure GHG emissions.(2) Fossil fuel consumption, when, pursuant to§98.33(e), the owner or operator of a unit that usesCEMS to quantify CO2emissions and that combustsboth fossil and biogenic fuels separately reports thebiogenic portion of the total annual CO2emissions.(3) Sorbent usage, if the methodology in §98.33(d) isused to calculate CO2emissions from sorbent.(c) [Reserved]See preamble text for explanationP98.164(d)(d) The owner or operator must document theprocedures used to ensure the accuracy of theestimates of fuel and feedstock usage and sorbentusage (as applicable) in paragraph (b) of this section,including, but not limited to, calibration of weighingequipment, fuel and feedstock flow meters, and othermeasurement devices. The estimated accuracy ofmeasurements made with these devices must also berecorded, and the technical basis for these estimatesmust be provided.(d) [Reserved]See preamble text for explanation19SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeP98.166(a)(2)-(a)(3)(2) Annual quantity of hydrogen produced (metrictons) for each process unit and for all unitscombined.(3) Annual quantity of ammonia produced (metrictons), if applicable, for each process unit and for allunits combined.(2) Annual quantity of hydrogen produced (metrictons) for each process unit.(3) Annual quantity of ammonia produced (metrictons), if applicable for each process unit.See preamble text forexplanationP98.167(c )(None)(c) For units using the calculation methodologiesdescribed 98.163(b), the records required under§98.3(g) must include both the company records anda detailed explanation of how company records areused to estimate the following:(1) Fuel and feedstock consumption, when solid fueland feedstock is combusted and a CEMS is not usedto measure GHG emissions.(2) Fossil fuel consumption, when, pursuant to§98.33(e), the owner or operator of a unit that usesCEMS to quantify CO2emissions and that combustsboth fossil and biogenic fuels separately reports thebiogenic portion of the total annual CO2emissions.(3) Sorbent usage, if the methodology in §98.33(d) isused to calculate CO2emissions from sorbent.See preambletext for explanationP98.167(d)(None)(d) The owner or operator must document theprocedures used to ensure the accuracy of theestimates of fuel and feedstock usage and sorbentusage (as applicable) in 98.163(b), including, but notlimited to, calibration of weighing equipment, fueland feedstock flow meters, and other measurementdevices. The estimated accuracy of measurementsmade with these devices must also be recorded, andthe technical basis for these estimates must beprovided.See preamble textfor explanationQ98.170Introductoryparagraph98.170 Definition of the source category.The iron and steel production source categoryincludes facilities with any of the followingprocesses: taconite iron ore processing, integratediron and steel manufacturing, cokemaking notcolocated with an integrated iron and steelmanufacturing process, and electric arc furnace(EAF) steelmaking not colocated with an integrated98.170 Definition of the source category.The iron and steel production source categoryincludes facilities with any of the followingprocesses: taconite iron ore processing, integratediron and steel manufacturing, cokemaking notcolocated with an integrated iron and steelmanufacturing process, direct reduction furnaces notcollocated with an integrated iron and steelSee preamble text for explanation20SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeiron and steel manufacturing process. Integrated ironand steel manufacturing means the production ofsteel from iron ore or iron ore pellets. At a minimum,an integrated iron and steel manufacturing processhas a basic oxygen furnace for refining molten ironinto steel. Each cokemaking process and EAFprocess located at a facility with an integrated ironand steel manufacturing process is part of theintegrated iron and steel manufacturing facility.manufacturing process,and electric arc furnace(EAF) steelmaking not colocated with an integratediron and steel manufacturing process. Integrated ironand steel manufacturing means the production ofsteel from iron ore or iron ore pellets. At a minimum,an integrated iron and steel manufacturing processhas a basic oxygen furnace for refining molten ironinto steel. Each cokemaking process and EAFprocess located at a facility with an integrated ironand steel manufacturing process is part of theintegrated iron and steel manufacturing facility.Q98.173(b)(1)(i)(Csf) = Carbon content of the solid fuel, from the fuelanalysis (percent by weight, expressed as a decimalfraction, e.g., 95% = 0.95).(C0) = Carbon content of the greenball (taconite)pellets, from the carbon analysis results (percent byweight, expressed as a decimal fraction).(Cp) = Carbon content of the fired pellets, from thecarbon analysis results (percent by weight, expressedas a decimal fraction).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (percent byweight, expressed as a decimal fraction).(Csf) = Carbon content of the solid fuel, from the fuelanalysis (expressed as a decimal fraction).(C0) = Carbon content of the greenball (taconite)pellets, from the carbon analysis results (expressedas a decimal fraction).(Cp) = Carbon content of the fired pellets, from thecarbon analysis results (expressed as a decimalfraction).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (expressedas a decimal fraction).Clarifies equation termsQ98.173(b)(1)(i)(Fs) = Annual mass of the solid fuel combusted(metric tons).(Fs) = Annual mass of the solid fuel used (metrictons).Clarifiesequation termQ98.173(b)(1)(i)(Fg) = Annual volume of the gaseous fuel combusted(scf).(Fg) = Annual volume of the gaseous fuel used (scf).Clarifies equation termQ98.173(b)(1)(i)(Fl) = Annual volume of the liquid fuel combusted(gallons).(Fl) =Annual volume of the liquid fuel used(gallons).Clarifies equation termQ98.173(b)(1)(ii),(CIron) = Carbon content of the molten iron, from thecarbon analysis results (percent by weight, expressedas a decimal fraction).(CScrap) = Carbon content of the ferrous scrap, fromthe carbon analysis results (percent by weight,expressed as a decimal fraction).(CFlux) = Carbon content of the flux materials, fromthe carbon analysis results (percent by weight,expressed as a decimal fraction).(CCarbon) = Carbon content of the carbonaceous(CIron) = Carbon content of the molten iron, from thecarbon analysis results (expressed as a decimalfraction).(CScrap) = Carbon content of the ferrous scrap, fromthe carbon analysis results (expressed as a decimalfraction).(CFlux) = Carbon content of the flux materials, fromthe carbon analysis results (expressed as a decimalfraction).(CCarbon) = Carbon content of the carbonaceousClarifies equation terms21SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangematerials, from the carbon analysis results (percentby weight, expressed as a decimal fraction).(CSteel) = Carbon content of the steel, from the carbonanalysis results (percent by weight, expressed as adecimal fraction).(CSlag) = Carbon content of the slag, from the carbonanalysis (percent by weight, expressed as a decimalfraction).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (percent byweight, expressed as a decimal fraction).materials, from the carbon analysis results (expressedas a decimal fraction).(CSteel) = Carbon content of the steel, from the carbonanalysis results (expressed as a decimal fraction).(CSlag) = Carbon content of the slag, from the carbonanalysis (expressed as a decimal fraction).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (expressedas a decimal fraction).Q98.173(b)(1)(iii)(CCoal) = Carbon content of the coal, from the carbonanalysis results (percent by weight, expressed as adecimal fraction).(CCoke) = Carbon content of the coke, from thecarbon analysis results (percent by weight, expressedas a decimal fraction).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (percent byweight, expressed as a decimal fraction).(CCoal) = Carbon content of the coal, from the carbonanalysis results (expressed as a decimal fraction).(CCoke) = Carbon content of the coke, from thecarbon analysis results (expressed as a decimalfraction).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (expressedas a decimal fraction).Clarifies equation termsQ98.173(b)(1)(iv)(CFeed) = Carbon content of the mixed sinter feedmaterials that form the bed entering the sinteringmachine, from the carbon analysis results (percent byweight, expressed as a decimal fraction).(CSinter) = Carbon content of the sinter pellets, fromthe carbon analysis results (percent by weight,expressed as a decimal fraction).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (percent byweight, expressed as a decimal fraction).(CFeed) = Carbon content of the mixed sinter feedmaterials that form the bed entering the sinteringmachine, from the carbon analysis results (expressedas a decimal fraction).(CSinter) = Carbon content of the sinter pellets, fromthe carbon analysis results (expressed as a decimalfraction).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (expressedas a decimal fraction).Clarifies equation termsQ98.173(b)(1)(iv)(Fg) = Annual volume of the gaseous fuel combusted(scf).(Fg) = Annual volume of the gaseous fuel used (scf).Clarifies equation termQ98.173(b)(1)(v)(v) For EAFs, estimateCO2emissions usingEquation Q-5 of this section.CO2=44/12*[(Iron)*(CIron)+(Scrap)*(CScrap)+(Flux)*(Cf)+(Electrode)*(CElectrode)+(Carbon)*(Cc)-(Steel)*(CSteel)-(Slag)*(CSlag)-(R)*(CR)(v) For EAFs, estimateCO2emissions usingEquation Q-5 of this section.CO2=44/12*[(Iron)*(CIron)+(Scrap)*(CScrap)+(Flux)*(CFlux)+(Electrode)*(CElectrode)+(Carbon)*(CCarbon)-(Steel)*(CSteel)+(Fg)*(Cgf)*MW/MVC*0.001-(Slag)*(CSlag)-(R)*(CR)]See preamble text for explanation22SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeWhere:CO2= Annual CO2mass emissions from the EAF(metric tons).44/12 = Ratio of molecular weights, CO2to carbon.(Iron) = Annual mass of direct reduced iron (if any)charged to the furnace (metric tons).(CIron) = 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 tothe furnace (metric tons).(CScrap) = Carbon content of the ferrous scrap, fromthe 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 (metrictons).(CFlux) = Carbon content of the flux materials, fromthe carbon analysis results (percent by weight,expressed as a decimal fraction).(Electrode) = Annual mass of carbon electrodeconsumed (metric tons).(CElectrode) = 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 (metrictons).(CCarbon) = Carbon content of the carbonaceousmaterials, from the carbon analysis results (percentby weight, expressed as a decimal fraction).(Steel) = Annual mass of molten raw steel producedby the furnace (metric tons).(CSteel) = Carbon content of the steel, from the carbonanalysis results (percent by weight, expressed as adecimal fraction).(Slag) = Annual mass of slag produced by thefurnace (metric tons).Where:CO2= Annual CO2mass emissions from the EAF(metric tons).44/12 = Ratio of molecular weights, CO2to carbon.(Iron) = Annual mass of direct reduced iron (if any)charged to the furnace (metric tons).(CIron) = Carbon content of the direct reduced iron,from the carbon analysis results (expressed as adecimal fraction).(Scrap) = Annual mass of ferrous scrap charged tothe furnace (metric tons).(CScrap) = Carbon content of the ferrous scrap, fromthe carbon analysis results (expressed as a decimalfraction).(Flux) = Annual mass of flux materials (e.g.,limestone, dolomite) charged to the furnace (metrictons).(CFlux) = Carbon content of the flux materials, fromthe carbon analysis results (expressed as a decimalfraction).(Electrode) = Annual mass of carbon electrodeconsumed (metric tons).(CElectrode) = Carbon content of the carbon electrode,from the carbon analysis results (expressed as adecimal fraction).(Carbon) = Annual mass of carbonaceous materials(e.g., coal, coke) charged to the furnace (metrictons).(CCarbon) = Carbon content of the carbonaceousmaterials, from the carbon analysis results (expressedas a decimal fraction).(Steel) = Annual mass of molten raw steel producedby the furnace (metric tons).(CSteel) = Carbon content of the steel, from the carbonanalysis results (expressed as a decimal fraction).(Fg) = Annual volume of the gaseous fuel used (scf at60 degrees F and one atmosphere).23SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChange(CSlag) = Carbon content of the slag, from the carbonanalysis results (percent by weight, expressed as adecimal fraction).(R) = Annual mass of air pollution control residuecollected (metric tons).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (percent byweight, expressed as a decimal fraction).(Cgf) = Average carbon content of the gaseous fuel,from the fuel analysis results (kg C per kg of fuel).(MW) = Molecular weight of the gaseous fuel(kg/kg-mole).(MVC) = Molar volume conversion factor (836.6 scfper kg-mole at standard conditions of 60 degrees Fand one atmosphere).(0.001) = Conversion factor from kg to metric tons.(Slag) = Annual mass of slag produced by thefurnace (metric tons).(CSlag) = Carbon content of the slag, from the carbonanalysis results (expressed as a decimal fraction).(R) = Annual mass of air pollution control residuecollected (metric tons).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (expressedas a decimal fraction).Q98.173(b)(1)(vi)(vi) For decarburization vessels, estimateCO2emissions using Equation Q-6 of this section.CO2=44/12*(Steel)*[(CSteelin)-(CSteelout)]-(R)*(CR)Where:CO2= Annual CO2mass emissions from thedecarburization vessel (metric tons).44/12 = Ratio of molecular weights, CO2to carbon.(Steel) = Annual mass of molten steel charged to thevessel (metric tons).(CSteelin) = Carbon content of the molten steel beforedecarburization, from the carbon analysis results(percent by weight, expressed as a decimal fraction).(CSteelout) = Carbon content of the molten steel afterdecarburization, from the carbon analysis results(percent by weight, expressed as a decimal fraction).(R) = Annual mass of air pollution control residuecollected (metric tons).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (percent byweight, expressed as a decimal fraction).(vi) For decarburization vessels, estimateCO2emissions using Equation Q-6 of this section.CO2=44/12*{(Steel)*[(CSteelin)-(CSteelout)]-(R)*(CR)}Where:CO2= Annual CO2mass emissions from thedecarburization vessel (metric tons).44/12 = Ratio of molecular weights, CO2to carbon.(Steel) = Annual mass of molten steel charged to thevessel (metric tons).(CSteelin) = Carbon content of the molten steel beforedecarburization, from the carbon analysis results(expressed as a decimal fraction).(CSteelout) = Carbon content of the molten steel afterdecarburization, from the carbon analysis results(expressed as a decimal fraction).(R) = Annual mass of air pollution control residuecollected (metric tons).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (expressedas a decimal fraction).Clarifies the order of operations in the equation.24SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeQ98.173(b)(1)(vii)(Fg) = Annual volume of the gaseous fuel combusted(scf).(Fg) = Annual volume of the gaseous fuel used (scf).Clarifies equation termQ98.173(b)(1)(vii)(COre) = Carbon content of the iron ore or iron orepellets, from the carbon analysis results (percent byweight, expressed as a decimal fraction).(CCarbon) = Carbon content of the carbonaceousmaterials, from the carbon analysis results (percentby weight, expressed as a decimal fraction).(COther) = Average carbon content of the othermaterials charged to the furnace, from the carbonanalysis results (percent by weight, expressed as adecimal fraction).(CIron) = Carbon content of the iron, from the carbonanalysis results (percent by weight, expressed as adecimal fraction).(CNM) = Carbon content of the non-metallicmaterials, from the carbon analysis results (percentby weight, expressed as a decimal fraction).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (percent byweight, expressed as a decimal fraction).(COre) = Carbon content of the iron ore or iron orepellets, from the carbon analysis results (expressedas a decimal fraction).(CCarbon) = Carbon content of the carbonaceousmaterials, from the carbon analysis results (expressedas a decimal fraction).(COther) = Average carbon content of the othermaterials charged to the furnace, from the carbonanalysis results (expressed as a decimal fraction).(CIron) = Carbon content of the iron, from the carbonanalysis results (expressed as a decimal fraction).(CNM) = Carbon content of the non-metallicmaterials, from the carbon analysis results (expressedas a decimal fraction).(CR) = Carbon content of the air pollution controlresidue, from the carbon analysis results (expressedas a decimal fraction).Clarifies equation termsQ98.173(c )(c) You must determine emissions ofCO2from thecoke pushing process in mtCO2e by multiplying themetric tons of coal charged to the coke ovens duringthe reporting period by 0.008.(c) You must determine emissionsofCO2from thecoke pushing process in mtCO2e by multiplying themetric tons of coal charged to the by-productrecovery and non-recovery coke ovens during thereporting period by 0.008.Clarifies requirement.Q98.173(d)(d)If GHG emissions from a taconite induratingfurnace, basic oxygen furnace, non-recovery cokeoven battery, sinter process, EAF, decarburizationvessel, or direct reduction furnace are vented throughthe same stack as any combustion unit or processequipment that reports CO2emissions using a CEMSthat complies with the Tier 4 CalculationMethodology in subpart C of this part (GeneralStationary Fuel Combustion Sources), then thecalculation methodology in paragraph (b) of thissection shall not be used to calculate processemissions. The owner or operator shall report underthis subpart the combined stack emissions according(d)If GHG emissions from a taconite induratingfurnace, basic oxygen furnace, non-recovery cokeoven battery, sinter process, EAF, decarburizationvessel, or direct reduction furnace are vented througha stack equipped with a CEMS that complies withthe Tier 4 methodology in subpart C of this part, orthrough the same stack as any combustion unit orprocess equipment that reports CO2emissions usinga CEMS that complies with the Tier 4 CalculationMethodology in subpart C of this part (GeneralStationary Fuel Combustion Sources), then thecalculation methodology in paragraph (b) of thissection shall not be used to calculate processSee preamble text for explanation25SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeto the Tier 4 Calculation Methodology in§98.33(a)(4) and all associated requirements for Tier4 in subpart C of this part (General Stationary FuelCombustion Sources).emissions. The owner or operator shall report underthis subpart the combined stack emissions accordingto the Tier 4 Calculation Methodology in§98.33(a)(4) and comply with all associatedrequirements for Tier 4 in subpart C of this part(General Stationary Fuel Combustion Sources).Q98.174(b)(1)(1) Except as provided in paragraph (b)(4) of thissection, determine the mass of each process inputand output other than fuels using the same plantinstruments or procedures that are used foraccounting purposes (such as weigh hoppers, beltweigh feeders, weighed purchased quantities inshipments or containers, combination of bulk densityand volume measurements, etc.), record the totals foreach process input and output for each calendarmonth, and sum the monthly mass to determine theannual mass for each process input and output.Determine the mass rate of fuels using theprocedures for combustion units in §98.34.(1) Except as provided in paragraph (b)(4) of thissection, determine the mass of each process inputand output other than fuels using the same plantinstruments or procedures that are used foraccounting purposes (such as weigh hoppers, beltweigh feeders, weighed purchased quantities inshipments or containers, combination of bulk densityand volume measurements, etc.), record the totals foreach process input and output for each calendarmonth, and sum the monthly mass to determine theannual mass for each process input and output.Determine the mass rate of fuels using theprocedures for combustion units in §98.34. Nodetermination of the mass of steel output fromdecarburization vessels is required.See preamble text for explanationQ98.174(c )(2)(2)For the furnace exhaust from basic oxygenfurnaces, EAFs, decarburization vessels, and directreduction furnaces, sample the furnace exhaust for atleast three complete production cycles that startwhen the furnace is being charged and end after steelor iron and slag have been tapped. For EAFs thatproduce both carbon steel and stainless or specialty(low carbon) steel, develop an emission factor for theproduction of both types of steel.(2)(i) For the exhaust from basic oxygen furnaces,EAFs, decarburization vessels, and direct reductionfurnaces, sample the furnace exhaust for at leastthree complete production cycles that start when thefurnace is being charged and end after steel or ironand slag have been tapped. For EAFs that produceboth carbon steel and stainless or specialty (lowcarbon) steel, develop an emission factor for theproduction of both types of steel.(ii) For the exhaust from continuously chargedEAFs, sample the exhaust for a period spanning atleast three three hours. For EAFs that produce bothcarbon steel and stainless or specialty (low carbon)steel, develop an emission factor for the productionof both types of steel.See preamble text for explanationQ98.175(a)(a) For each missing data for the carbon content ofinputs and outputs for facilities that estimateemissions using the carbon mass balance procedure(a) Except as provided in §98.174(b)(4), 100 percentdata availability is required for the carbon content ofinputs and outputs for facilities that estimateSee preamble text for explanation26SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangein §98.173(b)(1) or for facilities that estimateemissions using the site-specific emission factorprocedure in §98.173(b)(2); 100 percent dataavailability is required. You must repeat the test foraverage carbon contents of inputs and outputsaccording to the procedures in §98.174(b)(2).Similarly, you must repeat the test to determine thesite-specific emission factor if data on the CO2emission rate, process production rate or processfeed rate are missing.emissions using the carbon mass balance procedurein §98.173(b)(1) or facilities that estimate emissionsusing the site-specific emission factor procedure in§98.173(b)(2).Q98.176(e)(e) If you use the carbon mass balance method in§98.173(b)(1) to determine CO2emissions, you mustreport the following information for each process:(e) If you use the carbon mass balance method in§98.173(b)(1) to determine CO2emissions, youmust, except as provided in §98.174(b)(4), report thefollowing information for each process:See preamble text for explanationQ98.177(b)(b) When the carbon mass balance method is used toestimate emissions for a process, the monthly massof each process input and output that are used todetermine the annual mass.(b) When the carbon massbalance method is used toestimate emissions for a process, the monthly massof each process input and output that are used todetermine the annual mass, except that nodetermination of the mass of steel output fromdecarburization vessels is required.Separate measurements of the mass of liquid steelinput to the decarburization vessel and decarburizedliquid steel output from the decarburization vesselare not required, because these masses are verynearly equal.S98.190 (a)(a) Lime manufacturing plants (LMPs) engage in themanufacture of a lime product (e.g., calcium oxide,high-calcium quicklime, calcium hydroxide,hydrated lime, dolomitic quicklime, dolomitichydrate, or other lime products) by calcination oflimestone, dolomite, shells or other calcareoussubstances as defined in 40 CFR 63.7081(a)(1).(a) Lime manufacturing plants (LMPs) engage in themanufacture of a lime product by calcination oflimestone, dolomite, shells or other calcareoussubstances as defined in 40 CFR 63.7081(a)(1).Clarifies the applicability.S98.193(a)(a) If all lime kilns meet the conditions specified in§98.33(b)(4)(ii) or (b)(4)(iii), you must calculate andreport under this subpart the combined process andcombustion CO2emissions by operating andmaintaining a CEMS to measure CO2emissionsaccording to the Tier 4 Calculation Methodologyspecified in §98.33(a)(4) and all associatedrequirements for Tier 4 in subpart C of this part(General Stationary Fuel Combustion Sources).(a) If all lime kilns meet the conditions specified in§98.33(b)(4)(ii) or (b)(4)(iii), you must calculate andreport under this subpart the combined process andcombustion CO2emissions from all lime kilns byoperating and maintaining a CEMS to measure CO2emissions according to the Tier 4 CalculationMethodology specified in §98.33(a)(4) and allassociated requirements for Tier 4 in subpart C ofthis part (General Stationary Fuel CombustionSources).Clarifies language.S98.193(b)(1)(1) Calculate and report under this subpart thecombined process and combustion CO2emissions by(1) Calculate and report under this subpart thecombined process and combustion CO2emissionsClarifies language.27SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeoperating and maintaining a CEMS to measureCO2emissions from all lime kilns according to the Tier 4Calculation Methodology specified in §98.33(a)(4)and all associated requirements for Tier 4 in subpartC of this part (General Stationary Fuel CombustionSources).from all lime kilns by operating and maintaining aCEMS to measure CO2emissions from all lime kilnsaccording to the Tier 4 Calculation Methodologyspecified in §98.33(a)(4) and all associatedrequirements for Tier 4 in subpart C of this part(General Stationary Fuel Combustion Sources).S98.193(b)(2)(2) Calculate and report process and combustionCO2emissions separately using the procedures specifiedin paragraphs (b)(2)(i) through (b)(2)(v) of thissection.(2) Calculate and report process and combustionCO2emissions from all lime kilns separately using theprocedures specified in paragraphs (b)(2)(i) through(b)(2)(v) of this section.Clarifies language.S98.193(b)(2)(ii)(ii) You must calculate a monthly emission factor foreach type of calcined byproduct/waste sold(including lime kiln dust) using Equation S–2 of thissection:(ii) You must calculate a monthly emission factor foreach type of calcined byproduct or waste sold(including lime kiln dust) using Equation S–2 of thissection:Clarifies language.S98.193(b)(2)(ii)EFLKD,I,N= Emission factor for calcined limebyproduct/waste type i sold, for month n (metric tonsCO2/ton lime product.EFLKD,I,N= Emission factor for calcined limebyproduct or waste type i sold, for month n (metrictons CO2/ton lime product.Clarifies a calculation term.S98.193(b)(2)(ii)CaOLKD,i,n= Calcium oxide content for calcined limebyproduct/ waste type i sold, for month n (metrictons CaO / metric ton lime).CaOLKD,i,n= Calcium oxide content for calcined limebyproduct or waste type i sold, for month n (metrictons CaO / metric ton lime).Clarifies a calculation term.S98.193(b)(2)(ii)MgOLKD,i,n= Magnesium oxide content for calcinedlime byproduct/waste type i sold, for month n (metrictons MgO / metric ton lime).MgOLKD,i,n=Magnesium oxide content for calcinedlime byproduct or waste type i sold, for month n(metric tons MgO / metric ton lime).Clarifies a calculation term.S98.193(b)(2)(iii)(iii) You must calculate the annualCO2emissionsfrom each type of calcined byproduct/waste that isnot sold (including lime kiln dust and scrubbersludge) using Equation S–3 of this section:(iii) You must calculate the annualCO2emissionsfrom each type of calcined byproduct or waste that isnot sold (including lime kiln dust and scrubbersludge) using Equation S–3 of this section:Clarifies language.S98.193(b)(2)(iii)Ewaste,i= AnnualCO2emissions for calcined limebyproduct/waste type i that is not sold (metric tonsCO2)Ewaste,i= AnnualCO2emissions for calcined limebyproduct or waste type i that is not sold (metric tonsCO2)Clarifies a calculation term.S98.193(b)(2)(iii)CaOwaste,i= Calcium oxide content for calcined limebyproduct/ waste type i that is not sold (metric tonsCaO / metric ton lime).CaOwaste,i= Calcium oxide content for calcined limebyproduct or waste type i that is not sold (metric tonsCaO / metric ton lime).Clarifies a calculation term.S98.193(b)(2)(iii)MgOWaste,i= Magnesium oxide content for calcinedlime byproduct/ waste type i that is not sold (metrictons MgO / metric ton lime).MgOWaste,i= Magnesium oxide content for calcinedlime byproduct or waste type i that is not sold(metric tons MgO / metric ton lime).Clarifies a calculation term.S98.193(b)(2)(iii)MWaste,i= Annual weight or mass of calcinedbyproducts/wastes for lime type i that is not soldMWaste,i= Annual weight or mass of calcinedbyproducts or wastes for lime type i that is not soldClarifies a calculation term.28SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChange(tons).(tons).S98.193b(2)(iv)(iv) You must calculate annualCO2processemissions for all kilns using Equation S–4 of thissection:(iv) You must calculate annualCO2processemissions for all lime kilns using Equation S–4 ofthis section:Clarifies language.S98.193b(2)(iv)ECO2= AnnualCO2process emissions from limeproduction from all kilns (metric tons/year).ECO2= AnnualCO2process emissions from limeproduction from all lime kilns (metric tons/year).Clarifies a calculation term and corrects subscripts.S98.193b(2)(iv)EFLKD,i,n= Emission factor of calcinedbyproducts/wastes sold for lime type i in calendarmonth n, (metric tons CO2/ton byproduct/waste)from Equation S–2 of this section.EFLKD,i,n= Emission factor of calcined byproducts orwastes sold for lime type i in calendar month n,(metric tons CO2/ton byproduct or waste) fromEquation S–2 of this section.Clarifies a calculation term.S98.193b(2)(iv)MLKD,i,n= Monthly weight or mass of calcinedbyproducts/waste sold (such as lime kiln dust, LKD)for lime type i in calendar month n (tons).MLKD,i,n= Monthly weight or mass of calcinedbyproducts or waste sold (such as lime kiln dust,LKD) for lime type i in calendar month n (tons).Clarifies a calculation term.S98.193b(2)(iv)Ewaste,i= AnnualCO2emissions for calcined limebyproduct/waste type i that is not sold (metric tonsCO2) from Equation S–3 of this section.Ewaste,i= AnnualCO2emissions for calcined limebyproduct or waste type i that is not sold (metric tonsCO2) from Equation S–3 of this section.Clarifies a calculation term.S98.193b(2)(iv)b = Number of calcined byproducts/wastes that aresold.b = Number of calcinedbyproducts or wastes that aresold.Clarifies a calculation term.S98.193b(2)(iv)z = Number of calcined byproducts/wastes that arenot sold.z = Number of calcined byproducts or wastes that arenot sold.Clarifies a calculation term.S98.194(a)(a)You must determine the total quantity of eachtype of lime product that is produced and eachcalcined byproduct/waste (such as lime kiln dust)that is sold. The quantities of each should be directlymeasured monthly with the same plant instrumentsused for accounting purposes, including but notlimited to, calibrated weigh feeders, rail or truckscales, and barge measurements. The directmeasurements of each lime product shall bereconciled annually with the difference in thebeginning of and end of year inventories for theseproducts, when measurements represent lime sold.(a) You must determine the total quantity of eachtype of lime product that is produced and eachcalcined byproduct or waste (such as lime kiln dust)that is sold. The quantities of each should be directlymeasured monthly with the same plant instrumentsused for accounting purposes, including but notlimited to, calibrated weigh feeders, rail or truckscales, and barge measurements. The directmeasurements of each lime product shall bereconciled annually with the difference in thebeginning of and end of year inventories for theseproducts, when measurements represent lime sold.Clarifies language.S98.194(b)(b) You must determine the annual quantity of eachcalcined byproduct/waste generated that is not soldby either direct measurement using the same(b) You must determine the annual quantity of eachcalcined byproduct or waste generated that is notsold by either direct measurement using the sameClarifies language.29SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeinstruments identified in paragraph (a) of this sectionor by using a calcined byproduct/waste generationrate.instruments identified in paragraph (a) of this sectionor by using a calcined byproduct or waste generationrate.S98.194(c)(c) You must determine the chemical composition(percent total CaO and percent total MgO) of eachtype of lime product that is produced and each typeof calcined byproduct/waste sold according toparagraph (c)(1) or (2) of this section. You mustdetermine the chemical composition of each type oflime product that is produced and each type ofcalcined byproduct/waste sold on a monthly basis.You must determine the chemical composition foreach type of calcined byproduct/waste that is notsold on an annual basis.(c) You must determine thechemical composition(percent total CaO and percent total MgO) of eachtype of lime product that is produced and each typeof calcined byproduct or waste sold according toparagraph (c)(1) or (2) of this section. You mustdetermine the chemical composition of each type oflime product that is produced and each type ofcalcined byproduct or waste sold on a monthly basis.You must determine the chemical composition foreach type of calcined byproduct or waste that is notsold on an annual basis.Clarifies language.S98.195(a)(a) For each missing value of the quantity of limeproduced (by lime type), and quantity of calcinedbyproduct/waste produced and sold, the substitutedata value shall be the best available estimate basedon all available process data or data used foraccounting purposes.(a) For each missing value of the quantity of limeproduced (by lime type), and quantity of calcinedbyproduct or waste produced and sold, the substitutedata value shall be the best available estimate basedon all available process data or data used foraccounting purposes.Clarifies language.S98.196(a)(1)(1) Method used to determine the quantity of limethat is produced and sold.(1) Method used to determine the quantity of limethat is produced and quantity of lime that is sold.Clarifies language.S98.196(a)(2)(2) Method used to determine the quantity ofcalcined lime byproduct/waste sold.(2) Method used to determine the quantity ofcalcined lime byproduct or waste sold.Clarifies language.S98.196(a)(4)(4) Beginning and end of year inventories forcalcined lime byproducts/wastes sold, by type.(4) Beginning and end of year inventories forcalcined lime byproducts or wastes sold, by type.Clarifies language.S98.196(a)(5)(5) Annual amount of calcined lime byproduct/wastesold, by type (tons).(5) Annual amount of calcined lime byproduct orwaste sold, by type (tons).Clarifies language.S98.196(a)(7)(7) Annual amount of calcined lime byproduct/wastethat is not sold, by type (tons).(7) Annual amountof calcined lime byproduct orwaste that is not sold, by type (tons).Clarifies language.S98.196(b)(1)(1) AnnualCO2process emissions from all kilnscombined (metric tons).(1) AnnualCO2process emissions from all limekilns combined (metric tons).Clarifies language.S98.196(b)(2)(2) Monthly emission factors for each lime typeproduced.(2) Monthly emission factors (metric tonCO2/tonlime product) for each lime product type produced.Clarifies language.S98.196(b)(3)(3) Monthly emissionfactors for each calcinedbyproduct/waste by lime type that is sold.(3) Monthly emission factors for each calcinedbyproduct or waste by lime type that is sold.Clarifies language.S98.196(b)(4)(4) Standard method used (ASTM or NLA testingmethod) to determine chemical compositions of each(4) Standard method used (ASTM or NLA testingmethod) to determine chemical compositions of eachClarifies language.30SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangelime type produced and each calcined limebyproduct/waste type.lime type produced and each calcined lime byproductor waste type.S98.196(b)(5)(5) Monthly results of chemical composition analysisof each type of lime product produced and calcinedbyproduct/waste sold.(5) Monthly results of chemical composition analysisof each type of lime product produced and calcinedbyproduct or waste sold.Clarifies language.S98.196(b)(6)(6) Annual results of chemical composition analysisof each type of lime byproduct/waste that is not sold.(6) Annual results of chemical composition analysisof each type of lime byproduct or waste that is notsold.Clarifies language.S98.196(b)(9)(9) Method used to determine the quantity ofcalcined lime byproduct/waste sold.(9) Method used to determine the quantity ofcalcined lime byproduct or waste sold.Clarifieslanguage.S98.196(b)(10)(10) Monthly amount of calcined limebyproduct/waste sold, by type (tons).(10) Monthly amount of calcined lime byproduct orwaste sold, by type (tons).Clarifies language.S98.196(b)(11)(11) Annual amount of calcined limebyproduct/waste that is not sold, by type (tons).(11) Annual amount of calcined lime byproduct orwaste that is not sold, by type (tons).Clarifies language.S98.196(b)(14)(14) Beginning and end of year inventories forcalcined lime byproducts/wastes sold.(14) Beginning and end of year inventories forcalcined lime byproducts or wastes sold.Clarifies language.V98.222(a)(a) You must reportN2Oprocess emissions fromeach nitric acid production train as required by thissubpart.(a) You must reportN2Oprocess emissions fromeach nitric acid train as required by this subpart.Clarifies language.V98.223(b)(b) You must conduct an annual performance test foreach nitric acid train according to paragraphs (b)(1)through (3) of this section.(b) Youmust conduct an annual performance test foreach nitric acid train according to paragraphs (b)(1)through (b)(3) of this section.Clarifies language.V98.223(b)(1)(1) You must conduct the performance test at theabsorber tail gas vent, referred to as the test point, foreach nitric acid train according to §98.224(b)through (f). If multiple nitric acid production unitsexhaust to a common abatement technology and/oremission point, you must sample each process in theducts before the emissions are combined, sampleeach process when only one process is operating, orsample the combined emissions when multipleprocesses are operating and base the site-specificemission factor on the combined production rate ofthe multiple nitric acid production units.(1)You must conduct the performance test at theabsorber tail gas vent, referred to as the test point, foreach nitric acid train according to §98.224(b)through (f). If multiple nitric acid trains exhaust to acommon abatement technology and/or emissionpoint, you must sample each process in the ductsbefore the emissions are combined, sample eachprocess when only one process is operating, orsample the combined emissions when multipleprocesses are operating and base the site-specificemission factor on the combined production rate ofthe multiple nitric acid trains.Clarifies terminology of the production unitsV98.223(b)(3)(3) You must measure the production rate during theperformance test and calculate the production rate forthe test period in metric tons (100 percent acid basis)(3) You must measure the production rate during theperformance test and calculate the production rate forthe test period in tons (100 percent acid basis) perClarifies units of measurement.31SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeper hour.hour.V98.223(d)(d)If nitric acid train “t” exhausts to anyN2Oabatement technology “N” after the test point, youmust determine the destruction efficiency for eachN2O abatement technology “N” according toparagraphs (d)(1), (d)(2), or (d)(3) of this section.(d) If nitric acid train “t” exhausts to anyN2Oabatement technology “N”, you must determine thedestruction efficiency for each N2O abatementtechnology “N” according to paragraphs (d)(1),(d)(2), or (d)(3) of this section.Clarifies requirement.V98.223(e)(e) If nitric acid train “t” exhausts to anyN2Oabatement technology “N” after the test point, youmust determine the annual amount of nitric acidproduced on train “t” while N2O abatementtechnology “N” is operating according to §98.224(f).Then you must calculate the abatement utilizationfactor for each N2O abatement technology “N” foreach nitric acid train “t” according to Equation V–2of this section.(e) If nitric acid train “t” exhausts to anyN2Oabatement technology “N”, you must determine theannual amount of nitric acid produced on nitric acidtrain “t” while N2O abatement technology “N” isoperating according to §98.224(f). Then you mustcalculate the abatement utilization factor for eachN2O abatement technology “N” for each nitric acidtrain “t” according to Equation V–2 of this section.Clarifies requirementV98.223(e)Pa,t,NPt,NCorrects equation termV98.223(g)(1)EN2Ot= AnnualN2Omass emissions from nitricacid production unit “t” according to this EquationV–3a (metric tons)EN2Ot= AnnualN2Omass emissions from nitricacid train “t” according to this Equation V–3a(metric tons).Clarifies terminology of the production unitsV98.223(g)(1)Pt= Annual nitric acid production from the train “t”(ton acid produced, 100 percent acid basis).Pt= Annual nitric acid production from nitric acidtrain “t” (ton acid produced, 100 percent acid basis).Clarifies an equation term.V98.223(g)(1)DF = Destruction efficiency ofN2Oabatementtechnology N that is used on nitric acid train “t”(percent of N2O removed from vent stream).DF = Destruction efficiency ofN2Oabatementtechnology N that is used on nitric acid train “t”(decimal fraction of N2O removed from vent stream).Corrects a calculation term.V98.223(g)(1)AF = Abatement utilization factor ofN2Oabatementtechnology “N” for nitric acid train “t” (percent oftime that the abatement technology is operating).AF = Abatement utilization factor ofN2Oabatementtechnology “N” for nitric acid train “t” (decimalfraction of annual production during whichabatement technology is operating).Clarifies an equation term.V98.223(g)(2)(2) If multipleN2Oabatement technologies arelocated in series after your test point, you must usethe emissions factor (determined in Equation V–1 ofthis section), the destruction efficiency (determinedin paragraph (d) of this section), the annual nitricacid production (determined in paragraph (f) of thissection), and the abatement utilization factor(determined in paragraph (e) of this section),according to Equation V–3b of this section:(2) If multipleN2Oabatement technologies arelocated in series after your test point, you must usethe emissions factor (determined in Equation V–1 ofthis section), the destruction efficiency (determinedin paragraph (d) of this section), the annual nitricacid production (determined in paragraph (i) of thissection), and the abatement utilization factor(determined in paragraph (e) of this section),according to Equation V–3b of this section:Corrects a paragraph referenceV98.223(g)(2)EN2Ot= AnnualN2Omass emissions from nitric acidEN2Ot= AnnualN2Omass emissions from nitric acidClarifies terminology of the production units32SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeproduction unit “t” according to this Equation V–3b(metric tons).train “t” according to this Equation V–3b (metrictons).V98.223(g)(2)EFN2O,t=N2Oemissions factor for unit “t” (lbN2O/ton nitric acid produced).EFN2O,t=N2Oemissions factor for nitric acid train“t” (lb N2O/ton nitric acid produced).Clarifies terminology of the production unitsV98.223(g)(2)Pt=Annual nitric acid produced from unit “t” (tonacid produced, 100 percent acid basis).Pt= Annual nitric acid produced from nitric acidtrain “t” (ton acid produced, 100 percent acid basis).Clarifies terminology of the production unitsV98.223(g)(2)DF1= Destruction efficiency ofN2Oabatementtechnology 1 (percent of N2O removed from ventstream).DF1= Destruction efficiency ofN2Oabatementtechnology 1 (decimal fraction of N2O removed fromvent stream).Corrects a calculation term.V98.223(g)(2)AF1= Abatement utilization factor ofN2Oabatementtechnology 1 (percent of time that abatementtechnology 1 is operating).AF1= Abatement utilization factor ofN2Oabatementtechnology 1 (decimal fraction of time thatabatement technology 1 is operating).Corrects a calculation term.V98.223(g)(2)DF2= Destruction efficiency ofN2Oabatementtechnology 2 (percent of N2O removed from ventstream).DF2= Destruction efficiency ofN2Oabatementtechnology 2 (decimal fraction of N2O removed fromvent stream).Corrects a calculation term.V98.223(g)(2)AF2= Abatement utilization factor ofN2Oabatementtechnology 2 (percent of time that abatementtechnology 2 is operating).AF2= Abatement utilization factor ofN2Oabatementtechnology 2 (decimal fraction of time thatabatement technology 2 is operating).Corrects a calculation term.V98.223(g)(2)DFN= Destruction efficiency ofN2Oabatementtechnology N (percent of N2O removed from ventstream).DFN= Destruction efficiency ofN2Oabatementtechnology N (decimal fraction of N2O removedfrom vent stream).Corrects a calculation term.V98.223(g)(2)AFN= Abatement utilization factor ofN2Oabatement technology N (percent of time thatabatement technology N is operating).AFN= Abatement utilization factor ofN2Oabatement technology N (decimal fraction of timethat abatement technology N is operating).Corrects a calculation term.V98.223(g)(3)(3) If multipleN2Oabatement technologies arelocated in parallel after your test point, you must usethe emissions factor (determined in Equation V–1 ofthis section), the destruction efficiency (determinedin paragraph (d) of this section), the annual nitricacid production (determined in paragraph (f) of thissection), and the abatement utilization factor(determined in paragraph (e) of this section),according to Equation V–3c of this section:(3) If multipleN2Oabatement technologies arelocated in parallel after your test point, you must usethe emissions factor (determined in Equation V–1 ofthis section), the destruction efficiency (determinedin paragraph (d) of this section), the annual nitricacid production (determined in paragraph (i) of thissection), and the abatement utilization factor(determined in paragraph (e) of this section),according to Equation V–3c of this section:Corrects a paragraph referenceV98.223(g)(3)EN2Ot= AnnualN2Omass emissions from nitric acidproduction unit “t” according to this Equation V–3c(metric tons).EN2Ot= AnnualN2Omass emissions from nitric acidtrain “t” according to this Equation V–3c (metrictons).Clarifies terminology of the production unitsV98.223(g)(3)EFN2O,t=N2Oemissions factor for unit “t” (lbN2O/ton nitric acid produced).EFN2O,t=N2Oemissions factor for nitric acid train“t” (lb N2O/ton nitric acid produced).Clarifies terminology of the production units33SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeV98.223(g)(3)Pt= Annual nitric acid produced from unit “t” (tonacid produced, 100 percent acid basis).Pt= Annual nitric acid produced from nitric acidtrain “t” (ton acid produced, 100 percent acid basis).Clarifies terminology of the production unitsV98.223(g)(3)DFN= Destruction efficiency ofN2Oabatementtechnology “N” (percent of N2O removed from ventstream).DFN= Destruction efficiency ofN2Oabatementtechnology “N” (decimal fraction of N2O removedfrom vent stream).Corrects a calculation term.V98.223(g)(3)AFN= Abatement utilization factor ofN2Oabatement technology “N” (percent of time thatabatement technology “N” is operating).AFN= Abatement utilization factor ofN2Oabatement technology “N” (decimal fraction of timethat abatement technology “N” is operating).Corrects a calculation term.V98.223(g)(3)FCN= Fraction control factor ofN2Oabatementtechnology “N” (percent of total emissions from unit“t” that are sent to abatement technology “N”).FCN= Fraction control factor ofN2Oabatementtechnology “N” (decimal fraction of total emissionsfrom nitric acid train “t” that are sent to abatementtechnology “N”).Corrects a calculation term.V98.223(g)(4)EN2Ot= AnnualN2Omass emissions from nitric acidproduction unit “t” according to this Equation V–3d(metric tons).EN2Ot= AnnualN2Omass emissions from nitric acidtrain “t” according to this Equation V–3d (metrictons).Corrects a calculation term.V98.223(i)(i) You must determine the total annual amount ofnitric acid produced on nitric acid train “t” for eachnitric acid train (tons acid produced, 100 percent acidbasis), according to §98.224(f).(i) You must determine the total annual amount ofnitric acid produced on each nitric acid train “t” (tonsacid produced, 100 percent acid basis), according to§98.224(f).Clarifies terminology of the production unitsV98.224(c)(c) You must determine the production rate(s) (100percent basis) from each nitric acid train during theperformance test according to paragraphs (c)(1) or(c)(2) of this section.(c) You must determine the production rate(s) (100percent acid basis) from each nitric acid train duringthe performance test according to paragraphs (c)(1)or (c)(2) of this section.Clarifies units for a calculation term.V98.224(e)(e) You must determine the total monthly amount ofnitric acid produced. You must also determine themonthly amount of nitric acid produced while N2Oabatement technology (located after the test point) isoperating from each nitric acid train. These monthlyamounts are determined according to the methods inparagraphs (c)(1) or (2) of this section.(e) You must determine the total monthly amount ofnitric acid produced. You must also determine themonthly amount of nitric acid produced while N2Oabatement technology is operating from each nitricacid train. These monthly amounts are determinedaccording to the methods in paragraphs (c)(1) or (2)of this section.Clarifies requirements.V98.224(f)(f) You must determine the annual amount of nitricacid produced. You must also determine the annualamount of nitric acid produced while N2O abatementtechnology (located after the test point) is operatingfor each train. These annual amounts are determinedby summing the respective monthly nitric acidquantities determined in paragraph (e) of this section.(f) You must determine the annual amount of nitricacid produced. You must also determine the annualamount of nitric acid produced while N2O abatementtechnology is operating for each nitric acid train.These annual amounts are determined by summingthe respective monthly nitric acid quantitiesdetermined in paragraph (e) of this section.Clarifies requirements.V98.226(a)(a) Train identification number.(a) Nitric Acid train identification number.Clarifies requirements.34SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeV98.226(n)(n) If you requested Administrator approval for analternative method of determining N2O emissionsunder §98.223(a)(2), each annual report must alsocontain the information specified in paragraphs(n)(1) through (4) of this section. (n)(1) through(n)(4) of this section for each nitric acid productionfacility.(n) If you requested Administrator approval for analternative method of determining N2O emissionsunder §98.223(a)(2), each annual report must alsocontain the information specified in paragraphs(n)(1) through (n)(4) of this section for each nitricacid production facility.Corrects typographical errorV98.226(o)(None)(o) [Reserved]Corrects typographical errorV98.226(p)(p) Fraction control factor for each abatementtechnology (percent of total emissions from theproduction unit that are sent to the abatementtechnology) if equation V–3c is used.(p) Fraction control factor for eachabatementtechnology (percent of total emissions from the nitricacid train that are sent to each abatement technology)if Equation V–3c is used.Clarifies terminology of the production unitsX98.242(b)(2)(2) If you comply with §98.243(c), reportCO2,CH4,and N2O combustion emissions under subpart C ofthis part (General Stationary Fuel CombustionSources) by following the requirements of subpart Conly for the combustion of supplemental fuel.Determine the applicable Tier in subpart C of thispart (General Stationary Fuel Combustion Sources)based on the maximum rated heat input capacity ofthe stationary combustion source.(2) If you comply with §98.243(c), reportCO2,CH4,and N2O combustion emissions under subpart C ofthis part (General Stationary Fuel CombustionSources) by following the requirements of subpartCfor all fuels, except emissions from burningpetrochemical process off-gas in any combustionunit are not to be reported under subpart C of thispart. Determine the applicable Tier in subpart C ofthis part (General Stationary Fuel CombustionSources) based on the maximum rated heat inputcapacity of the stationary combustion source.See preamble text for explanationX98.243(b)(b) Continuous emission monitoring system(CEMS). Route all process vent emissions andemissions from combustion of process off-gas to oneor more stacks and determine CO2emissions fromeach stack (except flare stacks) according to the Tier4 Calculation Methodology requirements in subpartC of this part. For each stack (except flare stacks)that includes emissions from combustion ofpetrochemical process off-gas, calculate CH4andN20 emissions in accordance with subpart C of thispart (use the Tier 3 methodology, emission factorsfor “Petroleum” in Table C–2 of subpart C of thispart, and either the default high heat value for fuelgas in Table C–1 of subpart C of this part or acalculated HHV, as allowed in Equation C–8 ofsubpart C of this part). For each flare, calculate CO2,(b) Continuous emission monitoring system(CEMS). Route all process vent emissions andemissions from stationary combustion units that burnany amount of process off-gas to one or more stacksand determine GHG emissions as specified inparagraphs (b)(1) through (3) of this section.(1)Determine CO2emissions from each stack (exceptflare stacks) according to the Tier 4 CalculationMethodology requirements in subpart C of this part.(2)For each stack (except flare stacks) that includesemissions from combustion of petrochemical processoff-gas, calculate CH4and N2O emissions inaccordance with subpart C of this part (use EquationC-10 and the "fuel gas" emission factors in Table C–2 of subpart C of this part).(3)For each flare, calculate CO2, CH4, and N2OSee preamble text for explanation35SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeCH4, andN2Oemissions using the methodologyspecified in §98.253(b)(1) through (b)(3).emissions using the methodology specified in§98.253(b)(1) through (b)(3).X98.243(c)(3)(3) Collect a sample of each feedstock and product atleast once per month and determine the carboncontent of each sample according to the proceduresof §98.244(b)(4). If multiple valid carbon contentmeasurements are made during the monthlymeasurement period, average them arithmetically.However, if a particular liquid or solid feedstock isdelivered in lots, and if multiple deliveries of thesame feedstock are received from the same supplysource in a given calendar month, only onerepresentative sample is required. Alternatively, youmay use the results of analyses conducted by a fuelor feedstock supplier, provided the sampling andanalysis is conducted at least once per month usingany of the procedures specified in §98.244(b)(4).(3) Collect a sample of each feedstock and product atleast once per month and determine the carboncontent of each sample according to the proceduresof §98.244(b)(4). If multiple valid carbon contentmeasurements are made during the monthlymeasurement period, average them arithmetically.However, if a particular liquid or solid feedstock isdelivered in lots, and if multiple deliveries of thesame feedstock are received from the same supplysource in a given calendar month, only onerepresentative sample is required. Alternatively, youmay use the results of analyses conducted by afeedstock supplier, or product customer, provided thesampling and analysis is conducted at least once permonth using any of the procedures specified in§98.244(b)(4).See preamble text forexplanationX98.243(c)(4)(4) If you determine that the monthly averageconcentration of a specific compound in a feedstockor product is greater than 99.5 percent by volume (ormass for liquids and solids), then as an alternative tothe sampling and analysis specified in paragraph(c)(3) of this section, you may calculate the carboncontent assuming 100 percent of that feedstock orproduct is the specific compound during periods ofnormal operation. This alternative may not be usedfor products during periods of operation when offspecification product is produced. You mustmaintain records of any determination made inaccordance with this paragraph (c)(4) along with allsupporting data, calculations, and other information.You must reevaluate determinations made under thisparagraph (c)(4) after any process change that affectsthe feedstock or product composition. You mustkeep records of the process change and thecorresponding composition determinations. If thefeedstock or product composition changes so that theaverage monthly concentration falls below 99.5(4) If you determine that the monthly averageconcentration of a specific compound in a feedstockor product is greater than 99.5 percent by volume ormass, then as an alternative to the sampling andanalysis specified in paragraph (c)(3) of this section,you may determine carbon content in accordancewith paragraphs (c)(4)(i) through (iii) of this section.(i) Calculate the carbon content assuming 100percent of that feedstock or product is the specificcompound.(ii) You must maintain records of any determinationmade in accordance with this paragraph (c)(4) alongwith all supporting data, calculations, and otherinformation.(iii) Reevaluate determinations made under thisparagraph (c)(4) after any process change that affectsthe feedstock or product composition. Keep recordsof the process change and the correspondingcomposition determinations. If the feedstock orproduct composition changes so that the averagemonthly concentration falls below 99.5 percent, youSee preamble text for explanation36SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangepercent, you are no longer permitted to use thisalternative method.are no longer permitted to use this alternativemethod.X98.243(c)(5)(i)Cg= Annual net contribution to calculated emissionsfrom carbon (C ) in gaseous materials(kilograms/year, kg/yr)(Fgf)i,n= Volume of gaseous feedstock i introduced inmonth "n" (standard cubic feet, scf ).(MWf)i= Molecular weight of gaseous feedstock i(kg/kg-mole).(Pgp)i,n= volume of gaseous product i produced inmonth "n" (scf).(MWp)i,n= Molecular wieght of gaseous product i(kg/kg-mole).Cg= Annual net contribution to calculated emissionsfrom carbon (C ) in gaseous materials, includingstreams containing CO2recovered for sale or use inanother process( kg/yr)(Fgf) = Volume or mass of gaseous feedstock iintroduced in month "n" (scf or kg). If you measuremass, the term (MWf)i/MVC is replaced with "1".(MWf)i,n= Molecular weight of gaseous feedstock iin month "n" (kg/kg-mole).(Pgp)i,n= Volume or mass of gaseous product iproduced in month "n" (scf or kg). If you measuremass, the term (MWp)i/MVC is replaced with "1".(MWp)i,n= Molecular wieght of gaseous product i inmonth "n" (kg/kg-mole).See preamble text for explanationX98.243(d)(3)(i)(i) For all gaseous fuels that contain ethylene processoff-gas, use the emission factors for "Petroleum" inTable C–2 of subpart C of this part (GeneralStationary Fuel Combustion Sources).(i) For all gaseous fuels that contain ethylene processoff-gas, use the emission factors for "Fuel Gas" inTable C–2 of subpart C of this part (GeneralStationary Fuel Combustion Sources).See preamble text for explanationX98.244(b)(4)(4) ...Analyses conducted in accordance withmethods specified in paragraphs (b)(4)(i) through(b)(4)(xv) of this section may be performed by theowner or operator, by an independent laboratory, orby the supplier of a feedstock.(4) ...Analyses conducted in accordance withmethods specified in paragraphs (b)(4)(i) through(b)(4)(xv) of this section may be performed by theowner or operator, by an independent laboratory, bythe supplier of a feedstock, or by a product customer.Harmonizing change with 40 CFR 98.243(c)(3).X98.244(b)(4)(xiii)(xiii) The results of chromatographic analysis of afeedstock or product, provided that the gaschromatograph is operated, maintained, andcalibrated according to the manufacturer'sinstructions.(xiii)The results of chromatographic analysis of afeedstock or product, provided that thechromatograph is operated, maintained, andcalibrated according to the manufacturer'sinstructions.See preamble text for explanationX98.244(b)(4)(xiv)(xiv) The carboncontent results of massspectrometer analysis of a feedstock or product,provided that the mass spectrometer is operated,maintained, and calibrated according to themanufacturer's instructions.(xiv) The results of mass spectrometer analysis of afeedstock or product, provided that the massspectrometer is operated, maintained, and calibratedaccording to the manufacturer's instructions.See preamble text for explanationX98.244(b)(4)(xv)(A)(A) An industry standard practice for carbon blackfeedstock oils and carbon black products.(A) An industry standard practice, or a methodpublished by a consensus-based standardsorganization if such a method exists, for carbonblack feedstock oils and carbon black products.See preamble text for explanation37SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeConsensus-based standards organizationsinclude,but are not limited to, the following: ASTMInternational (100 Barr Harbor Drive, P.O. BoxCB700, West Conshohocken, Pennsylvania 19428-B2959, (800) 262-1373, http://www.astm.org), theAmerican National Standards Institute (ANSI, 1819L Street, NW., 6th floor, Washington, DC 20036,(202) 293-8020, http://www.ansi.org ), the AmericanGas Association (AGA, 400 North Capitol Street,NW., 4th Floor, Washington, DC 20001, (202) 824-7000, http://www.aga.org ), the American Society ofMechanical Engineers (ASME, Three Park Avenue,New York, NY 10016-5990, (800) 843-2763,http://www.asme.org ), the American PetroleumInstitute (API, 1220 L Street, NW., Washington, DC20005-4070, (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 theMonitoring Plan required under § 98.3(g)(5).X98.244(c)(None)(c) Ifyou comply with §98.243(b) or (d), conductmonitoring and QA/QC for flares in accordance with§98.254.See preamble text for explanationX98.245IntroductoryparagraphFor missing feedstock flow rates, product flow rates,and carbon contents, use the same procedures as formissing flow rates and carbon contents for fuels asspecified in §98.35.For missing feedstock and product flow rates, usethe same procedures as for missing fuel usage asspecified in §98.35(b)(2). For missing feedstock andproduct carbon contents and missing molecularweights for gaseous feedstocks and products, use thesame procedures as for missing carbon contents andmissing molecular weights for fuels as specified in§98.35(b)(1). For missing flare data, follow theprocedures in §98.255(b) and (c).See preamble text for explanationX98.246(a)(6)(6) Name of each method listed in §98.244 used todetermine a measured parameter (or description ofmanufacturer's recommended method).(6)For each feedstock and product, provide theinformation specified in paragraphs (a)(6)(i) through(a)(6)(iii) of this section.(i) Name of each method used to determine carboncontent or molecular weight in accordance with98.244(b)(4);See preamble text for explanation38SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChange(ii)Description of each type of device (e.g., flowmeter, weighing device) used to determine flow ormass in accordance 98.244(b)(1) through (3).(iii) Identification of each method (i.e., methodnumber, title, or other description) used to determineflow or mass in accordance with 98.244(b)(1)through (3).X98.246(a)(8)(8) Identification of each combustion unit thatburned both process off-gas and supplemental fuel.(8) Identification of each combustion unit thatburned both process off-gas and supplemental fuel,including combustion units that are not part of thepetrochemical process unit.See preamble text for explanationX98.246(a)(9)(9) If you comply with thealternative to samplingand analysis specified in §98.243(c)(4), the amountof time during which off-specification product wasproduced, the volume or mass of off-specificationproduct produced, and if applicable, the date of anyprocess change that reduced the composition to lessthan 99.5 percent.(9) If you comply with the alternative to samplingand analysis specified in §98.243(c)(4), the numberof days during which off-specification product wasproduced, and if applicable, the date of any processchange that reduced the composition to less than 99.5percent.See preamble text for explanationX98.246(a)(11)(11) If you determine carbon content or compositionof a feedstock or product using a method under§98.244(b)(4)(xv)(B), report the information listed inparagraphs (a)(11)(i) through (a)(11)(iv) of thissection.(11) If you determine carbon content or compositionof a feedstock or product using a method under§98.244(b)(4)(xv)(B), report the information listed inparagraphs (a)(11)(i) through (a)(11)(iii) of thissection.Corrects cross-reference.X98.246(b)(2)(2) For CEMS used on stacks for stationarycombustion units, report the relevant informationrequired under §98.36 for the Tier 4 calculationmethodology. Section 98.36(b)(9)(iii) does not applyfor the purposes of this subpart.(2) For CEMS used on stacksthat include emissionsfrom stationary combustion units that burn anyamount 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 calculationmethodology. Sections §98.36(c)(2)( ii) and(c)(2)(ix) do not apply for the purposes of thissubpart.Clarifies CEMS reporting requirement to align moreclosely with procedures in e-GGRT and correctscross-reference.X98.246(b)(3)(3) For CEMS used on stacks that are not used forstationary combustion units, report the informationrequired under §98.36(e)(2)(vi).(3) For CEMS used on stacks that do not includeemissions from stationary combustion units, reportthe information required under §98.36(b)(6), (b)(7),and §98.36(e)(2)(vi).Clarifies CEMS reporting requirement to align moreclosely with procedures in e-GGRT.39SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeX98.246(b)(4)(4) TheCO2emissions from each stack and thecombined CO2emissions from all stacks (exceptflare stacks) that handle process vent emissions andemissions from stationary combustion units that burnprocess off-gas for the petrochemical process unit.For each stationary combustion unit (or group ofcombustion units monitored with a single CO2CEMS) that burns petrochemical process off-gas,provide an estimate based on engineering judgmentof the fraction of the total emissions that isattributable to combustion of off-gas from thepetrochemical process unit.(4) For each CEMSmonitoring locationthat meetsthe conditions in paragraph (b)(2) or (3) of thissection, provide an estimate based on engineeringjudgment of the fraction of the total CO2emissionsthat is attributable to the petrochemical process unit.Seepreamble text for explanationX98.246(b)(5)(5) For stationary combustion units that burn processoff-gas from the petrochemical process unit, reportthe information related to CH4and N2O emissions asspecified in paragraphs (b)(5)(i) through (b)(5)(iv) ofthis section.(i) The CH4and N2O emissions from each stack thatis monitored with a CO2CEMS, expressed in metrictons of each gas and in metric tons of CO2e. Foreach stack provide an estimate based on engineeringjudgment of the fraction of the total emissions that isattributable to combustion of off-gas from thepetrochemical process unit.(ii) The combined CH4and N2O emissions from allstationary combustion units, expressed in metric tonsof each gas and in metric tons of CO2e.(iii) The quantity of each type of fuel used inEquation C–8 in §98.33(c) for each stationarycombustion unit or group of units (as applicable)during the reporting year, expressed in short tons forsolid fuels, gallons for liquid fuels, and scf forgaseous fuels.(iv) The HHV (either default or annual average from(5) For each CEMSmonitoringlocation that meetsthe conditions in paragraph (b)(2) of this section,report the CH4and N2O emissions expressed inmetric tons of each gas. For each CEMS monitoringlocation, provide an estimate based on engineeringjudgment of the fraction of the total CH4and N2Oemissions that is attributable to combustion of offgas from the petrochemical process unit.(i)[Reserved](ii)[Reserved](iii)[Reserved](iv)[Reserved]See preamble text for explanation40SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangemeasured data) used in Equation C–8 in §98.33(c)for each stationary combustion unit or group ofcombustion units (as applicable).X98.246(b)(6)(6) ID or other appropriate descriptor of eachstationary combustion unit that burns process offgas.(6) [Reserved]See preamble text for explanationX98.246(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 requirementX98.247(b)(b) If you comply with the mass balancemethodology in §98.243(c), then you must retainrecords of the information listed in paragraphs (b)(1)through (b)(3) of this section.(1) Results of feedstock or product compositiondeterminations conducted in accordance with§98.243(c)(4).(2) Start and end times and calculated carboncontents for time periods when off-specificationproduct is produced, if you comply with thealternative methodology in §98.243(c)(4) fordetermining carbon content of feedstock or product.(b) If you comply with the mass balancemethodology in §98.243(c), then you must retainrecords of the information listed in paragraphs (b)(1)through (b)(4) of this section.(1) Results of feedstock or product compositiondeterminations conducted in accordance with§98.243(c)(4).(2) Start and end times for time periods when offspecification product is produced, if you complywith the alternative methodology in §98.243(c)(4)for determining carbon content of product.Corrects a reference and reduces recordkeepingrequirements when the alternative methodology in98.234 (c )(4) is used.X98.248Product, as used in §98.243, means each of thefollowing carbon-containing outputs from a process:the petrochemical, recovered byproducts, and liquidorganic 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 thefollowing carbon-containing outputs from a process:the petrochemical, recovered byproducts, and liquidorganic wastes that are not combusted onsite.Product does not include process vent emissions,fugitive emissions, or wastewater.The definition of product has been revised to provideconsistency with other subparts of this rule.Y98.252(a)(a) .... ForCH4andN2Oemissions from combustionof fuel gas, use the applicable procedures in 98.33 (c) for the same tier methodology that was used forcalculating CO2emissions. (Use the default CH4andN2O emission factors for "Petroleum (All fuel typesin Table C-1)" in Table C-2 of this part. For Tier 3...(a) .... ForCH4andN2Oemissions from combustionof fuel gas, use the applicable procedures in 98.33(c )for the same tier methodology that was used forcalculating CO2emissions. (Use the default CH4andN2O emission factors for "Fuel Gas" in Table C-2 ofthis part. For Tier 3....See preamble text for explanationY98.252(i)(i)CO2emissions from non-merchant hydrogenproduction process units (not including hydrogenproduced from catalytic reforming units) under thissubpart. You must follow the calculationmethodologies, monitoring and QA/QC methods,missing data procedures, reporting requirements, andrecordkeeping requirements of subpart P of this part.(i)CO2emissions from non-merchant hydrogenproduction process units (not including hydrogenproduced from catalytic reforming units) followingthe calculation methodologies, monitoring andQA/QC methods, missing data procedures, reportingrequirements, and recordkeeping requirements ofsubpart P of this part.Clarifies requirement41SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeY98.253(b)(2)EmFCH4= DefaultCH4emission factor for"PetroleumProducts" from Table C-2 of Subpart C ofthis part (General Staionary Fuel CombusionSources) (kg CH4/ MMBtu)EmFCH4= DefaultCH4emission factor for "FuelGas" from Table C-2 of Subpart C of this part(General Staionary Fuel Combusion Sources) (kgCH4/ MMBtu)See preamble text for explanationY98.253(b)(3)EmFN2O= DefaultN2Oemission factor for"PetroleumProducts" from Table C-2 of subpart C ofthis part (General Stationary Fuel CombustionSources) (kg N2O/MMBtu).EmFN2O= DefaultN2Oemission factor for "FuelGas" from Table C-2 of subpart C of this part(General Stationary Fuel Combustion Sources) (kgN2O/MMBtu).See preambletext for explanationY98.253(f)(2)(2) Flow measurement. If you have a continuousflow monitor on the sour gas feed to the sulfurrecovery plant, you must use the measured flow rateswhen the monitor is operational to calculate the sourgas flow rate. If you do not have a continuous flowmonitor on the sour gas feed to the sulfur recoveryplant, you must use engineering calculations,company records, or similar estimates of volumetricsour gas flow.(2) Flow measurement. If you have a continuousflow monitor on the sour gas feed to the sulfurrecovery plant or the sour gas feed sent for off-sitesulfur recovery, you must use the measured flowrates when the monitor is operational to calculate thesour gas flow rate. If you do not have a continuousflow monitor on the sour gas feed to the sulfurrecovery plant or the sour gas feed sent for off-sitesulfur recovery, you must use engineeringcalculations, company records, or similar estimatesof volumetric sour gas flow.Clarifies requirementY98.253(f)(3)(3) Carbon content. If you have a continuous gascomposition monitor capable of measuring carboncontent on the sour gas feed to the sulfur recoveryplant or if you monitor gas composition for carboncontent on a routine basis, you must use themeasured carbon content value. Alternatively, youmay develop a site-specific carbon content factorusing limited measurement data or engineeringestimates or use the default factor of 0.20.(3) Carbon content. If you have a continuous gascomposition monitor capable of measuring carboncontent on the sour gas feed to the sulfur recoveryplant or the sour gas feed sent for off-site for sulfurrecovery, or if you monitor gas composition forcarbon content on a routine basis, you must use themeasured carbon content value. Alternatively, youmay develop a site-specific carbon content factorusing limited measurement data or engineeringestimates or use the default factor of 0.20.Clarifies requirementY98.253(f)(4)(4) Calculate theCO2emissions from each sulfurrecovery plant using Equation Y–12 of this section.Where:FSG= Volumetric flow rate of sour gas feed(including sour water stripper gas) to the sulfurrecovery plant (scf/year).MFC= Mole fraction of carbon in the sour gas to thesulfur recovery plant (kg-mole C/kg-mole gas);default = 0.20.(4) Calculate theCO2emissions from each on-sitesulfur recovery plant and for sour gas sent off-site forsulfur recovery using Equation Y–12 of this section.Where:FSG= Volumetric flow rate of sour gas (includingsour water stripper gas)fed to the sulfur recoveryplant or the sour gas feed sent for off-site for sulfurrecovery (scf/year).MFC= Mole fraction of carbon in the sour gas fed tothe sulfur recovery plant or the sour gas feed sent forSee preamble text for explanation42SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeoff-site for sulfur recovery (kg-mole C/kg-mole gas);default = 0.20.Y98.253(j)(j) For each process vent not covered in paragraphs(a) through (i) of this section that can reasonably beexpected to contain greater than 2 percent by volumeCO2or greater than 0.5 percent by volume of CH4orgreater than 0.01 percent by volume (100 parts permillion) of N2O, calculate GHG emissions using theEquation Y–19 of this section. You must useEquation Y–19 of this section to calculate CH4emissions for catalytic reforming unitdepressurization and purge vents when methane isused as the purge gas or if you elected this method asan 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 beexpected to contain greater than 2 percent by volumeCO2or greater than 0.5 percent by volume of CH4orgreater than 0.01 percent by volume (100 parts permillion) of N2O, calculate GHG emissions using theEquation Y–19 of this section. You must also useEquation Y–19 of this section to calculate CH4emissions for catalytic reforming unitdepressurization and purge vents when methane isused as the purge gas, CH4emissions if you electedto use the method in (i)(1) of this section, and CO2and/or CH4emissions, as applicable, if you electedthis method as an alternative to the methods inparagraphs (f), (h), or (k) of this section.See preamble text for explanationY98.253(k)(k) For uncontrolled blowdown systems, you mustcalculate CH4emissions either using the methods forprocess vents in paragraph (j) of this sectionregardless of the CH4concentration or using EquationY20 of this section. Blowdown systems where theuncondensed gas stream is routed to a flare or similarcontrol device is considered to be controlled and isnot required to estimate emissions under thisparagraph (k).(k) For uncontrolled blowdown systems, you mustcalculate CH4emissions either using the methods forprocess vents in paragraph (j) of this sectionregardless of the CH4concentration or using EquationY-20 of this section. Blowdown systems where theuncondensed gas stream is routed to a flare or similarcontrol device is considered to be controlled and isnot required to estimate emissions under thisparagraph (k).Corrects typographical error in reference to equationY-20Y98.253(m)(m) For storage tanks, except as provided inparagraph (m)(4) of this section, calculate CH4emissions using the applicable methods inparagraphs (m)(1) through (m)(3) of this section.(m) For storage tanks, except as provided inparagraph (m)(3) of this section, calculate CH4emissions using the applicable methods inparagraphs (m)(1) and (m)(2) of this section.Corrects cross-referenceY98.256(f)(6)(6) If you use a CEMS, the relevant informationrequired under §98.36 for the Tier 4 CalculationMethodology, the CO2annual emissions as measuredby the CEMS (unadjusted to remove CO2combustion emissions associated with additionalunits, if present) and the process CO2emissions ascalculated according to §98.253(c)(1)(ii). Report theCO2annual emissions associated with sources otherthan those from the coke burn-off in the applicable(6) If you use a CEMS, the relevant informationrequired under §98.36 for the Tier 4 CalculationMethodology, the CO2annual emissions as measuredby the CEMS (unadjusted to remove CO2combustion emissions associated with additionalunits, if present) and the process CO2emissions ascalculated according to §98.253(c)(1)(ii). Report theCO2annual emissions associated with sources otherthan those from the coke burn-off in accordance withClarifies reporting requirements43SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangesubpart (e.g., subpart C of this part in the case of aCO boiler).the applicable subpart (e.g., subpart C of this part inthe case of a CO boiler).Y98.256(h)(h) For sulfur recovery plants and for emissions fromsour gas sent off-site for sulfur recovery, the ownerand operator shall report:(h) For on-site sulfur recovery plants and foremissions from sour gas sent off-site for sulfurrecovery, the owner and operator shall report:See preamble text for explanationY98.256(h)(2)(2) Maximum rated throughput of each independentsulfur recovery plant, in metric tons sulfurproduced/stream day, a description of the type ofsulfur recovery plant, and an indication of themethod used to calculate CO2annual emissions forthe sulfur recovery plant (e.g., CO2CEMS, EquationY–12, or process vent method in §98.253(j)).(2) For each on-site sulfur recovery plant, themaximum rated throughput (metric tons sulfurproduced/stream day), a description of the type ofsulfur recovery plant, and an indication of themethod used to calculate CO2annual emissions forthe sulfur recovery plant (e.g., CO2CEMS, EquationY–12, or process vent method in §98.253(j)).See preamble text for explanationY98.256(h)(3)(3) The calculatedCO2annual emissions for eachsulfur recovery plant, expressed in metric tons. Thecalculated annual CO2emissions from sour gas sentoff-site for sulfur recovery, expressed in metric tons.(3) The calculatedCO2annual emissions for eachon-site sulfur recovery plant, expressed in metrictons. The calculated annual CO2emissions from sourgas sent off-site for sulfur recovery, expressed inmetric tons.See preamble text for explanationY98.256(h)(4)(4) If you use Equation Y–12 of this subpart, theannual volumetric flow to the sulfur recovery plant(in scf/year), the molar volume conversion factor (inscf/kg-mole), and the annual average mole fractionof carbon in the sour gas (in kg-mole C/kg-molegas).(4) If you use Equation Y–12 of this subpart, theannual volumetric flow to the on-site and off-sitesulfur recovery plant (in scf/year), the molar volumeconversion factor (in scf/kg-mole), and the annualaverage mole fraction of carbon in the sour gas (inkg-mole C/kg-mole gas).See preamble text for explanationY98.256(h)(5)(5) If you recycle tail gas to the front of the sulfurrecovery plant, indicate whether the recycled flowrate and carbon content are included in the measureddata under §98.253(f)(2) and (3). Indicate whether acorrection for CO2emissions in the tail gas was usedin Equation Y–12. If so, then report the value of thecorrection, the annual volume of recycled tail gas (inscf/year) and the annual average mole fraction ofcarbon in the tail gas (in kg-mole C/kg-mole gas).Indicate whether you used the default (95%) or a unitspecific correction, and if used, report the approachused.(5) If you recycle tail gas to the front of an on-sitesulfur recovery plant, indicate whether the recycledflow rate and carbon content are included in themeasured data under §98.253(f)(2) and (3). Indicatewhether a correction for CO2emissions in the tail gaswas used in Equation Y–12. If so, then report thevalue of the correction, the annual volume ofrecycled tail gas (in scf/year) and the annual averagemole fraction of carbon in the tail gas (in kg-moleC/kg-mole gas). Indicate whether you used thedefault (95%) or a unit specific correction, and if aunit specific correction is used, report the approachused.See preamble text for explanationY98.256(h)(6)(6) If you use a CEMS, the relevant informationrequired under §98.36 for the Tier 4 CalculationMethodology, the CO2annual emissions as measured(6) If you use a CEMS, the relevant informationrequired under §98.36 for the Tier 4 CalculationMethodology, the CO2annual emissions as measuredClarifies reporting requirements44SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeby the CEMS and the annual processCO2emissionscalculated according to §98.253(f)(1). Report theCO2annual emissions associated with fuelcombustion subpart C of this part (GeneralStationary Fuel Combustion Sources).by the CEMS and the annual processCO2emissionscalculated according to §98.253(f)(1). Report theCO2annual emissions associated with fuelcombustion in accordance with subpart C of this part(General Stationary Fuel Combustion Sources).Y98.256(j) (10)(None)(10)If you use Equation Y-19 of this subpart, therelevant information required under paragraph (l)(5)of this section.See preamble text for explanationY98.256(k)(4)(4) For each set ofcoking drums that are the samedimensions: 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 alldelayed coking drums in the set, the typical ventingpressure (in psig), void fraction (in cf gas/cf ofvessel), and the mole fraction of methane in cokinggas (in kg-mole CF4/kg-mole gas, wet basis).(4) For each set of coking drums that are the samedimensions: 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 alldelayed coking drums in the set, the typical ventingpressure (in psig), void fraction (in cf gas/cf ofvessel), and the mole fraction of methane in cokinggas (in kg-mole CH4/kg-mole gas, wet basis).Corrects typographical error (CF4 toCHY98.256(k)(6)(None)(6) If you use Equation Y-19 of this subpart, therelevant information required under paragraph (l)(5)of this section for each set of coke drums or vesselsof the same size.See preamble text for explanationY98.256(o)(4)(vi)(vi) If you did not use Equation Y–23, the tank-specific methane composition data and the gasgeneration rate data used to estimate the cumulativeCH4emissions for storage tanks used to processunstabilized crude oil.(vi) If you did not use Equation Y–23, the tank-specific methane composition data and the annualgas generation volume (scf/yr) used to estimate thecumulative CH4emissions for storage tanks used toprocess unstabilized crude oil.Clarifies reporting requirementsY98.256(o)(5),(6), (7)(5) The method used to calculate the reported storagetank emissions for storage tanks processingunstabilized crude oil.(6) The quantity of unstabilized crude oil receivedduring the calendar year (in MMbbl), the averagepressure differential (in psi), and the mole fraction ofCH4in vent gas from the unstabilized crude oilstorage tank, and the basis for the mole fraction.(7) The tank-specific methane composition data andthe gas generation rate data, if you did not useEquation Y–23.(5) [Reserved][6) [Reserved](7) [Reserved]Removes duplicate reporting requirements.Z98.263(b)(1)(ii)(ii) If your process measurement provides theCO2emissions directly as an output...CO2n,i= Carbon dioxide emissions of a grab sample(ii) If your process measurement provides theCO2content directly as an output...CO2n,i= Carbon dioxide content of a grab sampleSee preamble text for explanation45SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangebatch of phosphate rock by origin i obtained duringmonth n (percent by weight, expressed as a decimalfraction).batch of phosphate rock by origin i obtained duringmonth n (percent by weight, expressed as a decimalfraction).Z98.264(a)(a) You must obtain a monthly grab sample ofphosphate rock directly from the rock being fed tothe process line before it enters the mill using oneofthe following methods. You may conduct therepresentative bulk sampling using a methodpublished by a consensus standards organization, oryou may use industry consensus standard practicemethods, including but not limited to the PhosphateMining States Methods Used and Adopted by theAssociation of Fertilizer and Phosphate Chemists(AFPC) (P.O. Box 1645, Bartow, Florida 33831,(863) 534–9755, http://afpc.net,paul.mcafee@mosaicco.com). If phosphate rock isobtained from more than one origin in a month, youmust obtain a sample from each origin of rock orobtain a composite representative sample.(a) You must obtain a monthly grab sample ofphosphate rock directly from the rock being fed tothe process line before it enters the mill using oneofthe following methods. You may conduct therepresentative bulk sampling using a methodpublished by a consensus standards organization, oryou may use industry consensus standard practicemethods, including but not limited to the PhosphateMining States Methods Used and Adopted by theAssociation of Fertilizer and Phosphate Chemists(AFPC). If phosphate rock is obtained from morethan one origin in a month, you must obtain a samplefrom each origin of rock or obtain a compositerepresentative sample.Deletesoutdated contact informationZ98.264(b)(b) You must determine the carbon dioxide orinorganic carbon content of each monthly grabsample of phosphate rock (consumed in theproduction of phosphoric acid). You may use amethod published by a consensus standardsorganization, or you may use industry consensusstandard practice methods, including but not limitedto the Phosphate Mining States Methods Used andAdopted by AFPC (P.O. Box 1645, Bartow, Florida33831, (863) 534–9755, http://afpc.net,paul.mcafee@mosaicco.com).(b) You must determine thecarbon dioxide orinorganic carbon content of each monthly grabsample of phosphate rock (consumed in theproduction of phosphoric acid). You may use amethod published by a consensus standardsorganization, or you may use industry consensusstandard practice methods, including but not limitedto the Phosphate Mining States Methods Used andAdopted by AFPC.Deletesoutdated contact informationZ98.265(a)(a) For each missing value of the inorganic carboncontent of phosphate rock or carbon dioxide (byorigin), you must use the appropriate default factorprovided in Table Z–1 this subpart. Alternatively,you must determine a substitute data value bycalculating the arithmetic average of the qualityassured values of inorganic carbon contents ofphosphate rock of origin i from samples immediatelypreceding and immediately following the missingA complete record of all measured parameters usedin the GHG emissions calculations is required.Therefore, whenever a quality-assured value of arequired parameter is unavailable, a substitute datavalue for the missing parameter must be used in thecalculations as specified in paragraphs (a) and (b) ofthis section.(a) For each missing value of the inorganic carboncontent or CO2content of phosphate rock (by origin),Correction; clarifies the general requirement formissing data, removes a duplicate paragraph,clarifies the data element of inorganic carbon contentmay also be represented by CO2content, and correctsthe equation reference.46SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangedata incident. You must document and keep recordsof the procedures used for all such estimates.(a) For each missing value of the inorganic carboncontent of phosphate rock (by origin), you must usethe appropriate default factor provided in Table Z–1of this subpart. Alternatively, the you must determinesubstitute data value by calculating the arithmeticaverage of the quality-assured values of inorganiccarbon contents of phosphate rock of origin i (seeEquation Z–1 of this subpart) from samplesimmediately preceding and immediately followingthe missing data incident. If no quality-assured dataon inorganic carbon contents of phosphate rock oforigin i are available prior to the missing dataincident, the substitute data value shall be the firstquality-assured value for inorganic carbon contentsfor phosphate rock of origin i obtained after themissing data period.you must use the appropriate default factor providedin Table Z–1 of this subpart. Alternatively, you mustdetermine a substitute data value by calculating thearithmetic average of the quality-assured values ofinorganic carbon contents or CO2contents ofphosphate rock of origin i (see Equation Z–1a or Z1b of this subpart) from samples immediatelypreceding and immediately following the missingdata incident. If no quality-assured data on inorganiccarbon contents or CO2contents of phosphate rockof origin i are available prior to the missing dataincident, the substitute data value shall be the firstquality-assured value for inorganic carbon contentsor CO2contents for phosphate rock of origin iobtained after the missing data period.Z98.266(a)(a) Annual phosphoric acid production by origin (aslisted in Table Z–1 to this subpart) of the phosphaterock (tons).(a) Annual phosphoric acid production, by origin ofthe phosphate rock (tons).Removes a reference to Table Z-1. The reportingelement could have a place of origin other than thoselisted in Table Z-1Z98.266(b)(b) Annual phosphoric acid permittedproductioncapacity (tons)(b) Annual phosphoric acid production capacity(tons)See preamble text for explanationZ98.266(d)(d) Annual phosphate rock consumption frommonthly measurement records by origin, (as listed inTable Z–1 to this subpart) (tons).(d) Annual phosphate rock consumption frommonthly measurement records by origin (tons).Clarifies reporting requirementsZ98.266(f)(5)(5) Monthly inorganic carbon content of phosphaterock for each wet-process phosphoric acid processline for which Equation Z–1a is used (percent byweight, expressed as a decimal fraction), or CO2(percent by weight, expressed as a decimal fraction)for which Equation Z–1b is used.(5) Monthly inorganic carbon content of phosphaterock for each wet-process phosphoric acid processline for which Equation Z–1a is used (percent byweight, expressed as a decimal fraction), or CO2content (percent by weight, expressed as a decimalfraction) for which Equation Z–1b is used.Clarifies reporting requirementsZ98.266(f)(6)(6) Monthly mass of phosphate rock consumed byorigin, (as listed in Table Z–1 of this subpart) inproduction for each wet-process phosphoric acidprocess line (tons).(6) Monthly mass of phosphate rock consumed, byorigin, in production for each wet-processphosphoric acid process line (tons).Clarifies reporting requirementsZ98.266(f)(8)(8) Number of times missing data procedures wereused to estimate phosphate rock consumption(months) and inorganic carbon contents of the(8) Number of times missing data procedures wereused to estimate phosphate rock consumption(months), inorganic carbon contents of the phosphateAdds reporting requirement for missing dataprocedures47SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangephosphate rock (months).rock (months), andCO2contents of the phosphaterock (months).Z98.267(a)(a) Monthly mass of phosphate rock consumed byorigin (as listed in Table Z–1 of this subpart) (tons).(a) Monthly mass of phosphate rock consumed byorigin (tons).Removes a reference to Table Z-1. The reportingelement could have a place of origin other than thoselisted in Table Z-1Z98.26(c )(c) Documentation of the procedures used to ensurethe accuracy of monthly phosphate rockconsumption by origin, (as listed in Table Z–1 of thissubpart).(c) Documentation of the procedures used to ensurethe accuracy of monthly phosphate rockconsumption by origin.Removes a reference to Table Z-1. The reportingelement could have a place of origin other than thoselisted in Table Z-1AA98.273(a)(3)(3) Calculate biogenicCO2emissions and emissionsof CH4and N2O from biomass using measuredquantities of spent liquor solids fired, site-specificHHV, 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 emission factor forCO2, CH4, or N2O, from Table AA–1 of this subpart(kg CO2, CH4, or N2O per mmBtu).(3) Calculate biogenicCO2emissions and emissionsof CH4and N2O from biomass using measuredquantities of spent liquor solids fired, site-specificHHV, and default emissions factors, according toEquation AA–1 of this section:***(Variable from Equation AA-1:)(EF) = Default emission factor for CO2, CH4, orN2O, from Table AA–1 of this subpart (kg CO2, CH4,or N2O per mmBtu).See preamble text for explanationAA98.276(e)(e) The default or site-specific emission factor forCO2, CH4, or N2O, used in Equation AA–1 of thissubpart (kg CO2, CH4, or N2O per mmBtu).(e) The default emission factor forCO2,CH4, orN2O, used in Equation AA–1 of this subpart (kgCO2, CH4, or N2O per mmBtu).Harmonize with change made to 98.273(a)(3)AA98.276(k)(k) Annual production of pulp and/or paper productsproduced (metric tons).(k) Annual production of pulp and/or paper productsproduced (metric tons) as follows:(1) Report the total annual production of unbleachedvirgin pulp produced onsite during the reporting yearin air-dried metric tons per year. This total annualproduction value is the sum of all kraft,semichemical, soda, and sulfite pulp produced onsite,prior to bleaching, through all virgin pulping lines.(i) Do not include secondary fiber repulped for paperproduction in the virgin pulp production total.(ii) You must report a positive (non-zero) value forpulp production unless your pulp mill did not operateduring the reporting year.(2) Report the total annual production of paperproducts exiting the paper machine(s), prior toapplication of any off-machine coatings, in air-driedSee preamble text for explanation48SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangemetric tons per year. If you operate multiple papermachines, report the sum (total) of the air-driedmetric tons of paper produced during the reportingyear for all paper machines at the mill.AATables AA-1& AA-2See Tables AA-1 and AA-2 in the current rule file.See Appendix A for changes to Table AA-1 and AA-2See preamble text for explanationBB98.282(a)(a)CO2andCH4process emissions from all siliconcarbide process units or furnaces combined.(a)CO2process emissions from all silicon carbideprocess units or furnaces combined.Seepreamble text for explanationBB98.283Introductoryparagraph98.283 Calculating GHG Emissions.You must calculate and report the annual processCO2emissions from each silicon carbide process unitor production furnace using the procedures in eitherparagraph (a) or (b) of this section. You mustdetermine CH4process emissions in accordance withthe procedures specified in paragraph (d) of thissection.98.283 Calculating GHG Emissions.You must calculate and report the combined annualprocess CO2emissions from all silicon carbideprocess units and production furnaces using theprocedures in either paragraph (a) or (b) of thissection.See preambletext for explanationBB98.283(a)(a) Calculate and report under this subpart theprocess CO2emissions by operating and maintainingCEMS according to the Tier 4 CalculationMethodology specified in §98.33(a)(4) and allassociated requirements for Tier 4 in subpart C ofthis part (General Stationary Fuel CombustionSources).(a) Calculate and report under this subpart thecombined annual process CO2emissions byoperating and maintaining CEMS according to theTier 4 Calculation Methodology specified in§98.33(a)(4) and all associated requirements for Tier4 in subpart C of this part (General Stationary FuelCombustion Sources).Harmonizingchange with 98.283 introductoryparagraph.BB98.283(b)(b) Calculate and report under this subpart theprocess CO2emissions using the procedures inparagraphs (b)(1) and (b)(2) of this section.(b) Calculate and report under this subpart thecombined annual process CO2emissions using theprocedures in paragraphs (b)(1) and (b)(2) of thissection.Harmonizingchangewith 98.283 introductoryparagraph.BB98.283(b)(2)(2) Use Equation BB–2 of this section to calculateannual CO2process emissions from all siliconecarbide production:(2) Calculate annualCO2process emissions from thesilicon carbide production facility according toEquation BB-2 of this section:Corrects misspelling and clarifies requirementBB98.283(b)(2)Tn= Petroleum coke consumption in month n(tons)Tn= Petroleum coke consumption incalendar monthn(tons)Clarifies equation termBB98.283(d)(d) You must calculate annual processCH4emissions from all silicon carbide productioncombined using Equation BB–3 of this section:Eq. BB-3(d) [Reserved]See preamble text for explanationBB98.286(b)(b) If a CEMS is not used to measure processCO2emissions, you must report the information listed in(b) If a CEMS is not used to measure processCO2emissions, you must report the information inCorrection for consistency with 40 CFR 98.282.49SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangethis paragraph (b) for all furnaces combined:paragraph (b)(1) through (b)(8) of this section for allsilicon carbide process units or production furnacescombined:DD98.304(c)(1)(1) Ensure that cylinders returned to the gas supplierare consistently weighed on a scale that is certified tobe accurate and precise to within 2 pounds of thescale's capacity and is periodically recalibrated perthe manufacturer's specifications. Either measureresidual gas (the amount of gas remaining in returnedcylinders) or have the gas supplier measure it. If thegas supplier weighs the residual gas, obtain from thegas supplier a detailed monthly accounting, within ±2 pounds, of residual gas amounts in the cylindersreturned to the gas supplier.(1) Ensure that cylinders returned to the gas supplierare consistently weighed on a scale that is certified tobe accurate and precise to within 2 pounds of trueweight and is periodically recalibrated per themanufacturer's specifications. Either measureresidual gas (the amount of gas remaining in returnedcylinders) or have the gas supplier measure it. If thegas supplier weighs the residual gas, obtain from thegas supplier a detailed monthly accounting, within ±2 pounds, of residual gas amounts in the cylindersreturned to the gas supplier.See preamble text for explanationDD98.304(c)(2)(2) Ensure that cylinders weighed for the beginningand end of year inventory measurements are weighedon a scale that is certified to be accurate to within 2pounds of the scale's capacity and is periodicallyrecalibrated per the manufacturer's specifications. Allscales used to measure quantities that are to bereported under §98.306 must be calibrated usingcalibration procedures specified by the scalemanufacturer. Calibration must be performed prior tothe first reporting year. After the initial calibration,recalibration must be performed at the minimumfrequency specified by the manufacturer.(2) Ensure that cylinders weighed for the beginningand end of year inventory measurements are weighedon a scale that is certified to be accurate and preciseto within 2 pounds of true weight and is periodicallyrecalibrated per the manufacturer's specifications. Allscales used to measure quantities that are to bereported under §98.306 must be calibrated usingcalibration procedures specified by the scalemanufacturer. Calibration must be performed prior tothe first reporting year. After the initial calibration,recalibration must be performed at the minimumfrequency specified by the manufacturer.See preamble text for explanationFF98.320(b)(1)(1) Each ventilation well or shaft, including boththose wells and shafts where gas is emitted and thosewhere gas is sold, used onsite, or otherwisedestroyed (including by flaring).(1) Each ventilation system shaft or vent hole,including both those points where mine ventilationair is emitted and those where it is sold, used onsite,or otherwise destroyed (including by ventilation airmethane (VAM) oxidizers).See preamble text forexplanationFF98.320(b)(2)(2) Each degasification system well or shaft,including degasification systems deployed before,during, or after mining operations are conducted in amine area. This includes both those wells and shaftswhere gas is emitted, and those where gas is sold,used onsite, or otherwise destroyed (including byflaring).(2) Each degasification system well or gob gas venthole, including degasification systems deployedbefore, during, or after mining operations areconducted in a mine area. This includes both thosewells and vent holes where coal bed gas is emitted,and those where the gas is sold, used onsite, orotherwise destroyed (including by flaring).See preamble text for explanation50SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeFF98.322(b)(b) You must reportCH4destruction from systemswhere gas is sold, used onsite, or otherwisedestroyed (including by flaring).(b) You must reportCH4destruction from systemswhere gas is sold, used onsite, or otherwisedestroyed (including by VAM oxidation and byflaring).See preamble text for explanationFF98.322(d)(d) You must report under this subpart theCO2emissions from coal mine gas CH4destructionoccurring at the facility, where the gas is not a fuelinput for energy generation or use ( e.g., flaring).(d) You must report under this subpart theCO2emissions from coal mine gas CH4destructionoccurring at the facility, where the gas is not a fuelinput for energy generation or use ( e.g., flaring andVAM oxidation).See preamble text for explanationFF98.323(a)V = Volumetric flow rate for the quarter (cfm) basedon sampling or a flow rate meter. If a flow rate meteris used and the meter automatically corrects fortemperature and pressure, replace “520°R/T × P/1atm” with “1”.V = Volumetric flow ratefor the quarter (acfm)based on sampling or a flow rate meter. If a flow ratemeter is used and the meter automatically corrects tostandard temperature and pressure, then use scfm andreplace “520°R/T × P/1 atm” with “1”.Clarifies an equation termFF98.323(a)MCF = Moisture correction factor for themeasurement period, volumetric basis.= 1 when V and C are measured on a dry basis or ifboth are measured on a wet basis.= 1-(fH2O)nwhen Vis measured on a wet basis and C is measured on adry basis.= 1/[1-(fH2O)] when V is measured on a drybasis and C is measured on a wet basis.MCF = Moisture correction factor for themeasurement period, volumetric basis.= 1 when V and C are measured on a dry basis or ifboth are measured on a wet basis.= 1-(fH2O) when Vis measured on a wet basis and C is measured on adry basis.= 1/[1-(fH2O)] when V is measured on a drybasis and C is measured on a wet basis.Corrects subscript errorsFF98.323(a)(fH2O) = Moisture content of the methane emittedduring the measurement period, volumetric basis(cubic feet water per cubic feet emitted gas).(fH2O) = Moisture content of the methane emittedduring the measurement period, volumetric basis(cubic feet water per cubic feet emitted gas).Corrects subscript errorsFF98.323(a)P = Pressure at which flow is measured (atm) for thequarter. The annual average barometric pressurefrom the nearest NOAA weather service station maybe used as a default.P = Absolute pressure at which flow is measured(atm) for the quarter. The annual average barometricpressure from the nearest NOAA weather servicestation may be used as a default.See preamble text for explanationFF98.323(a)(2)(2) Values of V, C, T, P, and (fH2O), if applicable...(2) Values of V, C, T, P, and (fH2O), ifapplicable...Corrects subscript errorsFF98.323(b)Equation FF3TTiCorrects subscript errorsFF98.323(b)Vi= Measured volumetric flow rate for the days inthe week when the degasification system is inoperation at that monitoring point, based onsampling or a flow rate meter (cfm). If a flow rateVi= Measured volumetric flow rate for the days inthe week when the degasification system is inoperation at that monitoring point, based onsampling or a flow rate meter (acfm). If a flow rateClarification of equation term51SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangemeter is used and the meter automatically correctsfor temperature and pressure, replace “520°R/Ti×Pi/1 atm” with “1”.meter is used and the meter automatically corrects tostandard temperature and pressure, then use scfm andreplace “520°R/Ti× Pi/1 atm” with “1”.FF98.323(b)fH2OfH2OCorrects subscript errorsFF98.323(b)Pi= Pressure at which flow is measured (atm).Pi= Absolute pressure at which flow is measured(atm).Clarifies an equation termFF98.323(b)(1)(1) Values ofV, C, T, P, and (fH2O), if applicablemust be based on measurements taken at least onceeach quarter with no fewer than 6 weeks betweenmeasurements. If measurements are taken morefrequently than once per quarter, then use theaverage value for all measurements taken. Ifcontinuous measurements are taken, then use theaverage value over the time period of continuousmonitoring.(1) Values of V, C, T, P, and (fH2O), if applicablemust be based on measurements taken at least onceeach quarter with no fewer than 6 weeks betweenmeasurements. If measurements are taken morefrequently than once per quarter, then use theaverage value for all measurements taken. Ifcontinuous measurements are taken, then use theaverage value over the time period of continuousmonitoring.Corrects subscript errors and typographical error.FF98.323(b)(2)CH4D(CH4D)i.jCorrects subscript errorsFF98.323(c)(c) If gas from degasification system wells orventilation shafts is sold, used onsite, or otherwisedestroyed (including by flaring), you must calculatethe quarterly CH4destroyed for each destructiondevice and each point of offsite transport to adestruction device, using Equation FF–5 of thissection. You must measure CH4content and flowrate according to the provisions in §98.324, andcalculate the methane routed to the destructiondevice (CH4) using either Equation FF–1 or EquationFF–3 of this section, as applicable.(c) If gas from a degasification system orventilationsystem is sold, used onsite, or otherwise destroyed(including by flaring or VAM oxidation), you mustcalculate the quarterly CH4destroyed for eachdestruction device and each point of offsite transportto a destruction device, using Equation FF–5 of thissection. You must measure CH4content and flowrate according to the provisions in §98.324, andcalculate the methane routed to the destructiondevice (CH4) using either Equation FF–1 or EquationFF–4 of this section, as applicable.Clarifies terminology and equation reference52SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeFF98.323 (c )Equation FF6Corrects equation termFF98.324(b)(b) ForCH4liberated from ventilation systems,determine whether CH4will be monitored from eachventilation well and shaft, from a centralizedmonitoring point, or from a combination of the twooptions. Operators are allowed flexibility foraggregating emissions from more than oneventilation well or shaft, as long as emissions fromall are addressed, and the methodology forcalculating total emissions documented. Monitor byone of the following options:(b) ForCH4liberated from ventilation systems,determine whether CH4will be monitored from eachventilation shaft and vent hole, from a centralizedmonitoring point, or from a combination of the twooptions. Operators are allowed flexibility foraggregating emissions from more than oneventilation point, as long as emissions from all areaddressed, and the methodology for calculating totalemissions documented. Monitor by one of thefollowing options:Clarifies rule text.FF98.324(c)(2)(2) Collect weekly (once each calendar week, with atleast three days between measurements) or morefrequent samples, for all degasification wells andgobgas vent holes. Determine weekly or more frequentflow rates, methane concentration, temperature, andpressure from these degasification wells and gob gasvent holes. Methane composition should bedetermined either by submitting samples to a lab foranalysis, or from the use of methanometers at thedegasification well site. Follow the samplingprotocols for sampling of methane emissions fromventilation shafts, as described in §98.324(b)(1).Youmust record the date of sampling, flow, temperature,pressure, and moisture measurements, the methaneconcentration (percent), the bottle number of samplescollected, and the location of the measurement or(2) Collect weekly (once each calendar week, with atleast three days between measurements) or morefrequent samples, for all degasification wells andgobgas vent holes. Determine weekly or more frequentflow rates, methane concentration, temperature, andpressure from these degasification wells and gob gasvent holes. Methane composition should bedetermined either by submitting samples to a lab foranalysis, or from the use of methanometers at thedegasification monitoring site. Follow the samplingprotocols for sampling of methane emissions fromventilation shafts, as described in §98.324(b)(1).Youmust record the date of sampling, flow, temperature,pressure, and moisture measurements, the methaneconcentration (percent), the bottle number of samplescollected, and the location of the measurement orClarifies rule text.53SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangecollection.collection.FF98.324(d)(2)(iii)CCH4CCH4Corrects subscript errorsFF98.326(a)(a) QuarterlyCH4liberated from each ventilationmonitoring point (CH4Vm), (metric tons CH4).(a) QuarterlyCH4liberated from each ventilationmonitoring point, (metric tons CH4).Clarifies rule textFF98.326(f)(f) Quarterly volumetric flow rate for eachventilation monitoring point (scfm), date andlocation of each measurement, and method ofmeasurement (quarterly sampling or continuousmonitoring), used in Equation FF–1 of this subpart.(f) Quarterly volumetric flow rate for eachventilation monitoring point and units of measure(scfm or acfm), date and location of eachmeasurement, and method of measurement (quarterlysampling or continuous monitoring), used inEquation FF–1 of this subpart.Harmonizes reporting requirement with equations.FF98.326(h)(h) Weekly volumetric flow rate used to calculateCH4liberated from degasification systems (cfm) andmethod of measurement (sampling or continuousmonitoring), used in Equation FF–3 of this subpart.(h) Weekly volumetric flow rate used to calculateCH4liberated from degasification systems and unitsof measure (acfm or scfm), and method ofmeasurement (sampling or continuous monitoring),used in Equation FF–3 of this subpart.Harmonizes reporting requirement with equationsFF98.326(i)(i) Quarterly CEMSCH4concentration (%) used tocalculate CH4liberated from degasification systems(average from daily data), or quarterly CH4concentration data based on results from weeklysampling data) (C).(i) QuarterlyCH4concentration (%) used to calculateCH4liberated from degasification systems and if thedata is based on CEMS or weekly sampling.Includes the basis of the concentration data in thereport.FF98.326(j)(j) Weekly volumetric flow rate used to calculateCH4destruction for each destruction device and eachpoint of offsite transport (cfm).(j) Weekly volumetric flow rate used to calculateCH4destruction for each destruction device and eachpoint of offsite transport, and units of measure (acfmor scfm).Harmonizes reporting requirement with equations.FF98.326(o)(o) Temperatures (°R), pressure (atm), and moisturecontent used in Equation FF–1 and FF–3 of thissubpart, and the gaseous organic concentrationcorrection factor, if Equation FF–9 was required.(o) Temperatures (°R), pressure (atm), moisturecontent, and the moisture correction factor (ifapplicable) used in Equation FF–1 and FF–3 of thissubpart; and the gaseous organic concentrationcorrection factor, if Equation FF–9 was required.See preambletext for explanationFF98.326(r)(r) Identification information and description foreach well and shaft, indication of whether the well orshaft is monitored individually, or as part of acentralized monitoring point. Note which method(sampling or continuous monitoring) was used.(r) Identification information and description foreach well and shaft, including paragraphs (r)(1)through (r)(3) of this section:(1) Indication of whether the well or shaft ismonitored individually, or as part of a centralizedmonitoring point. Note which method (sampling orSee preamble text for explanation54SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangecontinuous monitoring) was used.(2) Start date and close date of each well or shaft.(3) Number of days the well or shaft was inoperation during the reporting year.FF98.326(t)No current requirement(t) QuarterlyCH4routed to each destruction deviceor offsite transfer point used in Equation FF-5 of thissubpart (metric tons).See preamble text for explanationFF98.326(u)No current requirement(u) Mine Safetyand Health Administration (MSHA)identification for this coal mineSee preamble text for explanationHH98.343(a)(1)Equation HH1DOC = Degradable organic carbon from Table HH-1of this subpart or measurement data, if available[fraction (metric tons C/metric ton waste)].DOC = Degradable organic carbon from Table HH-1of this subpart [fraction (metric tons C/metric tonwaste)].See preamble text for explanationHHEquation HH-1, 98.345F = Fraction by volume ofCH4in landfill gas frommeasurement data on a dry basis, if available(fraction); default is 0.5.F = Fraction by volume ofCH4in landfill gas frommeasurement data for the current reporting year, ifavailable (fraction, dry basis, corrected to 0 percentoxygen); otherwise, use the default of 0.5.See preamble text for explanationHH98.343(b)(1)Equation HH4(C)n(CCH4)nCorrects equation termHH98.343(b)(1)Equation HH4N = Total number of measurement periods in a year.Use daily averaging periods for a continuousmonitoring system and N=365 (or N = 366 for leapyears). For weekly sampling, as provided inparagraph (b)(2) of this section, use N=52.N = Total number of measurement periods in a year.Use daily averaging periods for a continuousmonitoring system and N=365 (or N = 366 for leapyears). For monthly sampling, as provided inparagraph (b)(2) of this section, use N=12.See preamble text for explanationHHHH-40.0423=Density of CH4lb/cfm at 520°R or 60degrees Fahrenheit and 1 atm.0.0423= Density of CH4lb/cfat 520°R or 60degrees Fahrenheit and 1 atm.Corrects typographical errorHH98.343(b)(2)(i)(i) Continuously monitor gas flow rate and determinethe cumulative volume of landfill gas each week andthe cumulative volume of landfill gas each year thatis collected and routed to a destruction device(before any treatment equipment). Under this option,the gas flow meter is not required to automaticallycorrect for temperature, pressure, or, if necessary,moisture content. If the gas flow meter is notequipped with automatic correction for temperature,pressure, or, if necessary, moisture content, you mustdetermine these parameters as specified in paragraph(b)(2)(iii) of this section.(i) Continuously monitor gas flow rate and determinethe cumulative volume of landfill gas each monthand the cumulative volume of landfill gas each yearthat is collected and routed to a destruction device(before any treatment equipment). Under this option,the gas flow meter is not required to automaticallycorrect for temperature, pressure, or, if necessary,moisture content. If the gas flow meter is notequipped with automatic correction for temperature,pressure, or, if necessary, moisture content, you mustdetermine these parameters as specified in paragraph(b)(2)(iii) of this section.Harmonizing change to accommodate monthlysampling of CH4concentration55SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeHH98.343(b)(2)(ii)(ii) Determine theCH4concentration in the landfillgas that is collected and routed to a destructiondevice (before any treatment equipment) in alocation near or representative of the location of thegas flow meter at least once each calendar week; ifonly one measurement is made each calendar week,there must be at least three days betweenmeasurements.(ii) Determine theCH4concentrationin the landfillgas that is collected and routed to a destructiondevice (before any treatment equipment) in alocation near or representative of the location of thegas flow meter at least once each calendar month; ifonly one measurement is made each calendar month,there must be at least fourteen days betweenmeasurements.Harmonizing change to accommodate monthlysampling of CH4concentrationHH98.343(b)(2)(iii)(A)(A) Determine the temperature and pressure in thelandfill gas that is collected and routed to adestruction device (before any treatment equipment)in a location near or representative of the locationofthe gas flow meter at least once each calendar week;if only one measurement is made each calendarweek, there must be at least three days betweenmeasurements.(A) Determine the temperature and pressure in thelandfill gas that is collected and routed to adestruction device (before any treatment equipment)in a location near or representative of the locationofthe gas flow meter at least once each calendar month;if only one measurement is made each calendarmonth, there must be at least fourteen days betweenmeasurements.Harmonizing change to accommodate monthlysampling of CH4concentrationHH98.343(b)(2)(iii)(B)(B) If theCH4concentration is determined on a drybasis and flow is determined on a wet basis or CH4concentration is determined on a wet basis and flowis determined on a dry basis, and the flow meter doesnot automatically correct for moisture content,determine the moisture content in the landfill gas thatis collected and routed to a destruction device(before any treatment equipment) in a location nearor representative of the location of the gas flowmeter at least once each calendar week; if only onemeasurement is made each calendar week, theremust be at least three days between measurements.(B) If theCH4concentration is determined on a drybasis and flow is determined on a wet basis or CH4concentration is determined on a wet basis and flowis determined on a dry basis, and the flow meter doesnot automatically correct for moisture content,determine the moisture content in the landfill gas thatis collected and routed to a destruction device(before any treatment equipment) in a location nearor representative of the location of the gas flowmeter at least once each calendar month; if only onemeasurement is made each calendar month, theremust be at least fourteen days betweenmeasurements.Harmonizing change to accommodate monthlysampling of CH4concentrationHH98.343(c )(1)(Eq. HH-5)OX = Oxidation fraction. Use the default value of0.1 (10%).OX = Oxidation fraction. Use the appropriateoxidation fraction default value from Table HH-4 ofthis subpart.See preamble text for explanationHH98.343(c)(3)(i)(Eq. HH-6)See preamble text for explanationHH98.343(c(None)N = Number of landfill gas measurement locationsHarmonizingwithchanges to Equation HH()( )( )DestCHfDERRG×−×−14( )( ){ }∑∑==×−×−NnnDestnnNnnCHfDERRG1,11456SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChange)(3)(i)(Eq. HH-6)(associated with a destruction device or gas sent off-site). If a single monitoring location is used tomonitor volumetric flow and CH4concentration ofthe recovered gas sent to one or multiple destructiondevices, then N=1.multiple measurement locations and/or multipledestruction devicesHH98.343(c)(3)(i)(Eq. HH-6)R = Quantity of recoveredCH4from Equation HH-4of this section (metric tons).Rn= Quantity of recoveredCH4from Equation HH-4of this section for the nthmeasurement location(metric tons).Harmonizingwithchanges to Equation HHmultiple measurement locations and/or multipledestruction devicesHH98.343(c)(3)(i)(Eq. HH-6)OX = OX = Oxidation fraction. Use the defaultvalue of 0.1 (10%).OX = Oxidation fraction. Use the appropriateoxidation fraction default value from Table HH-4 ofthis subpart.See preamble text for explanationHH98.343(c)(3)(i)(Eq. HH-6)DE = Destruction efficiency (lesser of manufacturer'sspecified destruction efficiency and 0.99). If the gasis transported off-site for destruction, use DE = 1.DEn= Destruction efficiency (lesser ofmanufacturer's specified destruction efficiency and0.99) for the nth measurement location. If the gas istransported off-site for destruction, use DE = 1. If thevolumetric flow and CH4concentration of therecovered gas is measured at a single locationproviding landfill gas to multiple destruction devices(including some gas destroyed on-site and some gassent off-site for destruction), calculate DEnas thearithmetic average of the DE values determined foreach destruction device associated with thatmeasurement location.Harmonizingwithchanges to Equation HHmultiple measurement locations and/or multipledestruction devicesHH98.343(c)(3)(i)(Eq. HH-6)fDest= Fraction of hours the destruction device wasoperating (annual operating hours / 8760 hours peryear). If the gas is destroyed in a back-up flare (orsimilar device) or if the gas is transported off-sitefordestruction, use fDest= 1.fDest,n=Fraction of hours the destruction deviceassociated with the nthmeasurement location wasoperating during active gas flow calculated as theannual operating hours for the destruction devicedivided by the annual hours flow was sent to thedestruction device as measured at the nthmeasurement location. If the gas is destroyed in aback-up flare (or similar device) or if the gas istransported off-site for destruction, use fDest= 1. If thevolumetric flow and CH4concentration of therecovered gas is measured at a single locationproviding landfill gas to multiple destruction devices(including some gas destroyed on-site and some gassent off-site for destruction), calculate fDest,nas thearithmetic average of the fDestvalues determined forHarmonizingwithchanges to Equation HHmultiple measurement locations and/or multipledestruction devices andclarifies equation termmore accurately reflect operating hours of the gascollection system.57SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeeach destruction device associated with thatmeasurementHH98.343(c)(3)(ii)(Eq. HH-7)See preamble for discussionHH98.343(c)(3)(ii)(Eq. HH-8)See preamble for discussionHH98.343(c)(3)(ii)(Eq. HH-8)(None)N = Number of landfill gas measurement locations(associated with a destruction device or gas sent offsite). If a single monitoring location is used tomonitor volumetric flow and CH4concentration ofthe recovered gas sent to one or multiple destructiondevices, then N=1.Harmonizingwithchanges to Equation HHmultiple measurement locations and/or multipledestruction devicesHH98.343(c)(3)(ii)(Eq. HH-8)R = Quantity of recoveredCH4from Equation HH-4of this section (metric tons CH4).Rn= Quantity of recoveredCH4from Equation HH-4of this section for the nthmeasurement location(metric tons CH4).Harmonizingwithchanges to Equation HHmultiple measurement locations and/or multipledestruction devicesHH98.343(c)(3)(ii)(Eq. HH-8)fRec= Fraction of hours the recovery system wasoperating (annual operating hours/8760 hours peryear).fRec,n= Fraction of hours the recovery systemassociated with the nthmeasurement location wasoperating (annual operating hours/8760 hours peryear or annual operating hours / 8784 per year foraleap year).Harmonizingwithchanges to Equation HHmultiple measurement locations and/or multipledestruction devicesHH98.343(c)(3)(ii)(Eq. HH-8)OX = Oxidation fraction. Use the default value of0.1 (10%).OX = Oxidation fraction. Use appropriate oxidationfraction default value from Table HH-4 of thissubpart.See preamble text for explanationHH98.343(c)(3)(ii)(Eq. HH-8)DE = Destruction efficiency (lesser of manufacturer'sspecified destruction efficiency and 0.99). If thegasis transported off-site for destruction, use DE = 1.DEn= Destruction efficiency (lesser ofmanufacturer's specified destruction efficiency and0.99) for the nthmeasurement location. If the gas istransported off-site for destruction, use DE = 1. If thevolumetric flow and CH4concentration of theHarmonizingwithchanges to Equation HHmultiple measurement locations and/or multipledestruction devices( )( ){ }∑∑∑===×−×−NnnDestnnNnnNnncnfDERRfRCE1,11,Re11OX)-(1fRCE1MG1nRec,n×=∑=Nn( )( )DestcfDERfCER×−−×1Re( )( ){ }∑∑∑===×−×−NnnDestnnNnnNnncnfDERRfRCE1,11,Re1158SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangerecovered gas is measured at a single locationproviding landfill gas to multiple destruction devices(including some gas destroyed on-site and some gassent off-site for destruction), calculate DEnas thearithmetic average of the DE values determined foreach destruction device associated with thatmeasurement location.HH98.343(c)(3)(ii) (Eq. HH-8)FDest,= Fraction of hours the destruction device wasoperating (device operating hours/8760 hours peryear). If the gas is destroyed in a back-up flare (orsimilar device) or if the gas is transported off-sitefordestruction, use fDest= 1.fDest,n=Fraction of hours the destruction deviceassociated with the nthmeasurement location wasoperating during active gas flow calculated as theannual operating hours for the destruction devicedivided by the annual hours flow was sent to thedestruction device as measured at the nthmeasurement location. If the gas is destroyed in aback-up flare (or similar device) or if the gas istransported off-site for destruction, use fDest= 1. If thevolumetric flow and CH4concentration of therecovered gas is measured at a single locationproviding landfill gas to multiple destruction devices(including some gas destroyed on-site and some gassent off-site for destruction), calculate fDest,nas thearithmetic average of the fDestvalues determined foreach destruction device associated with thatmeasurement location.Harmonizingwithchanges to Equation HHmultiple measurement locations and/or multipledestruction devices and clarifies equation term tomore accurately reflect operating hours of gascollection systemHH98.344(e)(e) The owner or operator shall document theprocedures used to ensure the accuracy of theestimates of disposal quantities and, if applicable,gas flow rate, gas composition, temperature,pressure, and moisture content measurements. Theseprocedures include, but are not limited to, calibrationof weighing equipment, fuel flow meters, and othermeasurement devices. The estimated accuracy ofmeasurements made with these devices shall also berecorded, and the technical basis for these estimatesshall be provided.(e) For landfills electing to measure the fraction byvolume of CH4in landfill gas (F), follow therequirements in paragraphs (e)(1) and (e)(2) of thissection.(1) Use a gas composition monitor capable ofmeasuring the concentration of CH4on a dry basisthat is properly operated, calibrated, and maintainedaccording to the requirements specified in paragraph(b) of this section. You must either use a gascomposition monitor that is also capable ofmeasuring the O2concentration correcting for excess(infiltration) air or you must operate, maintain, andHarmonizing change to accommodate the correctionto 0 percent oxygen for CH4content of landfill gas59SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangecalibrate a second monitor capable of measuring theO2concentration on a dry basis according to themanufacturer's specifications.(2) Use Equation HH-10 of this section to correct themeasured CH4concentration to 0% oxygen. Ifmultiple CH4concentration measurements are madeduring the reporting year, determine F separately foreach measurement made during the reporting year,and use the results to determine the arithmeticaverage value of F for use in Equation HH–1 of thispart.F = (CCH4/100%)x[20.9c/(20.9-%O2)] (Eq. HH10)Where:F = Fraction by volume of CH4in landfill gas(fraction, dry basis, corrected to 0 percent oxygen).CCH4= Measured CH4concentration in landfill gas(volume percent, dry basis).20.9c= Defined O2correction basis, (volumepercent, dry basis).20.9 = O2concentration in air (volume percent, drybasis).%O2= Measured O2concentration in landfill gas(volume percent, dry basis).HH98.344(f)(None)(f) The owner or operator shall document theprocedures used to ensure the accuracy of theestimates of disposal quantities and, if applicable,gas flow rate, gas composition, temperature,pressure, and moisture content measurements. Theseprocedures include, but are not limited to, calibrationof weighing equipment, fuel flow meters, and othermeasurement devices. The estimated accuracy ofmeasurements made with these devices shall also berecorded, and the technical basis for these estimatesshall be provided.Harmonizing change. Moves paragraph toaccommodate new paragraph (e)HH98.345(c)(c) For missing daily waste disposal quantity data fordisposal in reporting years, the substitute value(c) For missing daily waste disposal quantity data fordisposal in the reporting year, the substitute valueSee preamble text for explanation60SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeshall be the average daily waste disposal quantity forthat day of the week as measured on the week beforeand week after the missing daily data.shall be the average daily waste disposal quantity forthat day of the week as measured on the week beforeand week after the missing daily data.HH98.346(d)(1)(1) Degradable organic carbon (DOC), methanecorrection factor (MCF), and fraction of DOCdissimilated (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 ofthe waste in the landfill was conducted during thereporting year, a description of the aeration system,including aeration blower capacity, the fraction ofthe landfill containing waste affected by the aeration,the total number of hours during the year the aerationblower was operated, and other factors used as abasis for the selected MCF value.(1) Degradable organic carbon (DOC) and fraction ofDOC dissimilated (DOCF) values used in thecalculations.See preamble text for explanationHH98.346(e)(e) Fraction ofCH4in landfill gas (F), and anindication of whether the fraction of CH4wasdetermined based on measured values or the defaultvalue(e) Fraction ofCH4in landfill gas (F), an indicationof whether the fraction of CH4was determined basedon measured values or the default value, and themethane correction factor (MCF) used in thecalculations. If an MCF other than the default of 1 isused, provide an indication of whether activeaeration of the waste in the landfill was conductedduring the reporting year, a description of theaeration system, including aeration blower capacity,the fraction of the landfill containing waste affectedby aeration, the total number of hours during the yearthe aeration blower was operated, and other factorsused as a basis for the selected MCF value.See preamble for discussion61SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeHH98.346(h)(h) For landfills without gas collection systems,theannual methane emissions (i.e., the methanegeneration, adjusted for oxidation, calculated usingEquation HH–5 of this subpart), reported in metrictons CH4, and an indication of whether passivevents and/or passive flares (vents or flares that arenot considered part of the gas collection system asdefined in §98.6) are present at this landfill.(h) For landfills without gas collection systems,theannual methane emissions (i.e., the methanegeneration, adjusted for oxidation, calculated usingEquation HH–5 of this subpart), reported in metrictons CH4, the oxidation fraction used in thecalculation, and an indication of whether passivevents and/or passive flares (vents or flares that arenot considered part of the gas collection system asdefined in §98.6) are present at this landfill.Harmonizes reporting requirements with calculationmethod.HH98.346(i)(5)(5) An indication of whether destruction occurs atthe landfill facility or offsite. If destruction occursatthe landfill facility, also report an indication ofwhether a back-up destruction device is present atthe landfill, the annual operating hours for theprimary destruction device, the annual operatinghours for the back-up destruction device (if present),and the destruction efficiency used (percent).(5) An indication of whether destruction occurs atthe landfill facility, off-site, or both. If destructionoccurs at the landfill facility, also report for eachmeasurement location an indication of whether aback-up destruction device is present at the landfill,the annual operating hours for the primarydestruction device, the annual operating hours for theback-up destruction device (if present), and thedestruction efficiency used (percent).Clarification to provide landfills that use both offand on-sitedestruction a clear and accurate reportingoption.HH98.346(i)(8)(8) Methane generation corrected for oxidationcalculated using Equation HH-5 of this subpart,reported in metric tons CH4.(8) Methane generation corrected for oxidationcalculated using Equation HH-5 of this subpart,reported in metric tons CH4, and the oxidationfraction used in the calculationHarmonizes reporting requirements with calculationmethod.HH98.346(i)(10)(8) Methane generation corrected for oxidationcalculated using Equation HH-7 of this subpart,reported in metric tons CH4.(8) Methane generation corrected for oxidationcalculated using Equation HH-7 of this subpart,reported in metric tons CH4, and the oxidationfraction used in the calculationHarmonizes reportingrequirements with calculationmethod.HH98.346(i)(11)(8) Methane generation corrected for oxidationcalculated using Equation HH-6 of this subpart,reported in metric tons CH4.(8) Methane generation corrected for oxidationcalculated using Equation HH-6 of this subpart,reported in metric tons CH4, and the oxidationfraction used in the calculationHarmonizes reporting requirements with calculationmethod.HH98.346(i)(12)(8) Methane generation corrected for oxidationcalculated using Equation HH-8 of this subpart,reported in metric tons CH4.(8) Methane generation corrected for oxidationcalculated using Equation HH-8 of this subpart,reported in metric tons CH4, and the oxidationfraction used in the calculationHarmonizes reporting requirements with calculationmethod.62SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeHH98.348(None)Landfill capacitymeansthe maximum amount ofsolid waste a landfill can accept. For the purposes ofthis subpart, for landfills that have a permit, thelandfill capacity can be determined in terms ofvolume or mass in the most recent permit issued bythe state, local, or Tribal agency responsible forregulating the landfill, plus any in-place waste notaccounted for in the most recent permit. If the owneror operator chooses to convert from volume to massto determine its capacity, the calculation mustinclude a site-specific density.Add definition to clarify meaning of term as used inthe rule.HH98.348(None)Leachate recirculationmeans the practice of takingthe leachate collected from the landfill andreapplying it to the landfill by any of one of a varietyof methods, including pre-wetting of the waste,direct discharge into the working face, spraying,infiltration ponds, vertical injection wells, horizontalgravity distribution systems, and pressuredistribution systems.Add definition to clarify meaning of term as usethe rule.HHTable HH-2Table HH-2See Appendix A for changes to Table HH-2Effect changes that were intended to be made in theOctober 28, 2010 (75 FR 66474) amendments andrevise the last line of this table to read "2009 and alllater years".HHTable HH-4NoneSee Appendix A for Table HH-4See preamble text for explanationII98.353(d)(2)-Eq. II-6fDest_1= Fraction of hours the primary destructiondevice was operating (device operating hours/hoursin the year). If the biogas is transported off-site fordestruction, use fDest= 1.fDest_1= Fraction of hours the primary destructiondevice was operating calculated as the annual hourswhen the destruction device was operating dividedby the annual operating hours of the biogas recoverysystem. If the biogas is transported off-site fordestruction, use fDest= 1.Clarifies an equation term to more accurately roperating hours of biogas recovery system.II98.353(d)(2)-Eq. II-6fDest_2= Fraction of hours the back-up destructiondevice was operating (device operating hours/hoursin the year).fDest_2= Fraction of hours the back-up destructiondevice was operating calculated as the annual hourswhen the destruction device was operating dividedby the annual operating hours of the biogas recoverysystem.Clarifies equation term to more accurately refleoperating hours of biogas recovery system.LL98.386(a)(1)(1) For each product listed in Table MM-1 of subpartMM of this part that enters the coal-to-liquid facilityto be further processed or otherwise used on site,report the annual quantity in metric tons or barrels by(1) [Reserved.]See preamble text for explanation63SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeeach quantity measurement standard method or otherindustry standard practice used. For natural gasliquids, quantity shall reflect the individualcomponents of the product.LL98.386(a)(4)(4) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (a)(1) of this section.(4) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (a)(2) of this section.Harmonizing change with 40 CFR 98.386(a)(1).LL98.386(a)(5)(5) For each product (leaving the coal-to-liquidfacility) listed in Table MM-1 of subpart MM of thispart, report the annual quantity in metric tons orbarrels by each quantity measurement standardmethod or other industry standard practice used. Fornatural gas liquids, quantity shall reflect theindividual components of the product. Thoseproducts that enter the facility, but are not reported in(a)(1), shall not be reported under this paragraph.(5) [Reserved.]See preamble text for explanationLL98.386(a)(8)(8) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (a)(5) of this section.(8) Each standardmethod or other industry standardpractice used to measure each quantity reported inparagraph (a)(6) of this section.Harmonizing change with 40 CFR 98.386(a)(5).LL98.386(a)(9)(v)(v) The calculatedCO2emissions factor.(v) The calculatedCO2emissions factor in metrictons CO2per barrel or per metric ton of product.Clarifies units of reporting requirementLL98.386(a)(11)(v)(v) The calculatedCO2emissions factor.(v) The calculatedCO2emissions factor in metrictons CO2per barrel or per metric ton of product.Clarifies units of reporting requirementLL98.386(a)(13)(13)For each specific type of biomass that enters thecoal-to-liquid facility to be co-processed with fossilfuel-based feedstock to produce a product reported inparagraph (a)(6) of this section, report the annualquantity in metric tons or barrels by each quantitymeasurement standard method or other industrystandard practice used.(13) [Reserved.]See preamble text for explanationLL98.386(a)(15)(15)Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (a)(3) of this section.(15) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (a)(14 ) of this section.Harmonizing change with 40 CFR 98.386(a)(13) andcorrects referenceLL98.386(a)(18)(18) AnnualCO2emissions in metric tons that wouldresult from the complete combustion or oxidation ofeach type of biomass feedstock co-processed withfossil fuel-based feedstocks reported in paragraph(a)(3) of this section, calculated according to§98.393(c).(18) AnnualCO2emissions in metric tons that wouldresult from the complete combustion or oxidation ofeach type of biomass feedstock co-processed withfossil 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) andcorrects reference64SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeLL98.386(b)(1)(1) For each product listed in Table MM-1 ofsubpartMM of this part, report the annual quantity in metrictons or barrels by each quantity measurementstandard method or other industry standard practiceused. For natural gas liquids, quantity shall reflectthe individual components of the product.1) [Reserved.]See preamble text for explanationLL98.386(b)(4)(4) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (b)(1) of this section.(4) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (b)(2) of this section.Harmonizing change with 40 CFR 98.386 (b)(1)LL98.386(b)(5)(v)(v) The calculatedCO2emissions factor in metrictons.(v) The calculatedCO2emissions factor in metrictons CO2per barrel or per metric ton of product.Clarifies units of reporting requirementLL98.386( c)(1)(1) For each product listed in Table MM-1 of subpartMM of this part, report the annual quantity in metrictons or barrels by each quantity measurementstandard method or other industry standard practiceused. For natural gas liquids, quantity shall reflectthe individual components of the product.(1) [Reserved.]See preamble text for explanationLL98.386( c)(4)(4)Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (c)(1) of this section(4) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (c)(2) of this sectionHarmonizing change with 40 CFR 98.386 (c)(1)LL98.386(c)(5)(v)(v) The calculatedCO2emissions factor in metrictons.(v) The calculatedCO2emissions factor in metrictons CO2per barrel or per metric ton of product.Clarifies units ofreporting requirementLL98.386(d)(2)(2) For a product that enters the facility to be furtherrefined or otherwise used on site that is a blendedfeedstock, producers must meet the reportingrequirements of paragraphs (a)(1) and (a)(2) of thissection by reflecting the individual components ofthe blended feedstock.(2) For a product that enters the facility to be furtherrefined or otherwise used on site that is a blendedfeedstock, producers must meet the reportingrequirements of paragraph (a)(2) of this section byreflecting the individual components of the blendedfeedstock.Harmonizing change with 40 CFR 98.386(a)(1).LL98.386(d)(3)(3) For a product that is produced, imported, orexported that is a blended product, producers,importers, and exporters must meet the reportingrequirements 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 theblended product.(3) For a product that is produced, imported, orexported that is a blended product, producers,importers, and exporters must meet the reportingrequirements of paragraphs (a)(6), (b)(2), and (c)(2)of this section, as applicable, by reflecting theindividual components of the blended product.Harmonizing change with 40 CFR 98.386(a)(1),(b)(1), and (c )(1)MM98.393(a)(1)Producti= Annual volume of product "i" produced,imported, or exported by the reporting party(barrels). For refiners, this volume only includesproducts ex refinery gate, and excludes products thatProducti= Annual volume of product "i" produced,imported, or exported by the reporting party(barrels). For refiners, this volume only includesproducts ex refinery gate, and excludes products thatUpdated reference to harmonize with changes to98.396(a)(1)65SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeentered the refinery but are not reported under98.396(a)(1). For natural gas liquids, volumes shallreflect the individual components of the product aslisted in Table MM-1 to subpart MM.entered the refinery but are not reported under98.396(a)(2). For natural gas liquids, volumes shallreflect the individual components of the product aslisted in Table MM-1 to subpart MM.MM98.393(a)(2)Producti=Annual mass of product "i" produced,imported, or exported by the reporting party (metrictons). For refiners, this mass only includes productsex refinery gate.Producti= Annual mass of product "i" produced,imported, or exported by the reporting party (metrictons). For refiners, this mass only includes productsex refinery gate, and excludes products that enteredthe refinery but are not reported under §98.396(a)(2).See preamble text for explanationMM98.393(h)(1)(1)A reporter using CalculationMethodology 1 todetermine the emission factor of a petroleum productshall calculate the CO2emissions associated withthat product using Equation MM–8 of this section inplace of Equation MM–1 of this section.(1) A reporter using Calculation Method1 todetermine the emission factor of a petroleum productshall calculate the CO2emissions associated withthat product using Equation MM–8 of this section inplace of Equation MM–1 of this section.Harmonizing change with 98.393(f)(1).MM98.393(h)(2)Arefinery using Calculation Methodology 1 of thissubpart to determine the emission factor of a noncrude petroleum feedstock shall calculate the CO2emissions associated with that feedstock usingEquation MM–9 of this section in place of EquationMM–2 of this section.(2) A refineryusing Calculation Method1 of thissubpart to determine the emission factor of a noncrude petroleum feedstock shall calculate the CO2emissions associated with that feedstock usingEquation MM–9 of this section in place of EquationMM–2 of this section.Harmonizing change with 98.393(f)(1).MM98.394(a)(1)(1) The quantity of petroleum products, natural gasliquids, and biomass, as well as the quantity of crudeoil measured on site at a refinery, shall bedetermined as follows:(1) The quantity of petroleum products, natural gasliquids, and biomass, shall be determined as follows:See preamble text for explanationMM98.394(a)(3)(3) The quantity of crude oil not measured on site ata refinery shall be determined according to one of thefollowing methods. You may use an appropriatestandard method published by a consensus-basedstandards organization or you may use an industrystandard practice.(3) The annual quantity of crude oil received shall bedetermined according to one of the followingmethods. You may use an appropriate standardmethod published by a consensus-based standardsorganization or you may use an industry standardpractice.See preamble text for explanation66SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeMM98.394(b)(None)(3) For units and processes thatoperate continuouslywith infrequent outages, it may not be possible tocomplete the calibration of a flow meter or othermeasurement device without disrupting normalprocess operation. In such cases, the owner oroperator may postpone the calibration until the nextscheduled maintenance outage. The best availableinformation from company records may be used inthe interim. Such postponements shall bedocumented in the monitoring plan that is requiredunder §98.3(g)(5).See preamble text for explanationMM98.394(c)(c) Procedures for Calculation Methodology 2 of thissubpart.(c) Procedures for Calculation Method2 of thissubpart.Harmonizing change with 98.393(f)(2).MM98.394(d)(d) Measurement of API gravity and sulfur contentof crude oil(4)[Reserved]See preamble text for explanationMM98.395(a)(a) Determination of quantity. Whenever the qualityassurance procedures in §98.394(a) cannot befollowed to measure the quantity of one or morepetroleum products, natural gas liquids, types ofbiomass, feedstocks, or crude oil batches during anyperiod (e.g., if a meter malfunctions), the followingmissing data procedures shall be used:(a)Determination of quantity. Whenever the qualityassurance procedures in §98.394(a) cannot befollowed to measure the quantity of one or morepetroleum products, natural gas liquids, types ofbiomass, feedstocks, or crude oil during any period(e.g., if a meter malfunctions), the following missingdata procedures shall be used:See preamble text for explanationMM98.395(b)(b) Determination of emission factor. Whenever anyof the procedures in §98.394(c) cannot be followedto develop an emission factor for any reason,Calculation Methodology 1 of this subpart must beused in place of Calculation Methodology 2 of thissubpart for the entire reporting year.(b) Determination of emission factor. Whenever anyof the procedures in §98.394(c) cannot be followedto develop an emission factor for any reason,Calculation Method 1 of this subpart must be used inplace of Calculation Method 2 of this subpart for theentire reporting year.Clarifies methodMM98.395(c )(c)Determination of API gravity and sulfur contentof crude oil. For missing data on sulfur content or(c ) [Reserved]See preamble text for explanation67SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeAPI gravity, the substitute data value shall be thearithmetic average of the quality-assured values ofAPI gravity or sulfur content in the batch precedingand the batch immediately following the missingdata incident. If no quality-assured data are availableprior to the missing data incident, the substitute datavalue shall be the first quality-assured values for APIgravity and sulfur content obtained from the batchafter the missing data period.MM98.396(a)(1)(1) For each petroleum product or naturalgas liquidlisted in table MM–1 of this subpart that enters therefinery to be further refined or otherwise used onsite, report the annual quantity in metric tons orbarrels by each quantity measurement standardmethod or other industry standard practice used. Fornatural gas liquids, quantity shall reflect theindividual components of the product.(1) [Reserved]See preamble text for explanationMM98.396(a)(4)(4) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (a)(1) of this section.(4) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (a)(2) of this section.Harmonizing change with 40 CFR 98.396(a)(1).MM98.396(a)(5)(5) Foreach petroleum product and natural gas liquid(ex refinery gate) listed in Table MM–1 of thissubpart, report the annual quantity in metric tons orbarrels by each quantity measurement standardmethod or other industry standard practice used. Fornatural gas liquids, quantity shall reflect theindividual components of the product. Petroleumproducts and natural gas liquids that enter therefinery, but are not reported in (a)(1), shall not bereported under this paragraph.(5) [Reserved]See preamble text for explanationMM98.396(a)(8)(8) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (a)(5) of this section.(8) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (a)(6) of this section.Harmonizing change with 40 CFR 98.396(a)(5).MM98.396(a)(9)(9) For every feedstock reported in paragraph (a)(2)of this section for which Calculation Methodology 2of this subpart was used to determine an emissionsfactor, report:(9) For every feedstock reported in paragraph (a)(2)of this section for which Calculation Method 2 ofthis subpart was used to determine an emissionsfactor, report:Corrects terminologyMM98.396(a)(9)(i(iii) The carbon share test results in percentmass(iii) The carbon share test results in percent massCorrects typographical error68SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeii)MM98.396(a)(9)(v)(v) The calculatedCO2emissions factor in metrictons.(v) The calculatedCO2emissions factor in metrictons CO2per barrel or per metric ton of product.Clarifies units of reporting requirementMM98.396(a)(10)(10) For every non-solid feedstock reported inparagraph (a)(2) of this section for which CalculationMethodology 2 of this subpart was used to determinean emissions factor, report:(10) For every non-solid feedstock reported inparagraph (a)(2) of this section for which CalculationMethod 2 of this subpart was used to determine anemissions factor, report:Clarifies methodMM98.396(a)(11)(11) For every petroleum product and natural gasliquid reported in paragraph (a)(6) of this section forwhich Calculation Methodology2 of this subpart wasused to determine an emissions factor, report:(11) For every petroleum product and natural gasliquid reported in paragraph (a)(6) of this section forwhich Calculation Method 2 of this subpart was usedto determine an emissions factor, report:Clarifies methodMM98.396(11)(iii)(iii) The carbonshare test results in percentmass.(iii) The carbon share test results in percentmass.Corrects typoMM98.396(a)(13)(13) For each specific type of biomass that enters therefinery to be co-processed with petroleumfeedstocks to produce a petroleum product reportedin paragraph (a)(6) of this section, report the annualquantity in metric tons or barrels by each quantitymeasurement standard method or other industrystandard practice used.(13) [Reserved]See preamble text for explanationMM98.396(a)(15)(15) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (a)(13) of this section.(15) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (a)(14) of this section.Harmonizing change with 40 CFR 98.396(a)(13)MM98.396(a)(18)(18) TheCO2emissions in metric tons that wouldresult from the complete combustion or oxidation ofeach type of biomass feedstock co-processed withpetroleum feedstocks reported in paragraph (a)(13)of this section, calculated according to §98.393(c).(18) TheCO2emissions in metric tons that wouldresult from the complete combustion or oxidation ofeach type of biomass feedstock co-processed withpetroleum feedstocks reported in paragraph (a)(14)of this section, calculated according to §98.393(c).Harmonizing change with 40 CFR 98.396(a)(13)MM98.396(a)(20)(20) All of the following information for all crude oilfeedstocks used at the refinery:(i) Batch volume in barrels.(ii) Weighted average API gravity representing thebatch at the point of entry at the refinery.(iii) Weighted average sulfur content representingthe batch at the point of entry at the refinery.(iv) Country of origin, of the batch, if known anddata in paragraphs (a)(20)(v) and (a)(20)(vi) of thissection are unknown.(20) For all crude oil that enters the refinery, reportthe annual quantity in barrels.See preamble text for explanation69SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChange(v) EIA crude stream codeand crude stream name ofthe batch, if known.(vi) Generic name for the crude stream and theappropriate EIA two-letter country or state andproduction area code of the batch, if known and noappropriate EIA crude stream code exists.MM98.396(a)(21)(21) The quantity of bulk NGLs in metric tons orbarrels received for processing during the reportingyear.(21) The quantity of bulkNGLs in metric tons orbarrels received for processing during the reportingyear. Report only quantities of bulk NGLs notreported in (a)(2) of this section.See preamble text for explanationMM98.396(a)(22)(22) Volume of crude oil in barrels that youinjectedinto a crude oil supply or reservoir. A volume ofcrude oil that entered the refinery, but was notreported in paragraphs (a)(2) or (a)(20), shall not bereported under this paragraph.(22) Volume of crude oil in barrels that you injectedinto a crude oil supply or reservoir.See preamble text for explanationMM98.396(a)(23)(23) Special provisions for 2010. For reporting year2010 only, a refiner that knows the informationunder a specific tier of the batch definition in 40CFR 98.398, but does not have the necessary datacollection and management in place to readily reportthis information, can use the next most appropriatetier of the batch definition for reporting batchinformation under paragraph 98.396(a)(20).(23) [Reserved]Special provisions for 2010 are no longer necessary.MM98.396(b)(1)(1) For each petroleumproduct and natural gas liquidlisted in Table MM–1 of this subpart, report theannual quantity in metric tons or barrels by eachquantity measurement standard method or otherindustry standard practice used. For natural gasliquids, quantity shall reflect the individualcomponents of the product.(1) [Reserved]See preamble text for explanationMM98.396(b)(2)(2) For each petroleum product and natural gas liquidlisted in Table MM–1 of this subpart, report theannual quantity in metric tons or barrels. For naturalgas liquids, quantity shall reflect the individualcomponents of the product as listed in Table MM–1of this subpart.(2) For each petroleum product and natural gas liquidlisted in Table MM–1 of this subpart, report theannual quantity in metric tons or barrels. For naturalgas liquids, quantity shall reflect the individualcomponents of the product.Clarifies reporting requirements. Reporting is notlimited to those components listed in Table MM70SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeMM98.396(b)(4)(4) Each standard method orother industry standardpractice used to measure each quantity reported inparagraph (b)(1) of this section.(4) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (b)(2) of this section.Harmonizing change with 40 CFR 98.396 (b)(1)MM98.396(b)(5)(5) For each product reported in paragraph (b)(2) ofthis section for which Calculation Methodology 2 ofthis subpart used was used to determine an emissionsfactor, report:(5) For each product reportedin paragraph (b)(2) ofthis section for which Calculation Method 2 of thissubpart used was used to determine an emissionsfactor, report:Clarifies methodMM98.396(b)(6)(6) For each non-solid product reported in paragraph(b)(2) of this section for which CalculationMethodology 2 of this subpart was used to determinean emissions factor, report:(6) For each non-solid product reported in paragraph(b)(2) of this section for which Calculation Method 2of this subpart was used to determine an emissionsfactor, report:Clarifies methodMM98.396( c)(1)(1) For each petroleumproduct and natural gas liquidlisted in Table MM–1 of this subpart, report theannual quantity in metric tons or barrels by eachquantity measurement standard method or otherindustry standard practice used. For natural gasliquids, quantity shall reflect the individualcomponents of the product.(1)[Reserved]See preamble text for explanationMM98.396( c)(4)(4) Each standard method or other industry standardpractice used to measure each quantity reported inparagraph (c)(1) of this section.(4) Eachstandard method or other industry standardpractice used to measure each quantity reported inparagraph (c)(2) of this section.Harmonizing change with 40 CFR 98.396 (c)(1)MM98.396(c)(5)(5) For each product reported in paragraph (c)(2) ofthis section for which Calculation Methodology 2 ofthis subpart was used to determine an emissionsfactor, report:(5) For each product reported in paragraph (c)(2) ofthis section for which Calculation Method 2 of thissubpart was used to determine an emissions factor,report:Clarifies methodMM98.396(c)(6)(6) For each non-solid product reported in paragraph(c)(2) of this section for which CalculationMethodology 2 of this subpart used was used todetermine an emissions factor, report:(6) For each non-solidproduct reported in paragraph(c)(2) of this section for which Calculation Method 2of this subpart used was used to determine anemissions factor, report:Clarifies methodMM98.396(d)(2)(2) For a product that enters the refinery to be furtherrefined or otherwise used on site that is a blendednon-crude feedstock, refiners must meet thereporting requirements of paragraphs (a)(1) and(a)(2) of this section by reflecting the individualcomponents of the blended non-crude feedstock.(2) For a product that enters the refinery to be furtherrefined or otherwise used on site that is a blendednon-crude feedstock, refiners must meet thereporting requirements of paragraphs (a)(2) of thissection by reflecting the individual components ofthe blended non-crude feedstock.Harmonizing change with 40 CFR 98.396 (a)(1)MM98.396(d)(3)(3) For a product that is produced, imported, or(3) For a product that is produced, imported, orHarmonizing change with 40 CFR 98.396 (a)(1),71SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeexported that is a blended product, refiners,importers, and exporters must meet the reportingrequirements 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 theblended product.exported that is a blended product, refiners,importers, and exporters must meet the reportingrequirements of paragraphs (a)(6), (b)(2), and (c)(2)of this section, as applicable, by reflecting theindividual components of the blended product.(b)(1), and (c )(1)MM98.397(b)(b) Reporters shall maintain records to supportquantities that are reported under this subpart,including records documenting any estimations ofmissing data and the number of calendar days in thereporting year for which substitute data procedureswere followed. For all reported quantities ofpetroleum products, natural gas liquids, and biomass,as well as crude oil quantities measured on site at arefinery, reporters shall maintain metering, gauging,and other records normally maintained in the courseof business to document product and feedstock flowsincluding the date of initial calibration and thefrequency of recalibration for the measurementequipment used.(b) Reporters shall maintain records to supportquantities that are reported under this subpart,including records documenting any estimations ofmissing data and the number of calendar days in thereporting year for which substitute data procedureswere followed. For all reported quantities ofpetroleum products, natural gas liquids, and biomass,reporters shall maintain metering, gauging, and otherrecords normally maintained in the course ofbusiness to document product and feedstock flowsincluding the date of initial calibration and thefrequency of recalibration for the measurementequipment used.Harmonizing change with 40 CFR 98.396(a)(20).MM98.397(d)(d) Reporters shall maintain laboratory reports,calculations and worksheets used in the measurementof density and carbon share for any petroleumproduct or natural gas liquid for which CO2emissions were calculated using CalculationMethodology 2.(d) Reporters shall maintain laboratory reports,calculations and worksheets used in the measurementof density and carbon share for any petroleumproduct or natural gas liquid for which CO2emissions were calculated using Calculation Method2.Clarifies methodMM98.398(None)Bulk NGLs for purposes ofreporting under thissubpartmeans mixtures of NGLs that are sold ordelivered as undifferentiated product.See preamble text for explanationMM98.398(None)Natural Gas Liquids (NGLs) for the purposes ofreporting under this subpartmeans hydrocarbons thatare separated from natural gas as liquids through theprocess of absorption, condensation, adsorption, orother methods, and are sold or delivered asdifferentiated product. Generally, such liquidsconsist of ethane, propane, butanes, or pentanes plus.See preamble text for explanation72SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeMM98.398Batch means either a volume of crude oil that entersa refinery or the components of such volume (e.g.,the volumes of different crude streams that areblended together and then delivered to a refinery).The batch volume is the first appropriate tier in thefollowing list:(1) Up to an annual volume of a type of crude oilidentified by an EIA crude stream code, if the EIAcrude stream code is known.(2) Up to an annual volume of a type of crude oilidentified by a generic name for the crude stream andan appropriate EIA two-letter country or state andproduction area code, if the generic name and EIAtwo-letter code are known but no appropriate EIAcrude stream code exists.(3) Up to a calendar month of crude oil volume froma single known foreign country of origin if the crudestream name is unknown.(4) Up to a calendar month of crude oil volume fromthe United States if the crude stream name andproduction area are unknown.(5) Up to a calendar month of crude oil volume if thecountry of origin is unknown.(None)MMTable MM-1Table MM-1See Appendix A for changes toTable MM-1See preamble text for explanationNN98.400(a)(a) Natural gas liquids fractionators are installationsthat fractionate natural gas liquids (NGLs) into theirconsitutent liquid products (ethane, propane, normalbutane, isobutane or pentanes plus) for supply todownstream facilities.(a) Natural gas liquids fractionators are installationsthat fractionate natural gas liquids (NGLs) into theirconstituent liquid products or mixtures of products(ethane, propane, normal butane, isobutane orpentanes plus) for supply to downstream facilities.Clarifies rule text.NN98.400(b)(b) Local Distribution Companies (LDCs) arecompanies that own or operate distribution pipelines,not interstate pipelines or intrastate pipelines, thatphysically deliver natural gas to end users and thatare regulated as separate operating companies byState public utility commissions or that operate asindependent municipally-owned distributionsystems.(b) Local Distribution Companies (LDCs) arecompanies that own or operate distribution pipelines,not interstate pipelines or intrastate pipelines, thatphysically deliver natural gas to end users and thatare within a single state that are regulated as separateoperating companies by State public utilitycommissions or that operate as independentmunicipally-owned distribution systems. LDCs donot include pipelines (both interstate and intrastate)delivering natural gas directly to major industrialSee preamble text for explanation73SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeusers and farm taps upstream of the local distributioncompany inlet.NN98.403(a)(2)Fuelh= Total annual volume of product “h” supplied(bbl or Mscf per year)Fuelh= Total annual volumeof product “h” supplied(volume per year, in Mscf for natural gas and bbl forNGLs).Clarifies equation term.NN98.403(b)(1)(1) For natural gas that is received for redelivery todownstream gas transmission pipelines and otherlocal distribution companies, use eEquation NN–3 ofthis section and the default values for the CO2emission factors found in Table NN–2 of thissubpart.***(1) For natural gas that is received for redelivery todownstream gas transmission pipelines and otherlocal distribution companies, use Equation NN–3 ofthis section and the default values for the CO2emission factors found in Table NN–2 of thissubpart.***.Corrects typographical errorNN98.403(b)(2)(i)(2)(i) For natural gas delivered to each meterregistering a supply equal to or greater than 460,000Mscf per year, use Equation NN–4 of this sectionand the default values for the CO2emission factorsfound in Table NN–2 of this subpart.(2)(i) For natural gas delivered to end-usersregistering a supply equal to or greater than 460,000Mscf per year, use Equation NN–4 of this sectionand the default values for the CO2emission factorsfound in Table NN–2 of this subpart.See preamble text for explanationNN98.403(b)(2)(ii)CO2k= AnnualCO2mass emissions that wouldresult from the combustion or oxidation of naturalgas received by end-users that receive a supply equalto or greater than 460,000 Mscf per year (metrictons).CO2k= AnnualCO2mass emissions that wouldresult from the combustion or oxidation of naturalgas delivered to each end-user that receives a supplyequal to or greater than 460,000 Mscf per year(metric tons).Clarifies rule text.NN98.403(b)(2)(ii)Fuel = Total annualvolume of natural gas supplied(Mscf per year).Fuel = Total annual volume of natural gas suppliedto this end-user, if known, otherwise, the annualvolume supplied to this meter (Mscf per year).Clarifies the definition of the equation term “Fuel” inEquation NN-4” . The input for the total annualvolume of natural gas must be the total annualvolume of natural gas supplied to the endknown.NN98.403(b)(3)(3) For natural gas received by the LDC at the citygate that is injected into on-system storage, and/orliquefied and stored, use Equation NN–5 of thissection and the default value for the CO2emissionfactors found in Table NN–2 of this subpart.Alternatively, a reporter-specific CO2emissionfactor may be used, provided it is developed usingmethods outlined in §98.404.CO2l= [Fuel1-Fuel2]*EF (Eq. NN-5)Where:CO2l= Annual CO2mass emissions that would resultfrom the combustion or oxidation of the net naturalgas that is liquefied and/or stored and not used for(3) For the net change in natural gas stored onsystem by the LDC during the reporting year, useEquation NN-5a of this section. For natural gas thatis received by means other than through the city gate,and is not otherwise accounted for by Equation NN-1or NN-2 of this section, use Equation NN-5b of thissection.(i) For natural gas received by the LDC that isinjected into on-system storage, and/or liquefied andstored, and for gas removed from storage and usedfor deliveries, use Equation NN–5a of this sectionand the default value for the CO2emission factorsfound in Table NN–2 of this subpart. Alternatively, aHarmonize with changes to equations-rationale for a complete explanation of the changes.74SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangedeliveries by the LDC within the reported year(metric tons).Fuel1 = Total annual volume of natural gas receivedby the LDC at the city gate and stored on-system orliquefied and stored in the reporting year (Mscf peryear).Fuel2= Total annual volume of natural gas that isused for deliveries in the reporting year that was nototherwise accounted for in Equation NN–1 or NN–2of this section (Mscf per year). This primarilyincludes natural gas previously stored on-system orliquefied and stored that is removed from storage andused for deliveries to customers or other LDCs bythe LDC within the reporting year. This also includesnatural gas that bypassed the city gate and wasdelivered directly to LDC systems from producers ornatural gas processing plants from local production.EF = Fuel-specific CO2emission factor (MTCO2/Mscf).reporter-specificCO2emissionfactor may be used,provided it is developed using methods outlined in§98.404.CO2l= [Fuel1-Fuel2]*EF (Eq. NN-5a)Where:CO2l= Annual CO2mass emissions that would resultfrom the combustion or oxidation of the net changein natural gas stored on system by the LDC withinthe reporting year (metric tons).Fuel1= Total annual volume of natural gas added tostorage on-system or liquefied and stored in thereporting year (Mscf per year).Fuel2= Total annual volume of natural gas that isremoved from storage or vaporized and removedfrom storage and used for deliveries to customers orother LDCs by the LDC within the reporting year(Mscf per year).EF = Annual average CO2emission factor for naturalgas placed into/removed from storage(MTCO2/Mscf).NN98.403(b)(3)(ii)(None)(ii)(ii) For natural gas received by the LDC thatbypassed the city gate, use Equation NN-5b of thissection. This includes natural gas received directlyby LDC systems from producers or natural gasprocessing plants from local production, received asa liquid and vaporized for delivery, or received fromany other source that bypassed the city gate. Use thedefault value for the CO2emission factors found inTable NN–2 of this subpart. Alternatively, a reporterspecific CO2emission factor may be used, providedit is developed using methods outlined in §98.404.CO2n= Fuelz* EFzWhere:CO2n= Annual CO2mass emissions that wouldresult from the combustion or oxidation of naturalgas received that bypassed the city gate and is nototherwise accounted for by Equation NN-1 or NN-2of this section (metric tons).Fuelz= Total annual volume of natural gas receivedHarmonize with changes to equations-rationale for a complete description of the changes.75SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangethat was not otherwise accounted for by EquationNN-1 or NN-2 of this section (natural gas fromproducers and natural gas processing plants fromlocal production, or natural gas that was received asa liquid, vaporized and delivered, and any othersource that bypassed the city gate) (Mscf per year).EFz= Fuel-specific CO2emission factor (MTCO2/Mscf).NN98.403(b)(4)(4) Calculate the totalCO2emissions that wouldresult from the complete combustion or oxidation ofthe annual supply of natural gas to end-users usingEquation NN–6 of this section.CO2= Sum(CO2i)-Sum(CO2j)-Sum(CO2k)-Sum(CO2l)Where:CO2= Annual CO2mass emissions that would resultfrom the combustion or oxidation of natural gasdelivered to LDC customers not covered inparagraph (b)(2) of this section (metric tons).CO2i=Annual CO2mass emissions that would resultfrom the combustion or oxidation of natural gasdelivered to transmission pipelines or other LDCs ascalculated in paragraph (b)(1) of this section (metrictons).CO2j= Annual CO2mass emissions that would resultfrom the combustion or oxidation of natural gasdelivered to transmission pipelines or other LDCs ascalculated in paragraph (b)(1) of this section (metrictons).CO2k= Annual CO2mass emissions that wouldresult from the combustion or oxidation of naturalgas received by end-users that receive a supply equalto or greater than 460,000 Mscf per year ascalculated in paragraph (b)(2) of this section (metrictons).CO2l= Annual CO2mass emissions that would resultfrom the combustion or oxidation of natural gasreceived by the LDC and liquefied and/or stored butnot used for deliveries within the reported year as(4) Calculate the totalCO2emissions that wouldresult from the complete combustion or oxidation ofthe annual supply of natural gas to end-users thatreceive a supply less than 460,000 Mscf per yearusing Equation NN–6 of this section.CO2= CO2i+CO2n-CO2j-∑CO2k-CO2l(Eq. NN-6)WhereCO2= Annual CO2mass emissions that would resultfrom the combustion or oxidation of natural gasdelivered to LDC end-users not covered in paragraph(b)(2) of this section (metric tons).CO2i= Annual CO2mass emissions that would resultfrom the combustion or oxidation of natural gasreceived at the city gate as calculated in paragraph(a)(1) or (a)(2) of this section (metric tons).CO2j= Annual CO2mass emissions that would resultfrom the combustion or oxidation of natural gasdelivered to transmission pipelines or other LDCs ascalculated in paragraph (b)(1) of this section (metrictons).CO2k= Annual CO2mass emissions that wouldresult from the combustion or oxidation of naturalgas delivered to each end-user that receives a supplyequal to or greater than 460,000 Mscf per year ascalculated in paragraph (b)(2) of this section (metrictons).CO2l= Annual CO2mass emissions that would resultfrom the combustion or oxidation of the net changein natural gas stored by the LDC within the reportedyear as calculated in paragraph (b)(3)(i) of thissection (metric tons).Harmonize with changes to equations-rationale for a complete explanation76SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangecalculated in paragraph (b)(3) of this section (metrictons).CO2n= AnnualCO2mass emissions that wouldresult from the combustion or oxidation of naturalgas that was received by the LDC directly fromsources bypassing the city gate, and is not otherwiseaccounted for in Equation NN-1 or NN-2 of thissection, as calculated in paragraph (b)(3)(ii) of thissection (metric tons).NN98.403( c)(2)(2) Calculatethe totalCO2equivalent emissions thatwould result from the combustion or oxidation offractionated NGLs supplied less the quantityreceived by other fractionators using Equation NN-8of this section.(2) Calculate the totalCO2equivalent emissions thatwould result from the combustion or oxidation offractionated NGLs supplied less the quantityreceived from other fractionators using EquationNN-8 of this section.Clarifies rule languageNN98.403( c)(2)CO2= AnnualCO2mass emissions that would resultfrom the combustion or oxidation of fractionatedNGLs delivered to customers or on behalf ofcustomers (metric tons).CO2= AnnualCO2mass emissions that would resultfrom the combustion or oxidation of fractionatedNGLs delivered to customers or on behalf ofcustomers less the quantity received from otherfractionators (metric tons).Clarifies calculation resultNN98.404(a)(5)(5) For an LDC using Equation NN–1 or NN–2 ofthis subpart, the point(s) of measurement for thenatural gas volume supplied shall be the LDC citygate meter(s).(5) For an LDC using Equation NN–1 or NN–2 ofthis subpart, the point(s) of measurement for thenatural gas volume received shall be the LDC citygate meter(s).Clarifies rule languageNN98.404(a)(7)(7) An LDC using Equation NN–4 of this subpartshall measure natural gas at the customer meters. Thereporter shall consider the volume delivered througha single particluar meter at a single particularlocation as the volume delivered to an individualend-user.(7) An LDC using Equation NN–4 of this subpartshall measure natural gas at the end-user’s meter(s).Where an end-user is known to have more than onemeter located at their facility, the reporter shallmeasure the natural gas at each meter and sum theannual volume delivered to all meters located at theend-user’s facility to determine the total volumedelivered to the end- user. Otherwise, the reportershall consider the total annual volume deliveredthrough each single meter at a single particularlocation to be the the volume delivered to anindividual end-user.Clarifies rule text.NN98.404(a)(8)(8) An LDC using Equation NN–5 of this subpartshall measure natural gas as follows:(i) Fuel1shall be measured at the on-system storageinjection meters and/or at the meters measuringnatural gas to be liquefied.(8) An LDC using Equation NN–5a and/or NN-5b ofthis subpart shall measure natural gas as follows:(i) Fuel1shall be measured at the on-system storageinjection meters and/or at the meters measuringnatural gas to be liquefied.Harmonize with changes to equations-rationale for a complete explanation77SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChange(ii) Fuel2shall be measured at the meters used formeasuring on-system storage withdrawals and/orLNG vaporization injection. If Fuel2is from a sourceother than storage, the appropriate meter shall beused to measure the quantity.(ii) Fuel2shall be measured at the meters used formeasuring on-system storage withdrawals and/orLNG vaporization injection.(iii) Fuelzshall be measured using establishedbusiness practices.NN98.404(a)(9)(9) An LDC shall measure all natural gas under thefollowing standard industry temperature and pressureconditions: Cubic foot of gas at a temperature of 60degrees Fahrenheit and at an absolute pressure offourteen and seventy-three hundredths (14.73)pounds per square inch.(9) An LDC shall measure all natural gas under thefollowing standard industry temperature and pressureconditions: Cubic foot of gas at a temperature of 60degrees Fahrenheit and at an absolute pressure of oneatmosphere.Clarified standard conditions for measurements.NN98.404(c )(2)(2) When a reporter usedthe default EF provided inthis section to calculate Equation NN–2, NN–3, NN–4, NN–5, or NN–7 of this subpart, the appropriatevalue shall be taken from Table NN–2 of thissubpart.(2) When a reporter used the default EF provided inthis section to calculate Equation NN-2, NN-3, NN4, NN-5a, NN-5b, or NN-7 of this subpart, theappropriate value shall be taken from Table NN-2 ofthis subpart.Harmonize with changes to equations-rationale for a complete explanationNN98.404(d)(1)(1)Equipment used to measure quantities inEquations NN–1, NN–2, and NN–5 of this subpartshall be calibrated prior to its first use for reportingunder this subpart, using a suitable standard methodpublished by a consensus based standardsorganization or according to the equipmentmanufacturer's directions.(1) Equipment used to measure quantities inEquations NN–1, NN–2, NN–5a and NN-5b of thissubpart shall be calibrated prior to its first use forreporting under this subpart, using a suitablestandard method published by a consensus basedstandards organization or according to the equipmentmanufacturer's directions.Harmonize with changes to equations-rationale for a complete explanationNN98.404(d)(2)(2) Equipment used to measure quantities inEquations NN–1, NN–2, and NN–5 of this subpartshall be recalibrated at the frequency specified by thestandard method used or by the manufacturer'sdirections.(2) Equipment used to measure quantities inEquations NN–1, NN–2, NN–5a, and NN-5b of thissubpart shall be recalibrated at the frequencyspecified by the standard method used or by themanufacturer's directions.Harmonize with changes to equations-rationale for a complete explanationNN98.404(d)(3)[(None)](3) Equipment used to measure quantities inEquations NN-3, and NN-4 of this subpart shall berecalibrated at the frequency commonly used withinthe industry.Clarification of when to calibrate equipment made incase of new reportersNN98.404(a)(5)5) For an LDC using Equation NN–1 or NN–2 ofthis subpart, the point(s) of measurement for thenatural gas volume supplied shall be the LDC citygate meter(s).5) For an LDC using Equation NN–1 or NN–2 ofthis subpart, the point(s) of measurement for thenatural gas volume received shall be the LDC citygate meter(s).Clarifies rule text.NN98.405( c)(3)(3) Whenever a NGL fractionator cannot follow thequality assurance procedures for developing areporter-specific HHV, as specified in §98.404,(3) [Reserved]Deleted duplicaterequirement78SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeduring any period for any reason, the NGLfractionator shall use the default HHV provided inTable NN–1 of this part for that period.NN98.406(a)(4)(4) Annual quantity (in barrels) of y-grade, bulkNGLs 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 notfractionated by the reporter.See preamble text for explanationNN98.406(a)(7)(7) AnnualCO2mass emissions (metric tons) thatwould result from the combustion or oxidation offractionated NGLs supplied less the quantityreceived by other fractionators, calculated inaccordance with §98.403(c)(2).(7) AnnualCO2mass emissions (metric tons) thatwould result from the combustion or oxidation offractionated NGLs supplied less the quantityreceived from other fractionators, calculated inaccordance with §98.403(c)(2). If the calculatedvalue is negative, the reporter shall report the valueas zero.Corrects regulatory textand resolves potential fornegative calculation result due to rounding ofemission factors.NN98.406(b)(2)(2) Annual volumein Mscf of natural gas placed intostorage.(2)Annual volume in Mscf of natural gas placedinto storage or liquified and stored (Fuel1inEquation NN-5a).Includes equation terms for clarity-see preamblerationale line 147.NN98.406(b)(3)(3) Annual volume in Mscf of vaporized liquefiednatural gas (LNG) produced at on-systemvaporization facilities for delivery on the distributionsystem that is not accounted for in paragraph (b)(1)of this section.(3) Annual volume in Mscf of natural gas withdrawnfrom on-system storage and annual volume in Mscfof vaporized liquefied natural gas (LNG) produced aton-system vaporization facilities withdrawn fromstorage for delivery on the distribution system (Fuel2in Equation NN-5a).Harmonize reportingrequirements with calculationchanges -see preamble rationale for a completeexplanationNN98.406(b)(4)(4) Annual volume in Mscf of natural gas withdrawnfrom on-system storage (that is not delivered to thecity gate) for delivery on the distribution system.(4) [Reserved]Reporting of revised definition Fuel 2 in98.406(b)(3) eliminates the need for this reportingelement.NN98.406(b)(5)(5) Annual volume in Mscf of natural gas delivereddirectly to LDC systems from producers or naturalgas processing plants from local production.(5) Annual volume in Mscf of natural gas thatbypassed the city gate(s) and was supplied throughthe LDC distribution system. This includes naturalgas from producers and natural gas processing plantsfrom local production, or natural gas that wasvaporized upon receipt and delivered, and any othersource that bypassed the city gate (Fuelz in EquationNN-5b).Harmonize reporting requirements with calculationchanges -see preamble rationale for a completeexplanationNN98.406(b)(7)(7) Annual volume in Mscf of natural gas deliveredby LDC to each meter registering supply equal to orgreater than 460,000 Mcsf during the calendar year.(7) Annual volume in Mscf of natural gas deliveredby the LDC to each end-user facility that receivedfrom the LDC deliveries equal to or greater than460,000 Mscf during the calendar year, if known;See preamble text for explanation79SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeotherwise, report the annual volume in Mscf ofnatural gas delivered by the LDC to each meterregistering supply equal to or greater than 460,000Mscf during the calendar year.NN98.406(b)(9)(9) AnnualCO2emissions (metric tons) that wouldresult from the complete combustion or oxidation ofthe annual supply of natural gas to end-usersregistering less than 460,000 Mcsf, calculated inaccordance with §98.403(b)(4).(9) AnnualCO2emissions (metric tons) that wouldresult from the complete combustion or oxidation ofthe annual supply of natural gas to end-usersregistering less than 460,000 Mscf, calculated inaccordance with §98.403(b)(4). If the calculatedvalue is negative, the reporter shall report the valueas zero.Corrects typographical error, and resolves potentialfor negative calculation result due to rounding ofemission factors.NN98.406(b)(12)(12) The customer name, address, and meter numberof each meter reading used to report in paragraph(b)(7) of this section.(12) The customer name, address, and meter numberof each end-user reported in paragraph (b)(7) of thissection. Additionally, report whether the quantity ofnatural gas reported in paragraph (b)(7) of thissection is the total quantity delivered to the end-user,or the quantity delivered to a specific meter.Clarifies rule text.NN98.407IntroductoryParagraph98.407 Records that must be retained.In addition to the information required by §98.3(g),each annual report must contain the followinginformation:98.407 Records that must be retained.In addition to the information required by §98.3(g),the reporter shall retain the following records:Corrects requirement.NN98.408-Table NN-1Table NN–1 to Subpart HH of Part 98—DefaultFactors for Calculation Methodology 1 of ThisSubpartSee Appendix A for changes toTable NN-1Corrects title of table, and harmonizes values withTable C-1.NN98.408-Table NN-2Table NN–2 to Subpart HH of Part 98—LookupDefault Values for Calculation Methodology 2 ofThis SubpartSee Appendix A for changes toTable NN-2Corrects title of table, and harmonizes values withTable C-1.PP98.423(a)(3)(i)(3) To aggregate data, use either Equation PP–3a orPP–3b in this paragraph, as appropriate.(i) For facilities with production process units thatcapture a CO2stream and either measure it aftersegregation or do not segregate the flow, calculatethe total CO2supplied in accordance with EquationPP–3a.(3) To aggregate data, use either Equation PP–3a orPP–3b in this paragraph, as appropriate.(i) For facilities with production process units orproduction wells that capture or extract a CO2streamand either measure it after segregation or do notsegregate the flow, calculate the total CO2suppliedin accordance with Equation PP–3a.See preamble text for explanationPP98.426(b)(4)(i) and (ii)(4) Report density as follows:(i) Quarterly density of CO2in metric tons perstandard cubic meter if you report the concentrationof the CO2stream in paragraph (b)(3) of this sectionin weight percent.(4) Report density as follows:(i) Quarterly density of the CO2stream in metric tonsper standard cubic meter if you report theconcentration of the CO2stream in paragraph (b)(3)of this section in weight percent.Clarifies reporting requirement80SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChange(ii) Quarterly density of theCO2stream in metrictons per standard cubic meter if you report theconcentration of the CO2stream in paragraph (b)(3)of this section in volume percent.(ii) Quarterly density ofCO2in metric tons perstandard cubic meter if you report the concentrationof the CO2stream in paragraph (b)(3) of this sectionin volume percent.PP98.426(f)(10)(10) Enhanced oil and natural gas recovery(10) Injection ofCO2for enhancedoil and naturalgas recovery that is covered by subpart UU of thispart.See preamble text for explanationPP98.426(f)(11)(11) Long-term storage (sequestration)(11) Geologic sequestration of carbon dioxide that iscovered by subpart RR of this part.See preamble text for explanationQQ98.433(a)St= Mass of fluorinated GHG per unit of equipmenttype t or foam type t (charge per piece of equipmentor cubic foot of foam, kg).St= Mass of fluorinated GHG per unit of equipmenttype t or foam type t (charge per piece of equipment,kg) or density of fluorinated GHG in foam (chargeper cubic foot of foam, kg per cubic foot).See preamble text for explanationQQ98.433(b)St= Mass inCO2e of the fluorinated GHGs per unitof equipment type t or foam type t (charge per pieceof equipment or cubic foot of foam, kg).St= Mass inCO2e of the fluorinated GHGs per unitof equipment type t or foam type t (charge per pieceof equipment, kg) or density of fluorinated GHG infoam (CO2e per cubic foot of foam, kg CO2e percubic foot).Clarifiesequation term.QQ98.434(b)(b) The inputs to the annual submission must bereviewed against the import or export transactionrecords to ensure that the information submitted toEPA is being accurately transcribed as the correctchemical or blend in the correct pre-chargedequipment or closed-cell foam in the correctquantities (metric tons) and units (kg per piece ofequipment or cubic foot of foam).(b) The inputs to the annual submission must bereviewed against the import or export transactionrecords to ensure that the information submitted toEPA is being accurately transcribed as the correctchemical or blend in the correct pre-chargedequipment or closed-cell foam in the correctquantities and units.Clarifies intent of the requirement.QQ98.436(a)(3)(3) For closed-cell foams that are imported inside ofappliances, the identity of the fluorinated GHGcontained in the foam in each appliance, the mass ofthe fluorinated GHG contained in the foam in eachappliance, and the number of appliances importedwith each unique combination of mass and identityof fluorinated GHG within the closed-cell foams.(3) For closed-cell foams that are imported inside ofequipment, the identity of the fluorinated GHGcontained in the foam in each appliance, the mass ofthe fluorinated GHG contained in the foam in eachpiece of equipment, and the number of pieces ofequipment imported with each unique combinationof mass and identity of fluorinated GHG within theclosed-cell foams.See preamble text for explanationQQ98.436(a)(4)(4) For closed cell-foams that are not imported insideof appliances, the identity of the fluorinated GHG inthe foam, the density of the fluorinated GHG in thefoam (kg fluorinated GHG/cubic foot), and thevolume of foam imported (cubic feet) for each type(4) For closed cell-foams that arenot imported insideof equipment, the identity of the fluorinated GHG inthe foam, the density of the fluorinated GHG in thefoam (kg fluorinated GHG/cubic foot), and thevolume of foam imported (cubic feet) for each typeSee preamble text for explanation81SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeof closed-cell foam with a unique combination offluorinated GHG density and identity.of closed-cell foam with a unique combination offluorinated GHG density and identity.QQ98.436(a)(5)(5) Dates on which the pre-charged equipment orclosed-cell foams were imported.(5) [Reserved.]See preamble text for explanationQQ98.436(a)(6)(ii)(ii) For closed-cell foamsthat are imported inside ofappliances, the mass of the fluorinated GHGs inCO2e contained in the foam in each appliance andthe number of appliances imported for each type ofappliance.(ii) For closed-cell foams that are imported inside ofequipment, the mass of the fluorinated GHGs inCO2e contained in the foam in each piece ofequipment and the number of pieces of equipmentimported for each equipment type.See preamble text for explanationQQ98.436(a)(6)(iii)(iii) For closed-cell foams that are notimportedinside of appliances, the mass in CO2e of thefluorinated GHGs in the foam (kg CO2e/cubic foot)and the volume of foam imported (cubic feet) foreach type of closed-cell foam.(iii) For closed-cell foams that are not importedinside of equipment, the density in CO2e of thefluorinated GHGs in the foam (kg CO2e/cubic foot)and the volume of foam imported (cubic feet) foreach type of closed-cell foam.See preamble text for explanationQQ98.436(a)(6)(iv)(iv) Dates on which the closed-cell foamswereimported.(iv) [Reserved.]See preamble text for explanationQQ98.436(b)(3)(3) For closed-cell foams that are exported inside ofappliances, the identity of the fluorinated GHGcontained in the foam in each appliance, the mass ofthe fluorinated GHG contained in the foam in eachappliance, and the number of appliances exportedwith each unique combination of mass and identityof fluorinated GHG within the closed-cell foams.(3) For closed-cell foams that are exported inside ofequipment, the identity of the fluorinated GHGcontained in the foam in each piece of equipment,the mass of the fluorinated GHG contained in thefoam in each piece of equipment, and the numberpieces of equipment exported with each uniquecombination of mass and identity of fluorinatedGHG within the closed-cell foams.See preamble text for explanationQQ98.436(b)(4)(4) For closed-cell foams that are not exported insideof appliances, the identity of the fluorinated GHG inthe foam, the density of the fluorinated GHG in thefoam (kg fluorinated GHG/cubic foot), and thevolume of foam exported (cubic feet) for each typeof closed-cell foam with a unique combination offluorinated GHG density and identity.(4) For closed-cell foams that are not exported insideof equipment, the identity of the fluorinated GHG inthe foam, the density of the fluorinated GHG in thefoam (kg fluorinated GHG/cubic foot), and thevolume of foam exported (cubic feet) for each typeof closed-cell foam with a unique combination offluorinated GHG density and identity.See preamble text for explanationQQ98.436(b)(5)(5) Dates on which the pre-charged equipment orclosed-cell foams were exported.(5) [Reserved.]See preamble text for explanationQQ98.436(b)(6)(ii)(ii) For closed-cell foamsthat are exported inside ofappliances, the mass of the fluorinated GHGs inCO2e contained in the foam in each appliance andthe number of appliances imported for each type of(ii) For closed-cell foams that are exported inside ofequipment, the mass of the fluorinated GHGs inCO2e contained in the foam in each piece ofequipment and the number of pieces of equipmentSee preamble text for explanation82SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeappliance.imported for each equipment type.QQ98.436(b)(6)(iii)(iii) For closed-cell foams that are notexportedinside of appliances, the mass in CO2e of thefluorinated GHGs in the foam (kg CO2 e/cubic foot)and the volume of foam imported (cubic feet) foreach type of closed-cell foam.(iii) For closed-cell foams that are not exportedinside of equipment, the density in CO2e of thefluorinated GHGs in the foam (kg CO2 e/cubic foot)and the volume of foam imported (cubic feet) foreach type of closed-cell foam.See preamble text for explanationQQ98.436(b)(6)iv)(6)(iv) Dates on which the closed-cellfoams wereexported.(6)(iv) [Reserved.]See preamble text for explanationQQ98.438Closed-cell foammeansany foam product, excludingpackaging foam that is constructed with a closed-cellstructure and a blowing agent containing afluorinated GHG. Closed-cell foams include but arenot limited to polyurethane (PU) appliance foam, PUcontinuous and discontinuous panel foam, PU onecomponent foam, PU spray foam, extrudedpolystyrene (XPS) boardstock foam, and XPS sheetfoam. Packaging foam means foam used exclusivelyduring shipment or storage to temporarily encloseitems.Closed-cell foam means any foam product, excludingpackaging foam that is constructed with a closed-cellstructure and a blowing agent containing afluorinated GHG. Closed-cell foams include but arenot limited to polyurethane (PU) foam contained inequipment, PU continuous and discontinuous panelfoam, PU one component foam, PU spray foam,extruded polystyrene (XPS) boardstock foam, andXPS sheet foam. Packaging foam means foam usedexclusively during shipment or storage totemporarily enclose items.See preamble text for explanationQQ98.438Pre-charged electricalequipment componentmeansany portion of electrical equipment that is chargedwith SF6or PFCs prior to sale or distribution or offerfor sale or distribution in interstate commerce.Pre-charged electrical equipment componentmeansany portion of electrical equipment that is chargedwith a fluorinated greenhouse gas prior to sale ordistribution or offer for sale or distribution ininterstate commerce.See preamble text for explanationRR98.443 (b)(2)Sr,p= Quarterly mass of contents in containers r thatis redelivered to another facility without beinginjected into your well in quarter p (metric tons)Sr,p= Quarterly volume of contents in containers rthat is redelivered to another facility without beinginjected into your well in quarter p (standard cubicmeters)Corrects equation term for consistency of units.RR98.443(d)(3)(3) To aggregate production data, you must sum themass of all of the CO2separated at each gas-liquidseparator in accordance with the procedure specifiedin Equation RR–9 of this section. You must assumethat the total CO2measured at the separator(s)represents a percentage of the total CO2produced. Inorder to account for the percentage of CO2producedthat is estimated to remain with the produced oil orother fluid, you must multiply the quarterly mass ofCO2measured at the separator(s) by a percentageestimated using a methodology in your approved(3) To aggregate production data, you must sum themass of all of the CO2separated at each gas-liquidseparator in accordance with the procedure specifiedin Equation RR–9 of this section. You must assumethat the total CO2measured at the separator(s)represents a percentage of the total CO2produced. Inorder to account for the percentage of CO2producedthat is estimated to remain with the produced oil orother fluid, you must multiply the quarterly mass ofCO2measured at the separator(s) by a percentageestimated using a methodology in your approvedCorrects reference.83SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeMRV plan. If fluids containingCO2from injectionwells covered under this source category areproduced and not processed through a gas-liquidseparator, the concentration of CO2in the producedfluids must be measured at a flow meter located priorto reinjection or reuse using methods in§98.444(f)(1). The considerations you intend to useto calculate CO2from produced fluids for the massbalance equation must be described in your approvedMRV plan in accordance with §98.448(d)(5).MRV plan. If fluids containingCO2from injectionwells covered under this source category areproduced and not processed through a gas-liquidseparator, the concentration of CO2in the producedfluids must be measured at a flow meter located priorto reinjection or reuse using methods in§98.444(f)(1). The considerations you intend to useto calculate CO2from produced fluids for the massbalance equation must be described in your approvedMRV plan in accordance with §98.448(a)(5).RR98.443(f)(2)CO2FI= Total annualCO2mass emitted (metric tons)from equipment leaks and vented emissions of CO2from equipment located on the surface between theflow meter used to measure injection quantity andthe injection wellhead.CO2FI= Total annualCO2mass emitted (metric tons)from equipment leaks and vented emissions of CO2from equipment located on the surface between theflow meter used to measure injection quantity andthe injection wellhead, for which a calculationprocedure is provided in subpart W of this part.Harmonizing change to conform the variabledefinitions in RR-11 and RR-12RR98.446(b)(5)(5) The standard ormethod used to calculate eachvalue in paragraphs (b)(1) and (b)(2) of this section.(5) The standard or method used to calculate eachvalue in paragraphs (b)(1), (b)(2), and (b)(3) of thissection.See preamble text for explanationSS98.453(d)(d) Estimate the mass of SF6or PFCs disbursed tocustomers in new equipment or cylinders over theperiod p by monitoring the mass flow of the SF6orPFCs into the new equipment or cylinders using aflowmeter or by weighing containers before and aftergas from containers is used to fill equipment orcylinders.(d) Estimate the mass of SF6or PFCs disbursed tocustomers in new equipment or cylinders over theperiod p by monitoring the mass flow of the SF6orPFCs into the new equipment or cylinders using aflowmeter, or by weighing containers before andafter gas from containers is used to fill equipment orcylinders, or by using the nameplate capacity of theequipment.See preamble text for explanationSS98.453(h)(h) The mass of SF6or the PFC disbursed tocustomers in new equipment over the period p mustbe determined either by using the nameplate capacityof the equipment or, in cases where equipment isshipped with a partial charge, by calculating thepartial shipping charge. Calculate the partial shippingcharge by multiplying the nameplate capacity of theequipment by the ratio of the densities of the partialcharge to the full charge.To determine the equipment's actual nameplatecapacity, you must measure the nameplate capacitiesof a representative sample of each make and model(h) If the mass of SF6or the PFC disbursed tocustomers in new equipment or cylinders over theperiod p is determined by using the nameplatecapacity, or by using the nameplate capacity of theequipment and calculating the partial shippingcharge, use the methods in either paragraph (h)(1) or(h)(2) of this section.(1) Determine the equipment's actual nameplatecapacity, by measuring the nameplate capacities of arepresentative sample of each make and model andcalculating the mean value for each make and modelas specified at §98.454(f);See preamble text for explanation84SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeand take the average for each make and model asspecified at §98.454(f).(2) If equipment is shipped with a partial charge,calculate the partial shipping charge by multiplyingthe nameplate capacity of the equipment by the ratioof the densities of the partial charge to the fullcharge.SS98.453(i)MF = The total annual mass of the SF6or PFCs, inpounds, used to fill equipment.MF = The total annual mass of the SF6orPFCs, inpounds, used to fill equipment during equipmentinstallation at electric transmission or distributionfacilities.Clarifies a calculation term.SS98.456(m)(m) The values for each hose and valve combinationand the associated valve fitting sizes and hosediameters.(m) The values for EFCiof Equation SS-5of thissubpart for each hose and valve combination and theassociated valve fitting sizes and hose diameters.Clarifies a reporting requirement.SS98.456(o) &(p)(o) The mean value foreach make, model, and groupof conditions if the mass of SF6or the PFC disbursedto customers in new equipment over the period p isdetermined by assuming that it is equal to theequipment's nameplate capacity or, in cases whereequipment is shipped with a partial charge, equal toits partial shipping charge.(p) The number of samples and the upper and lowerbounds on the 95 percent confidence interval foreach make, model, and group of conditions if themass of SF6or the PFC disbursed to customers innew equipment over the period p is determined byassuming that it is equal to the equipment'snameplate capacity or, in cases where equipment isshipped with a partial charge, equal to its partialshipping charge.(o) If the mass of SF6or the PFC disbursed tocustomers in new equipment over the period p isdetermined according to the methods required in§98.453(h) of this subpart, report the mean value ofnameplate capacity in pounds for each make, model,and group of conditions.(p) If the mass of SF6or the PFC disbursed tocustomers in new equipment over the period p isdetermined according to the methods required in§98.453(h) of this subpart, report the number ofsamples and the upper and lower bounds on the 95percent confidence interval for each make, model,and group of conditions.Clarifies a reporting requirement.TT98.460(c)(2)(xiii)(xiii) Other waste material that has a DOC value of0.3 weight percent (on a wet basis) or less. DOCvalue must be determined using a 60-day anaerobicbiodegradation test procedure identified in §98.464(b)(4)(i)(A) .(xiii) Other waste material that has a DOC value of0.3 weight percent (on a wet basis) or less. DOCvalue must be determined using a 60-day anaerobicbiodegradation test procedure identified in §98.464(b)(4)(i) .Corrects cross-reference to 98.464(b)(4)(i) toindicate that all of the requirements in subparagraph(A) through (E) are applicable.TT98.463(a)(1)DOCF= Fraction of DOC dissimilated (fraction); usethe default value of 0.5.DOCF= Fraction ofDOC dissimilated (fraction); usethe default value of 0.5. If measured values of DOCare available using the 60-day anaerobicbiodegradation test procedure identified inSee preamble text for explanation85SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChange98.464(b)(4)(i), use a default value of 1.0 .TT98.463(a)(1)Eq. TT-1Fx= Fraction by volume ofCH4in landfill gas(fraction, dry basis, corrected to 0% oxygen). If youhave a gas collection system, use the annual averageCH4concentration from measurement data for thecurrent reporting year; otherwise, use the defaultvalue of 0.5.F = Fraction by volume ofCH4in landfill gas(fraction, dry basis, corrected to 0% oxygen). If youhave a gas collection system, use the annual averageCH4concentration from measurement data for thecurrent reporting year; otherwise, use the defaultvalue of 0.5.Corrects an equation term. This term correspona factor for the current reporting year, and should nothave a subscript indicating that it is a variable thatchanges with each disposal year.TT98.463(a)(2)(ii)(C )Eq. TT-4bCorrects a typographical error inEquation TTThe summation should start with "n=1" rather than"n-1"TT98.463(b)(1)Eq. TT-6OX = Oxidation fraction. Use the default value of 0.1(10 percent).OX = Oxidation fraction from Table HH-4 of subpartHH of this part.See preamble text for explanationTT98.464(b)(b) For each waste stream placed in the landfillduring the reporting year for which you choose todetermine volatile solids concentration for thepurposes of § 98.460(c)(2)(xii) or choose todetermine a landfill-specific DOCXfor use inEquation TT-1 of this subpart or for the purposes of§ 98.460(c)(2)(xiii) of this subpart, you must collectand test a representative sample of that waste streamusing the methods specified in paragraphs (b)(1)through (b)(4) of this section.(b) For each waste stream placed in the landfillduring the reporting year for which you choose todetermine volatile solids concentration and/or awaste stream-specific DOCX, you must collect andtest a representative sample of that waste streamusing the methods specified in paragraphs (b)(1)through (b)(4) of this section, as applicable.See preamble text for explanationTT98.464(b)(4)(i)(E)Eq. TT-7Where:DOCX= Degradable organic content of the waste stream in YearX (weight fraction, wet basis)DOCF= Fraction of DOC dissimilated (fraction); use the defaultvalue of 0.5.MCDsample,x= Mass of carbon degraded in the waste streamsample in Year X as determined in paragraph (b)(4)(i)(C) of thisWhere:DOCX= Degradable organic content of the wastestream in Year X (weight fraction, wet basis)MCDsample,x= Mass of carbon degraded in the wastestream sample in Year X as determined in paragraph(b)(4)(i)(C) of this section [milligrams (mg)].Msample,x= Mass of waste stream sample used in theanaerobic degradation test in Year X (mg, wet basis).See preamble text for explanation∑−NYrDatannmeasW1,∑=NYrDatannmeasW1,=controlcontrolxsamplexsampleFXMCMCDMMCDDOCDOC,,1xsamplexsampleXMMCDDoc,,=86SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangesection [milligrams (mg)].Msample,x= Mass of waste stream sample used in the anaerobicdegradation test in Year X (mg, wet basis).MCDcontrol= Mass of carbon degraded in the control sample asdetermined in paragraph (b)(4)(i)(B) of this section (mg).MCcontrol= Mass of carbon added to the control sample via thesubstrate material in the anaerobic degradation (mg).TT98.464(c)(c) For each waste stream for which youchoose todetermine volatile solids concentration for thepurposes of paragraph § 98.460(c)(2)(xii), and thatwas historically managed in the landfill but was notreceived during the first reporting year, you mustdetermine volatile solids concentration of the wastestream as initially placed in the landfill using themethods specified in paragraph (c)(1) or (c)(2) ofthis section, as applicable.(c) For each waste stream that was historicallymanaged in the landfill but was not received duringthe first reporting year for which you choose todetermine volatile solids concentration and/or awaste stream-specific DOCX, you must determinevolatile solids concentration or DOCXof the wastestream as initially placed in the landfill using themethods specified in paragraph (c)(1) or (c)(2) ofthis section, as applicable.See preamble text for explanationTT98.464(c)(1)(1) If you can identify a similar waste stream to thewaste stream that was historically managed in thelandfill, you must determine the volatile solidsconcentration of the similar waste stream using theprocedures in paragraphs (b)(1) through (b)(3) of thissection.(1) If you can identify a similar waste stream to thewaste stream that was historically managed in thelandfill, you must determine the volatile solidsconcentration or DOCXof the similar waste streamusing the applicable procedures in paragraphs (b)(1)through (b)(4) of this section.See preamble text for explanationTT98.464(c)(2)(2) If you cannot identify a similar waste stream tothe waste stream that was historically managed in thelandfill, you may determine the volatile solidsconcentration of the historically managed wastestream using process knowledge. You mustdocument the basis for volatile solids concentrationas determined through process knowledge.(2) If you cannot identify a similar waste stream tothe waste stream that was historically managed in thelandfill, you may determine the volatile solidsconcentration or DOCXof the historically managedwaste stream using process knowledge. You mustdocument the basis for the volatile solidsconcentration or DOCXvalue as determined throughprocess knowledge.See preamble text for explanationTT98.466(b)(1)(1) The number of waste steams (including “OtherIndustrial Solid Waste (not otherwise listed)”) forwhich Equation TT-1 of this subpart is used tocalculate modeled CH4generation.(1) The number of waste steams (including “OtherIndustrial Solid Waste (not otherwise listed)” and“Inerts ”) for which Equation TT–1 of this subpart isused to calculate modeled CH4generation.See preamble text for explanationTT98.466(b)(5)(None)(5) For each waste stream, the decay rate (k) valueused in the calculations.See preamble text for explanationTT98.466(c )(c) For each waste stream identified in paragraph (b)of this section, report the following information:(1) The decay rate (k) value used in the calculations.(c) Report the following historical wasteinformation:(1) [Reserved]See preamble text for explanation87SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChange(2) The method(s) for estimating historical wastedisposal quantities and the range of years for whicheach method applies.(3) If Equation TT–2 of this subpart is used, provide:(i) The total number of years (N) for which disposaland production data are both available.(ii) The year, the waste disposal quantity andproduction quantity for each year used in EquationTT–2 of this subpart to calculate the average wastedisposal factor (WDF).(iii) The average waste disposal factor (WDF)calculated for the waste stream.(2) For each waste stream identified in paragraph (b)of this section, the method(s) for estimatinghistorical waste disposal quantities and the range ofyears for which each method applies.(3) For each waste stream identified in paragraph (b)of this section for which Equation TT-2 of thissubpart is used, provide:(i) The total number of years (N) for which disposaland production data are both available.(ii) The year, the waste disposal quantity andproduction quantity for each year used in EquationTT–2 of this subpart to calculate the average wastedisposal factor (WDF).(iii) The average waste disposal factor (WDF)calculated for the waste stream.TT98.466(c)(4)(4) If Equation TT-4 of this subpart is used, provide:(i) The value of landfill capacity (LFC).(ii) YrData.(iii) YrOpen.(4) If Equation TT–4a of this subpart is used,provide:(i) The value of landfill capacity (LFC).(ii) YrData.(iii) YrOpen.See preamble text for explanationTT98.466(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 thestart of the reporting year from design drawings orengineering estimates (metric tons) or, for closedlandfills for which waste in-place quantities are notavailable, the landfill's design capacity);(ii) The cumulative quantity of waste placed in thelandfill for the years for which disposal quantities areavailable from company record or from EquationTT-3 of this part;(iii) YrLast;(iv) YrOpen; and(v) NYrData.See preamble text for explanationTT98.466(d)(3)(3) The degradable organic carbon (DOCX)value(mass fraction) for the specified year and anindication as to whether this was the default valuefrom Table TT-1 to this subpart, a measured value(3) For each waste stream, the degradable organiccarbon (DOCX) value (mass fraction) for thespecified year and an indication as to whether thiswas the default value from Table TT–1 to thisSee preamble text for explanation88SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeusing a 60-day anaerobic biodegradation test asspecified in §98.464(b)(4)(i), or a value based ontotal and volatile solids measurements as specified in§98.464(b)(4)(ii). If DOCXwas determined by a 60-day anaerobic biodegradation test, specify the testmethod used.subpart, a measured value using a 60-day anaerobicbiodegradation test as specified in §98.464(b)(4)(i),or a value based on total and volatile solidsmeasurements as specified in §98.464(b)(4)(ii). IfDOCXwas determined by a 60-day anaerobicbiodegradation test, specify the test method used.TT98.466(h)(h) For landfills with gas collection systems, inaddition to the reporting requirements in paragraphs(a) through (f) of this section, you must reportaccording to §98.346(i).(h) For landfills with gas collection systems, inaddition to the reporting requirements in paragraphs(a) through (f) of this section, provide:(1) The annual methane generation, adjusted foroxidation, calculated using Equation TT-6 of thissubpart, reported in metric tons CH4;(2) The oxidation factor used in Equation TT-6 ofthis subpart; and(3) All information required under 40 CFR98.346(i)(1) through (i)(7) and 40 CFR 98.346(i)(9)through (i)(12).See preamble text for explanationTT98.467In addition to the information required by §98.3(g),you must retain the calibration records for allmonitoring equipment, including the method ormanufacturer's specification used for calibration, andall measurement data used for the purposes ofparagraph § 98.460(c)(2)(xii) or used to determinelandfill-specific DOCXvalues.In addition to the information required by §98.3(g),you must retain the calibration records for allmonitoring equipment, including the method ormanufacturer's specification used for calibration, andall measurement data used for the purposes ofparagraphs §98.460(c)(2)(xii) or (c)(2)(xiii) or usedto determine waste stream-specific DOCXvalues foruse in Equation TT-1 of this subpart.See preamble text for explanationTTTable TT-1Table TT-1See Appendix A for changes to Table TT-1See preamble text for explanationUU98.473(a)(2)D= Density ofCO2at standard conditions (metrictons per standard cubic meter): 0.0018704D= Density ofCO2at standard conditions (metrictons per standard cubic meter): 0.0018682Harmonizing change to conform with the densityvalues used in 98.473(b)(2).UU98.473(b)(2)Sr,p= Quarterly mass of contents in containers r thatis redelivered to another facility without beinginjected into your well in quarter p (standard cubicmeters)Sr,p= Quarterly volume of contents in containers rthat is redelivered to another facility without beinginjected into your well in quarter p (standard cubicmeters)Corrects equation term for consistency of units.UU98.476(b)(5)(5) The standard or method used to calculate eachvalue in paragraphs (b)(1) and (b)(2) of this section.(5)The standard or method used to calculate eachvalue in paragraphs (b)(1), (b)(2), and (b)(3) of thissection.See preamble text for explanationUU98.476(e)(None)(e) Report the following:(1) Whether the facility received a Research andDevelopment project exemption from reportingSee preamble text for explanation89SubpartRequirementCurrent Rule TextProposed Rule TextRationale forChangeunder 40 CFR Part 98 subpart RR for this reportingyear. If you received an exemption, report the startand end dates of the exemption approved by EPA;(2) Whether the facility includes a well or group ofwells where a CO2stream was injected intosubsurface geologic formations to enhance therecovery of oil during this reporting year;(3) Whether the facility includes a well or group ofwells where a CO2stream was injected intosubsurface geologic formations to enhance therecovery of natural gas during this reporting year;(4) Whether the facility includes a well or group ofwells where a CO2stream was injected intosubsurface geologic formations for acid gas disposalduring this reporting year;(5) Whether the facility includes a well or group ofwells where a CO2stream was injected for a purposeother than those listed in (e)(1)through (4) of thissection. If you injected CO2for another purpose,report the purpose of the injection.

# Attachment A

1. Proposed Amendments to Table A–1 to Subpart A of Part 98—Global Warming

Potentials

[100-Year Time Horizon]

Name CAS No. Chemical formula Global warming

potential

(100 yr.)

Carbon dioxide 124–38–9 CO2 1

Methane 74–82–8 CH4 25 a



# Nitrous oxide 10024–97–2 N2O 298 a



# HFC–23 75–46–7 CHF3 14,800 a



# HFC–32 75–10–5 CH2F2 675 a



# HFC–41 593–53–3 CH3F 92 a



# HFC–125 354–33–6 C2HF5 3,500 a



# HFC–134 359–35–3 C2H2F4 1,100 a



# HFC–134a 811–97–2 CH2FCF3 1,430 a



# HFC–143 430–66–0 C2H3F3 353 a



# HFC–143a 420–46–2 C2H3F3 4,470 a



# HFC–152 624–72–6 CH2FCH2F 53

HFC–152a 75–37–6 CH3CHF2 124 a



# HFC–161 353–36–6 CH3CH2F 12

HFC–227ea 431–89–0 C3HF7 3,220 a



# HFC–236cb 677–56–5 CH2FCF2CF3 1,340

HFC–236ea 431–63–0 CHF2CHFCF3 1,370

HFC–236fa 690–39–1 C3H2F6 9,810a

HFC–245ca 679–86–7 C3H3F5 693a

HFC–245fa 460–73–1 CHF2CH2CF3 1,030

HFC–365mfc 406–58–6 CH3CF2CH2CF3 794

HFC–43–10mee 138495–42–8 CF3CFHCFHCF2CF3 1,640 a



# Sulfur hexafluoride 2551–62–4 SF6 22,800 a

# Name CAS No. Chemical formula Global warming

potential

(100 yr.)

Trifluoromethyl sulphur

pentafluoride 373–80–8 SF5CF3 17,700

Nitrogen trifluoride 7783–54–2 NF3 17,200

PFC–14 (Perfluoromethane) 75–73–0 CF4 7,390 a



# PFC–116 (Perfluoroethane) 76–16–4 C2F6 12,200 a



# PFC–218 (Perfluoropropane) 76–19–7 C3F8 8,830 a



# Perfluorocyclopropane 931–91–9 C-C3F6 17,340

PFC–3–1–10 (Perfluorobutane) 355–25–9 C4F10 8,860 a



# Perfluorocyclobutane 115–25–3 C-C4F8 10,300 a



# PFC–4–1–12 (Perfluoropentane) 678–26–2 C5F12 9,160 a



# PFC–5–1–14

(Perfluorohexane) 355–42–0 C6F14 9,300 a



# PFC–9–1–18 306–94–5 C10F18 7,500

HCFE–235da2 (Isoflurane) 26675–46–7 CHF2OCHClCF3 350

HFE–43–10pccc (H–Galden 1040x) E1730133 CHF2OCF2OC2F4OC

HF2 1,870

HFE–125 3822–68–2 CHF2OCF3 14,900

HFE–134 1691–17–4 CHF2OCHF2 6,320

HFE–143a 421–14–7 CH3OCF3 756

HFE–227ea 2356–62–9 CF3CHFOCF3 1,540

HFE–236ca12 (HG–10) 78522–47–1 CHF2OCF2OCHF2 2,800

HFE–236ea2 (Desflurane) 57041–67–5 CHF2OCHFCF3 989

HFE–236fa 20193–67–3 CF3CH2OCF3 487

HFE–245cb2 22410–44–2 CH3OCF2CF3 708

HFE–245fa1 84011–15–4 CHF2CH2OCF3 286

HFE–245fa2 1885–48–9 CHF2OCH2CF3 659

HFE–254cb2 425–88–7 CH3OCF2CHF2 359

HFE–263fb2 460–43–5 CF3CH2OCH3 11

HFE-329mcc2 67490-36-2 CF3CF2OCF2CHF2 919

# Name CAS No. Chemical formula Global warming

potential

(100 yr.)

HFE–338mcf2 156053–88–2 CF3CF2OCH2CF3 552

HFE–338pcc13 (HG–01) 188690–78–0 CHF2OCF2CF2OCH

F2 1,500

HFE–347mcc3 28523–86–6 CH3OCF2CF2CF3 575

HFE–347mcf2 E1730135 CF3CF2OCH2CHF2 374

HFE–347pcf2 406–78–0 CHF2CF2OCH2CF3 580

HFE–356mec3 382–34–3 CH3OCF2CHFCF3 101

HFE–356pcc3 160620–20–2 CH3OCF2CF2CHF2 110

HFE–356pcf2 E1730137 CHF2CH2OCF2CHF2 265

HFE–356pcf3 35042–99–0 CHF2OCH2CF2CHF2 502

HFE–365mcf3 378–16–5 CF3CF2CH2OCH3 11

HFE–374pc2 512–51–6 CH3CH2OCF2CHF2 557

HFE–449sl (HFE–7100)

Chemical blend 163702–07–6

163702–08–7 C4F9OCH3

(CF3)2CFCF2OCH3 297

HFE–569sf2 (HFE–7200)

Chemical blend 163702–05–4

163702–06–5 C4F9OC2H5

(CF3)2CFCF2OC2H5 59

Sevoflurane 28523–86–6 CH2FOCH(CF3)2 345

HFE–356mm1 13171–18–1 (CF3)2CHOCH3 27

HFE–338mmz1 26103–08–2 CHF2OCH(CF3)2 380

(Octafluorotetramethylene)hydroxymethyl group NA X-(CF2)4CH(OH)-X 73

HFE–347mmy1 22052–84–2 CH3OCF(CF3)2 343

Bis(trifluoromethyl)-methanol 920–66–1 (CF3)2CHOH 195

2,2,3,3,3-pentafluoropropanol 422–05–9 CF3CF2CH2OH 42

PFPMIE NA CF3OCF(CF3)CF2OC

F2OCF3 10,300

HFC-1234ze b 

# 29118-24-9 C3H2F4 6

hexafluoropropylene (HFP) b 

# 116-15-4 C3F6 0.25

perfluoromethyl vinyl ether

(PMVE) b 

# 1187-93-5 CF(CF3)OCF3 3

# Name CAS No. Chemical formula Global warming

potential

(100 yr.)

tetrafluoroethylene (TFE) b 

# 116-14-3 C2F4 0.02

trifluoro propene (TFP) b 

# 677-21-4 C3H3F3 3

vinyl fluoride (VF) b 

# 75-02-5 C2H3F 0.7

vinylidiene fluoride (VF2) b 

# 75-38-7 C2H2F2 0.9

carbonyl fluoride b 

# 353-50-4 COF2 2

perfluoropropyl vinyl ether b 

# 1623-05-8 C5F10O 3

perfluoroethyl vinyl ether b 

# 10493-43-3 C4F8O 3

HFC-1234yf b 

# 754-12-1 C3H2F4 4

perfluorethyl iodide (2-I) b 

# 354-64-3 C2F5I 3

perfluorbutyl iodide (PFBI, 42-I) b 

# 423-39-2 C4F9I 3

perfluorhexyl iodide (6-I) b 

# 355-43-1 CF3CF2CF2CF2CF2

CF2IC6F13I 2

perfluoroctyl iodide (8-I) b 

# 507-63-1 C8F17I 2

1,1,1,2,2-pentafluoro-4-iodo butane

(22-I) b 

# 40723-80-6 C4H4F5I 2

1,1,1,2,2,3,3,4,4-nonafluoro-6-iodo

hexane (42-I) b 

# 2043-55-2 C6H4F9I 2

perfluorobutyl ethene (42-U) b 

# 19430-93-4 C6H3F9 2

perfluorohexyl ethene (62-U) b 

# 25291-17-2 C8H3F13 1

perfluorooctyl ethene (82-U) b 

# 21652-58-4 C10H3F17 1

1H,1H, 2H,2H-perfluorohexan-1-ol

(42-AL) b 

# 2043-47-2 C6H5F9O 5

FK-5-1-12 Perfluoroketone; FK-5-1-

12myy2; n-Perfluorooctane;

Octanedecafluorooctane b 

# 756-13-8 CF3CF2C(O)CF

(CF3)2 1.8

C7 Fluoroketone, Novec 774/ FK-6-

1-12 813-44-5 and

813-45-6 C7F14O Chemical

Blend 1

trans-1-chloro-3,3,3-trifluoroprop-1-

ene b 

# 2730-43-0 C3H2ClF3 7

Hexadecofluoroheptane b



# (PFC-6-1-12) 335-57-9 C7F16 7930

# Name CAS No. Chemical formula Global warming

potential

(100 yr.)

octadecafluorooctane b



# (PFC-7-1-18) 307-34-6 C8F18 8340

a The GWP for this compound is different than the GWP i n the version of Table A-1 to subpart

A of part 98 published on October 30, 2009.

b The GWP for this compound was not provided in the version of Table A-1 to subpart A of part

98 published on October 30, 2009.

NA – Not available

3. Proposed Amendments to Table A-6 to 40 CFR part 98, subpart A:

Table A–6 to Subpart A of Part 98—Data Elements That Are Inputs

to Emission Equations and for Which the Reporting Deadline Is

March 31, 2013

Subpart Rule citation

(40 CFR part 98) Specific data elements for which

reporting date is March 31, 2013

(“All” means all data elements in the

cited paragraph are not required to

be reported until March 31, 2013)

C 98.36(d)(1)(iv) All.

C 98.36(d)(2)(ii)(G) All.

C 98.36(d)(2)(iii)(G) All.

C 98.36(e)(2)(iv)(G) All.

C 98.36(e)(2)(viii)(A) All.

C 98.36(e)(2)(viii)(B) All.

C 98.36(e)(2)(viii)(C) All.

C 98.36(e)(2)(x)(A) All.

C 98.36(e)(2)(xi) All.

DD 98.306(a)(2) All.

DD 98.306(a)(3) All.

DD 98.306(d) All.

DD 98.306(e) All.

DD 98.306(f) All.

# Subpart Rule citation

(40 CFR part 98) Specific data elements for which

reporting date is March 31, 2013

(“All” means all data elements in the

cited paragraph are not required to

be reported until March 31, 2013)

DD 98.306(g) All.

DD 98.306(h) All.

DD 98.306(i) All.

DD 98.306(j) All.

DD 98.306(k) All.

DD 98.306(l) All.

FF 98.326(a) All.

FF 98.326(b) All.

FF 98.326(c) All.

FF 98.326(f) Only quarterly volumetric flow rate.

FF 98.326(g) Only quarterly CH 4 

# concentration.

FF 98.326(h) Only weekly volumetric flow used to

calculate CH 4 

# liberated from

degasification systems.

FF 98.326(j) All.

FF 98.326(k) All.

FF 98.326(o) All.

FF 98.326(p) Only assumed destruction efficiency

for the primary destruction device

and assumed destruction efficiency

for the backup destruction device.

HH 98.346(a) Only year in which landfill first

accepted waste, last year the

landfill accepted waste (if used as

an input in Equation HH–3), capacity

of the landfill (if used as an input

in 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

# Subpart Rule citation

(40 CFR part 98) Specific data elements for which

reporting date is March 31, 2013

(“All” means all data elements in the

cited paragraph are not required to

be reported until March 31, 2013)

determined using the methods in

§98.343(a)(3)(ii), population served

by the landfill for each year, and

the value of landfill capacity (LFC)

used in the calculation.

HH 98.346(c) All.

HH 98.346(d)(1) Only degradable organic carbon (DOC)

value, and fraction of DOC

dissimilated (DOCF) values.

HH 98.346(d)(2) All.

HH 98.346(e) Only fraction of CH 4 

# in landfill gas

and methane correction factor (MCF)

values.

HH 98.346(f) Only surface area associated with

each cover type.

HH 98.346(g) All.

HH 98.346(i)(5) Only annual operating hours for the

primary destruction device, annual

operating hours for the backup

destruction device, destruction

efficiency for the primary

destruction device, and destruction

efficiency for the backup destruction

device.

HH 98.346(i)(6) All.

HH 98.346(i)(7) Only surface area specified in Table

HH– 3, estimated gas collection system

efficiency, and annual operating

hours of the gas collection system.

HH 98.346(i)(9) Only CH 4 

# generation value.

II 98.356(b)(1) All.

II 98.356(b)(2) All.

II 98.356(b)(3) All.

# Subpart Rule citation

(40 CFR part 98) Specific data elements for which

reporting date is March 31, 2013

(“All” means all data elements in the

cited paragraph are not required to

be reported until March 31, 2013)

II 98.356(b)(4) All.

II 98.356(b)(5) All.

II 98.356(d)(1) All.

II 98.356(d)(7) All.

II 98.356(d)(8) Only annual operating hours for the

primary destruction device, annual

operating hours for the backup

destruction device, destruction

efficiency of the primary destruction

device, and destruction efficiency of

the backup destruction device.

SS 98.456(a) All.

SS 98.456(b) All.

SS 98.456(c) All.

SS 98.456(d) All.

SS 98.456(e) All.

SS 98.456(f) All.

SS 98.456(g) All.

SS 98.456(h) All.

SS 98.456(i) All.

SS 98.456(j) All.

SS 98.456(m) All.

SS 98.456(n) All.

SS 98.456(o) All.

SS 98.456(q) All.

SS 98.456(r) All.

SS 98.456(s) All.

SS 98.456(t) Only for any missing data the

substitute parameters used to

# Subpart Rule citation

(40 CFR part 98) Specific data elements for which

reporting date is March 31, 2013

(“All” means all data elements in the

cited paragraph are not required to

be reported until March 31, 2013)

estimate emissions in their absence.

TT 98.466(a)(2) All.

TT 98.466(a)(3) Only last year the landfill accepted

waste (for closed landfills using

Equation TT–4).

TT 98.466(a)(4) Only capacity of the landfill in

metric tons (for closed landfills

using Equation TT–4).

TT 98.466(c)(1) All.

TT 98.466(c)(4)(i) All.

TT 98.466(c)(4)(ii) All.

TT 98.466(c)(4)(iii) All.

TT 98.466(d)(1) All.

TT 98.466(d)(2) Only degradable organic carbon (DOC

X 

# )

value used in calculations.

TT 98.466(d)(3) Only fraction of CH 4 

# in landfill gas.

TT 98.466(e)(2) Only surface area (in square meters)

at the start of the reporting year

for the landfill sections that

contain waste and that are associated

with the selected cover type (for

facilities using a landfill gas

collection system).

TT 98.466(f) All.

# 4. Proposed Amendments 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

Waste Anthracite (Culm) See footnote 1 103.69

Bituminous 24.93 93.28

Waste Bituminous (Gob) See footnote 1 93.28

Subbituminous 17.25 97.17

Lignite 14.21 97.72

Coal Coke 24.80 113.67

Mixed (Commercial sector) 21.39 94.27

Mixed (Industrial coking) 26.28 93.90

Mixed (Industrial sector) 22.35 94.67

Mixed (Electric Power sector) 19.73 95.52

Natural gas mmBtu/scf kg CO 2 

# /mmBtu

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

# 53.06

Petroleum products 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) 2 

# 0.092 61.71

Propane 2 

# 0.091 62.87

Propylene 2 

# 0.091 67.77

Ethane 2 

# 0.068 59.60

# Fuel type Default high heat value Default CO 2



# emission factor

Ethanol 0.084 68.44

Ethylene 3 

# 0.058 65.96

Isobutane 2 

# 0.099 64.94

Isobutylene 2 

# 0.103 68.86

Butane 2 

# 0.103 64.77

Butylene 2 

# 0.105 68.72

Naphtha (<401 deg F) 0.125 68.02

Natural Gasoline 0.110 66.88

Other Oil (>401 deg F) 0.139 76.22

Pentanes Plus 0.110 70.02

Petrochemical Feedstocks 0.125 71.02

Petroleum Coke 0.143 102.41

Special Naphtha 0.125 72.34

Unfinished Oils 0.139 74.54

Heavy Gas Oils 0.148 74.92

Lubricants 0.144 74.27

Motor Gasoline 0.125 70.22

Aviation Gasoline 0.120 69.25

Kerosene-Type Jet Fuel 0.135 72.22

Asphalt and Road Oil 0.158 75.36

Crude Oil 0.138 74.54

Other fuels-solid mmBtu/short ton kg CO 2 

# /mmBtu

Municipal Solid Waste 9.95 4 

# 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

# Fuel type Default high heat value Default CO 2



# emission factor

Coke Oven Gas 0.599 × 10 −3 

# 46.85

Propane Gas 2.516 × 10 −3 

# 61.46

Fuel Gas 5 

# 1.388 × 10 −3 

# 59.00

Biomass fuels—solid mmBtu/short ton kg CO 2 

# /mmBtu

Wood and Wood Residuals(dry basis) 6 

# 17.48 93.80

Agricultural Byproducts 8.25 118.17

Peat 8.00 111.84

Solid Byproducts 10.39 105.51

Biomass fuels—gaseous mmBtu/scf kg CO 2 

# /mmBtu

Landfill Gas 0.485 × 10 −3 

# 52.07

Other Biomass Gases 0.655 x 10

- 3 

# 52.07

Biomass Fuels—Liquid 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 

# Provisions of the rule referencing “default HHVs f rom Table C-1” do

not apply to culm and gob. The HHV for culm and go b must be

determined according to the procedures specified in the Tier 2

Calculation Methodology.

2 

# The HHV for components of LPG determined at 60oF a nd saturation

pressure with the exception of ethylene.

3 

# Ethylene HHV determined at 41oF (5oC) and saturatio n pressure.

4 

# Use of this default HHV is allowed only for: (a) Un its that combust

MSW, do not generate steam, and are allowed to use Tier 1; (b) units

that derive no more than 10 percent of their annual heat input from

MSW and/or tires; and (c) small batch incinerators that combust no

more than 1,000 tons of MSW per year.

5 

# Reporters subject to subpart X of this part that ar e complying with

§98.243(d) or subpart Y of this part may only use t he default HHV and

the default CO 2 

# emission factor for fuel gas combustion under the

conditions prescribed in §98.243(d)(2)(i) and (d)(2 )(ii) and

§98.252(a)(1) and (a)(2), respectively. Otherwise, reporters subject

# to subpart X or subpart Y shall use either Tier 3 ( Equation C–5) or

Tier 4.

6 

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

Equation C-1: HHV

w 

# =((100-M)/100)*HHV

d 

# where HHV

w 

# = wet basis HHV, M =

moisture content(percent) and HHV d 

# =dry basis HHV from Table C-1.



# 5. Proposed Amendments to Table C-2 to 40 CFR part 98, subpart C:

Table C–2 to Subpart C—Default CH 4 

# and N 2 

# O Emission Factors for

Various Types of Fuel

Fuel type Default CH 4 

# emission

factor (kg CH 4 

# /mmBtu) Default N 2 

# O emission

factor (kg N 2 

# O/mmBtu)

Coal and Coke (All fuel types in Table

C–1) 1 

# 1.1 × 10 −02 

# 1.6 × 10 −03



# Anthracite for FBCs only 2 

# 1.1 x 10

- 02 

# 1.6 x 10

- 01



# Waste Anthracite (Culm) for FBCs only 2 

# 1.1 x 10

- 02 

# 4.0 x 10

- 01



# Bituminous for FBCs only 2 

# 1.1 x 10

- 02 

# 1.3 x 10

- 01



# Waste Bituminous (Gob) for FBCs only 2 

# 1.1 x 10

- 02 

# 2.9 x 10

- 01



# Subbituminous for FBCs only 2 

# 1.1 x 10

- 02 

# 6.5 x 10

- 0 2



# Lignite for FBCs only 2 

# 1.1 x 10

- 02 

# 1.1 x 10

- 01



# Natural Gas 1.0 × 10 −03 

# 1.0 × 10 −04



# Petroleum (All fuel types in Table C–1) 3.0 × 10 −03 

# 6.0 × 10 −04



# Fuel Gas 3.0 × 10 −03 

# 6.0 × 10 −04



# Municipal Solid Waste 3.2 × 10 −02 

# 4.2 × 10 −03



# Tires 3.2 × 10 −02 

# 4.2 × 10 −03



# Blast Furnace Gas 2.2 × 10 −05 

# 1.0 × 10 −04



# Coke Oven Gas 4.8 × 10 −04 

# 1.0 × 10 −04



# Biomass Fuels—Solid (All fuel types in

Table C–1, except wood and wood

residuals) 3.2 × 10 −02 

# 4.2 × 10 −03



# Wood and wood residuals 7.2 x 10

- 3 

# 3.6 x 10

- 3



# Biomass Fuels-Gaseous (All fuel types in

Table C-1) 3.2 × 10 −03 

# 6.3 × 10 −04



# Biomass Fuels—Liquid (All fuel types in

Table C–1) 1.1 × 10 −03 

# 1.1 × 10 −04

# 1 

# Use of the default emission factors for the coal an d coke category may

not be used to estimate emissions from combusting a nthracite, waste

anthracite, bituminous, waste bituminous, subbitumi nous, or lignite

coal burned in an FBC.

2 

# Use of these default emission factors is required f or FBCs burning the

specified coal type.

Note: Those employing this table are assumed to fal l under the IPCC

definitions of the “Energy Industry” or “Manufactur ing Industries and

Construction”. In all fuels except for coal the val ues for these two

categories are identical. For coal combustion, thos e who fall within

the IPCC “Energy Industry” category may employ a va lue of 1g of

CH&ihel4;/mmBtu.

# 6. Proposed Amendments to Table AA-1 to 40 CFR part 98, subpart AA:

Table AA–1 to Subpart AA of Part 98—Kraft Pulping Liquor

Emissions Factors for Biomass-Based CO 2 

# , CH 4 

# , and N 2 

# O

Wood furnish Biomass-based emissions factors

(kg/mmBtu HHV)

CO 2 

# a CH 4 

# N 2 

# O

North American Softwood 94.4 0.0019 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 a nd pulp mill lime

kiln.



# 7. Proposed Amendments to Table AA-2 to 40 CFR part 98, subpart AA:

Table AA–2 to Subpart AA of Part 98—Kraft Lime Kiln and Calciner

Emissions Factors for 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 type) 0.0027 0 0.0027 0.0003

Distillate Oil

(any type) 0.0027 0 0.0027 0.0004

Natural Gas 0.0027 0 0.0027 0.0001

Biogas 0.0027 0 0.0027 0.0001

Petroleum coke 0.0027 0 NA a 

# 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 availa ble.

# 8. Proposed Amendments to Table HH-1 to 40 CFR part 98, subpar t HH:

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,

# Factor Default value Units

wet basis.

DOC (paper) 0.4 Weight fraction,

wet basis.

DOC (wood and straw) 0.43 Weight fraction,

wet basis.

DOC (textiles) 0.24 Weight fraction,

wet basis.

DOC (diapers) 0.24 Weight fraction,

wet basis.

DOC (sewage sludge) 0.05 Weight fraction,

wet basis.

DOC (inerts, e.g., glass,

plastics, metal, cement) 0.00 Weight fraction,

wet basis.

k (food waste) 0.06 to 0.185 c 

# yr−1

k (garden) 0.05 to 0.10 c 

# yr−1

k (paper) 0.04 to 0.06 c 

# yr−1

k (wood and straw) 0.02 to 0.03 c 

# yr−1

k (textiles) 0.04 to 0.06 c 

# yr−1

k (diapers) 0.05 to 0.10 c 

# yr−1

k (sewage sludge) 0.06 to 0.185 c 

# yr−1

k (inerts e.g., glass, 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

# Factor Default value Units

DE 0.99

a 

# Recirculated leachate (in inches/year) is the total volume of

leachate recirculated from company records or engineering

estimates divided by the area of the portion of the landfill

containing waste with appropriate unit conversions.

Alternatively, landfills that use leachate recirculation can

elect to use the k value of 0.057 rather than calculating the

recirculated leachate rate.

b 

# Use the lesser value when precipitation plus recirculated

leachate is less than 20 inches/year. Use the greater value when

precipitation plus recirculated leachate is greater than 40

inches/year. Use the average of the range of values when

precipitation plus recirculated leachate is 20 to 40 inches/year

(inclusive). Alternatively, landfills that use leachate

recirculation can elect to use the greater value rather than

calculating the recirculated leachate rate.

c 

# Use the lesser value when the potential evapotranspiration rate

exceeds the mean annual precipitation rate plus recirculated

leachate. Use the greater value when the potential

evapotranspiration rate does not exceed the mean annual

precipitation rate plus recirculated leachate. Alternatively,

landfills that use leachate recirculation can elect to use the

greater value rather than assessing the potential

evapotranspiration rate or recirculated leachate rate.

9. Proposed Amendments to Table HH-2 to 40 CFR part 98, subpar t HH:

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

# Year Waste per capita

ton/cap/yr

1963 0.65

1964 0.65

1965 0.66

1966 0.66

1967 0.67

1968 0.68

1969 0.68

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 0.82

1991 0.76

1992 0.74

1993 0.76

1994 0.75

1995 0.70

1996 0.68

1997 0.69

1998 0.75

1999 0.75

2000 0.80

2001 0.91

2002 1.02

2003 1.02

2004 1.01

2005 

# 1.06 0.98

2006 

# 1.06 0.95

2007 0.95

# Year Waste per capita

ton/cap/yr

2008 0.95

2009 and all later years 0.95

# 10. Proposed Table HH-4 to 40 CFR part 98, subpart HH:

Table HH–4 to Subpart HH of Part 98—Landfill Methane Oxidation

Fractions

If your methane flux rate a 

# for the

reporting year is: Use this landfill methane

oxidation fraction:

Less than 10 grams per square

meter per day (g/m 2 

# /d) 0.35

10 to 70 g/m 2 

# /d 0.25

Greater than 70 g/m 2 

# /d 0.10

a 

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

# /d) is

the mass flow rate of methane per unit area at the bottom of the

surface soil prior to any oxidation and is calculated as

follows.

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/year) or 10 6 

# /366 for a leap year.

# SArea = The surface area of the landfill containing waste at

the beginning of the reporting year (square meters,

m 2 

# ).

G CH4 

# = Modeled methane generation rate in reporting year from

Equation HH–1 of this subpart, or, for application

with Equation HH-6 only, the greater of the modeled

methane generation rate in reporting year from

Equation HH–1 of this subpart and the quantity of

recovered CH 4 

# from Equation HH–4 of this subpart

(metric tons CH 4 

# ).

CE = Collection efficiency estimated at landfill, taking

into account system coverage, operation, and cover

system materials from Table HH–3 of this subpart. If

area by soil cover type information is not available,

use default value of 0.75 (CE4 in table HH–3 of this

subpart) for all areas under active influence of the

collection system.

N = Number of landfill gas measurement locations

(associated with a destruction device or gas sent offsite). 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 n th 

# measurement location (metric tons).

f Rec,n 

# = Fraction of hours the recovery system associated with

the n th 

# measurement location was operating (annual

operating hours/8760 hours per year or annual

operating hours/8784 hours per year for a leap year).

11. Proposed Amendments to Table MM-1 to 40 CFR part 98, subpar t MM:

# Table MM–1 to Subpart MM of Part 98—Default Factors for

Petroleum Products and Natural Gas Liquids 12



# Products Column A:

density

(metric

tons/bbl) Column B:

carbon

share

(% of

mass) Column C:

emission factor

(metric tons

CO 2 

# / bbl)

Finished Motor Gasoline

Conventional—Summer

Regular 0.1181 86.66 0.3753

Midgrade 0.1183 86.63 0.3758

Premium 0.1185 86.61 0.3763

Conventional—Winter

Regular 0.1155 86.50 0.3663

Midgrade 0.1161 86.55 0.3684

Premium 0.1167 86.59 0.3705

Reformulated—Summer

Regular 0.1167 86.13 0.3686

Midgrade 0.1165 86.07 0.3677

Premium 0.1164 86.00 0.3670

Reformulated—Winter

Regular 0.1165 86.05 0.3676

Midgrade 0.1165 86.06 0.3676

Premium 0.1166 86.06 0.3679

Gasoline—Other 0.1185 86.61 0.3763

Blendstocks

CBOB—Summer

Regular 0.1181 86.66 0.3753

Midgrade 0.1183 86.63 0.3758

Premium 0.1185 86.61 0.3763

CBOB—Winter

Regular 0.1155 86.50 0.3663

Midgrade 0.1161 86.55 0.3684

Premium 0.1167 86.59 0.3705

# Products Column A:

density

(metric

tons/bbl) Column B:

carbon

share

(% of

mass) Column C:

emission factor

(metric tons

CO 2 

# / bbl)

RBOB—Summer

Regular 0.1167 86.13 0.3686

Midgrade 0.1165 86.07 0.3677

Premium 0.1164 86.00 0.3670

RBOB—Winter

Regular 0.1165 86.05 0.3676

Midgrade 0.1165 86.06 0.3676

Premium 0.1166 86.06 0.3679

Blendstocks—Other 0.1185 86.61 0.3763

Oxygenates

Methanol 0.1268 37.48 0.1743

GTBA 0.1257 64.82 0.2988

MTBE 0.1181 68.13 0.2950

ETBE 0.1182 70.53 0.3057

TAME 0.1229 70.53 0.3178

DIPE 0.1156 70.53 0.2990

Distillate Fuel Oil

Distillate No. 1

Ultra Low Sulfur 0.1346 86.40 0.4264

Low Sulfur 0.1346 86.40 0.4264

High Sulfur 0.1346 86.40 0.4264

Distillate No. 2

Ultra Low Sulfur 0.1342 87.30 0.4296

Low Sulfur 0.1342 87.30 0.4296

High Sulfur 0.1342 87.30 0.4296

Distillate Fuel Oil No. 4 0.1452 86.47 0.4604

Residual Fuel Oil No. 5 (Navy

Special) 0.1365 85.67 0.4288

Residual Fuel Oil No. 6 0.1528 84.67 0.4744

# Products Column A:

density

(metric

tons/bbl) Column B:

carbon

share

(% of

mass) Column C:

emission factor

(metric tons

CO 2 

# / bbl)

(a.k.a. Bunker C)

Kerosene-Type Jet Fuel 0.1294 86.30 0.4095

Kerosene 0.1346 86.40 0.4264

Diesel—Other 0.1452 86.47 0.4604

Petrochemical Feedstocks

Naphthas (< 401 °F) 0.1158 84.11 0.3571

Other Oils (> 401 °F) 0.1390 87.30 0.4450

Unfinished Oils

Heavy Gas Oils 0.1476 85.80 0.4643

Residuum 0.1622 85.70 0.5097

Other Petroleum Products and Natural Gas Liquids

Aviation Gasoline 0.1120 85.00 0.3490

Special Naphthas 0.1222 84.76 0.3798

Lubricants 0.1428 85.80 0.4492

Waxes 0.1285 85.30 0.4019

Petroleum Coke 0.1818 92.28 0.6151

Asphalt and Road Oil 0.1634 83.47 0.5001

Still Gas 0.1405 77.70 0.4003

Ethane 3 

# 0.0579 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

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 biomassbased fuel, the carbon share in Table MM–1 of this subpart

represents only the petroleum-based components.

2 

# Products that are derived entirely from biomass should not be

reported, but products that were derived from both 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.

12. Proposed Amendments to Table NN-1 to 40 CFR part 98, subp art NN:

Table NN–1 to Subpart NN of Part 98—Default Factors for

Calculation Methodology 1 of This Subpart

Fuel Default higher heating value 1 

# Default CO 2



# emission factor

(kg CO 2 

# / MMBtu)

Natural Gas 1.026 MMBtu/Mscf 53.06

Propane 3.84 MMBtu/bbl 62.87

Normal butane 4.34 MMBtu/bbl 64.77

Ethane 2.85 MMBtu/bbl 59.60

Isobutane 4.16 MMBtu/bbl 64.94

Pentanes plus 4.62 MMBtu/bbl 70.02

1 

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

13. Proposed Amendments to Table NN-2 to 40 CFR part 98, subp art 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 0.0544

Propane Barrel 0.241

Normal butane Barrel 0.281

Ethane Barrel 0.170

# Fuel Unit Default CO 2



# emission value

(MT CO 2 

# / Unit) 1



# 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.

14. Proposed Amendments to Table TT-1 to 40 CFR part 98, subp art TT:

Table TT–1 to Subpart TT—Default DOC and Decay Rate Values for

Industrial Waste Landfills

Industry/Waste Type DOC

(weight

fraction,

wet basis) k

[dry

climate a 

# ]

(yr −1 

# ) k

[moderate

climate a 

# ]

(yr −1 

# ) k

[wet

climate a 

# ]

(yr −1 

# )

Food Processing

(other than sludge) 0.22 0.06 0.12 0.18

Pulp and Paper (other

than sludge) 0.20 0.02 0.03 0.04

Wood and Wood Product

(other than sludge) 0.43 0.02 0.03 0.04

Construction and

Demolition 0.08 0.02 0.03 0.04

Industrial Sludge 0.09 0.02 0.04 0.06

Inert Waste [i.e.,

wastes listed in

§98.460(c)(2)] 0 0 0 0

Other Industrial

Solid Waste (not

otherwise listed) 0.20 0.02 0.04 0.06

a 

# The applicable climate classification is determined based on the annual

rainfall plus the recirculated leachate application rate. Recirculated

leachate application rate (in inches/year) is the t otal volume of leachate

recirculated from company records or engineering es timates and applied to the

landfill divided by the area of the portion of the landfill containing waste

[with appropriate unit conversions].

# (1) Dry climate = precipitation plus recirculated leachate

less than 20 inches/year

(2) Moderate climate = precipitation plus recirculated

leachate from 20 to 40 inches/year (inclusive)

(3) Wet climate = precipitation plus recirculated leachate

greater than 40 inches/year

Alternatively, landfills that use leachate recirculation

can elect to use the k value for wet climate rather than

calculating the recirculated leachate rate.

(1) Dry climate = precipitation plus recirculated leachate

less than 20 inches/year.