Title 40
PART 98 APPENDIX
| Name | CAS No. | Chemical formula | Global warming potential (100 yr.) |
|---|---|---|---|
| Chemical-Specific GWPs | |||
| Carbon dioxide | 124-38-9 | CO2 | 1 |
| Methane | 74-82-8 | CH4 | a 25 |
| Nitrous oxide | 10024-97-2 | N2O | a 298 |
| Fully Fluorinated GHGs | |||
| Sulfur hexafluoride | 2551-62-4 | SF6 | a 22,800 |
| Trifluoromethyl sulphur pentafluoride | 373-80-8 | SF5CF3 | 17,700 |
| Nitrogen trifluoride | 7783-54-2 | NF3 | 17,200 |
| PFC-14 (Perfluoromethane) | 75-73-0 | CF4 | a 7,390 |
| PFC-116 (Perfluoroethane) | 76-16-4 | C2F6 | a 12,200 |
| PFC-218 (Perfluoropropane) | 76-19-7 | C3F8 | a 8,830 |
| Perfluorocyclopropane | 931-91-9 | C-C3F6 | 17,340 |
| PFC-3-1-10 (Perfluorobutane) | 355-25-9 | C4F10 | a 8,860 |
| PFC-318 (Perfluorocyclobutane) | 115-25-3 | C-C4F8 | a 10,300 |
| PFC-4-1-12 (Perfluoropentane) | 678-26-2 | C5F12 | a 9,160 |
| PFC-5-1-14 (Perfluorohexane, FC-72) | 355-42-0 | C6F14 | a 9,300 |
| PFC-6-1-12 | 335-57-9 | C7F16; CF3(CF2)5CF3 | b 7,820 |
| PFC-7-1-18 | 307-34-6 | C8F18; CF3(CF2)6CF3 | b 7,620 |
| PFC-9-1-18 | 306-94-5 | C10F18 | 7,500 |
| PFPMIE (HT-70) | NA | CF3OCF(CF3)CF2OCF2OCF3 | 10,300 |
| Perfluorodecalin (cis) | 60433-11-6 | Z-C10F18 | b 7,236 |
| Perfluorodecalin (trans) | 60433-12-7 | E-C10F18 | b 6,288 |
| Saturated Hydrofluorocarbons (HFCs) With Two or Fewer Carbon-Hydrogen Bonds | |||
| HFC-23 | 75-46-7 | CHF3 | a 14,800 |
| HFC-32 | 75-10-5 | CH2F2 | a 675 |
| HFC-125 | 354-33-6 | C2HF5 | a 3,500 |
| HFC-134 | 359-35-3 | C2H2F4 | a 1,100 |
| HFC-134a | 811-97-2 | CH2FCF3 | a 1,430 |
| HFC-227ca | 2252-84-8 | CF3CF2CHF2 | b 2640 |
| HFC-227ea | 431-89-0 | C3HF7 | a 3,220 |
| HFC-236cb | 677-56-5 | CH2FCF2CF3 | 1,340 |
| HFC-236ea | 431-63-0 | CHF2CHFCF3 | 1,370 |
| HFC-236fa | 690-39-1 | C3H2F6 | a 9,810 |
| HFC-329p | 375-17-7 | CHF2CF2CF2CF3 | b 2360 |
| HFC-43-10mee | 138495-42-8 | CF3CFHCFHCF2CF3 | a 1,640 |
| Saturated Hydrofluorocarbons (HFCs) With Three or More Carbon-Hydrogen Bonds | |||
| HFC-41 | 593-53-3 | CH3F | a 92 |
| HFC-143 | 430-66-0 | C2H3F3 | a 353 |
| HFC-143a | 420-46-2 | C2H3F3 | a 4,470 |
| HFC-152 | 624-72-6 | CH2FCH2F | 53 |
| HFC-152a | 75-37-6 | CH3CHF2 | a 124 |
| HFC-161 | 353-36-6 | CH3CH2F | 12 |
| HFC-245ca | 679-86-7 | C3H3F5 | a 693 |
| HFC-245cb | 1814-88-6 | CF3CF2CH3 | b 4620 |
| HFC-245ea | 24270-66-4 | CHF2CHFCHF2 | b 235 |
| HFC-245eb | 431-31-2 | CH2FCHFCF3 | b 290 |
| HFC-245fa | 460-73-1 | CHF2CH2CF3 | 1,030 |
| HFC-263fb | 421-07-8 | CH3CH2CF3 | b 76 |
| HFC-272ca | 420-45-1 | CH3CF2CH3 | b 144 |
| HFC-365mfc | 406-58-6 | CH3CF2CH2CF3 | 794 |
| Saturated Hydrofluoroethers (HFEs) and Hydrochlorofluoroethers (HCFEs) With One Carbon-Hydrogen Bond | |||
| HFE-125 | 3822-68-2 | CHF2OCF3 | 14,900 |
| HFE-227ea | 2356-62-9 | CF3CHFOCF3 | 1,540 |
| HFE-329mcc2 | 134769-21-4 | CF3CF2OCF2CHF2 | 919 |
| HFE-329me3 | 428454-68-6 | CF3CFHCF2OCF3 | b 4,550 |
| 1,1,1,2,2,3,3-Heptafluoro-3-(1,2,2,2-tetrafluoroethoxy)-propane | 3330-15-2 | CF3CF2CF2OCHFCF3 | b 6,490 |
| Saturated HFEs and HCFEs With Two Carbon-Hydrogen Bonds | |||
| HFE-134 (HG-00) | 1691-17-4 | CHF2OCHF2 | 6,320 |
| HFE-236ca | 32778-11-3 | CHF2OCF2CHF2 | b 4,240 |
| 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-338mcf2 | 156053-88-2 | CF3CF2OCH2CF3 | 552 |
| HFE-338mmz1 | 26103-08-2 | CHF2OCH(CF3)2 | 380 |
| HFE-338pcc13 (HG-01) | 188690-78-0 | CHF2OCF2CF2OCHF2 | 1,500 |
| HFE-43-10pccc (H-Galden 1040x, HG-11) | E1730133 | CHF2OCF2OC2F4OCHF2 | 1,870 |
| HCFE-235ca2 (Enflurane) | 13838-16-9 | CHF2OCF2CHFCl | b 583 |
| HCFE-235da2 (Isoflurane) | 26675-46-7 | CHF2OCHClCF3 | 350 |
| HG-02 | 205367-61-9 | HF2C-(OCF2CF2)2-OCF2H | b 3,825 |
| HG-03 | 173350-37-3 | HF2C-(OCF2CF2)3-OCF2H | b 3,670 |
| HG-20 | 249932-25-0 | HF2C-(OCF2)2-OCF2H | b 5,300 |
| HG-21 | 249932-26-1 | HF2C-OCF2CF2OCF2OCF2O-CF2H | b 3,890 |
| HG-30 | 188690-77-9 | HF2C-(OCF2)3-OCF2H | b 7,330 |
| 1,1,3,3,4,4,6,6,7,7,9,9,10,10,12,12,13,13,15,15-eicosafluoro-2,5,8,11,14-Pentaoxapentadecane | 173350-38-4 | HCF2O(CF2CF2O)4CF2H | b 3,630 |
| 1,1,2-Trifluoro-2-(trifluoromethoxy)-ethane | 84011-06-3 | CHF2CHFOCF3 | b 1,240 |
| Trifluoro(fluoromethoxy)methane | 2261-01-0 | CH2FOCF3 | b 751 |
| Saturated HFEs and HCFEs With Three or More Carbon-Hydrogen Bonds | |||
| HFE-143a | 421-14-7 | CH3OCF3 | 756 |
| 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-263m1; R-E-143a | 690-22-2 | CF3OCH2CH3 | b 29 |
| HFE-347mcc3 (HFE-7000) | 375-03-1 | CH3OCF2CF2CF3 | 575 |
| HFE-347mcf2 | 171182-95-9 | CF3CF2OCH2CHF2 | 374 |
| HFE-347mmy1 | 22052-84-2 | CH3OCF(CF3)2 | 343 |
| HFE-347mmz1 (Sevoflurane) | 28523-86-6 | (CF3)2CHOCH2F | c 216 |
| HFE-347pcf2 | 406-78-0 | CHF2CF2OCH2CF3 | 580 |
| HFE-356mec3 | 382-34-3 | CH3OCF2CHFCF3 | 101 |
| HFE-356mff2 | 333-36-8 | CF3CH2OCH2CF3 | b 17 |
| HFE-356mmz1 | 13171-18-1 | (CF3)2CHOCH3 | 27 |
| HFE-356pcc3 | 160620-20-2 | CH3OCF2CF2CHF2 | 110 |
| HFE-356pcf2 | 50807-77-7 | CHF2CH2OCF2CHF2 | 265 |
| HFE-356pcf3 | 35042-99-0 | CHF2OCH2CF2CHF2 | 502 |
| HFE-365mcf2 | 22052-81-9 | CF3CF2OCH2CH3 | b 58 |
| HFE-365mcf3 | 378-16-5 | CF3CF2CH2OCH3 | 11 |
| HFE-374pc2 | 512-51-6 | CH3CH2OCF2CHF2 | 557 |
| HFE-449s1 (HFE-7100) Chemical blend | 163702-07-6 | C4F9OCH3 | 297 |
| 163702-08-7 | (CF3)2CFCF2OCH3 | ||
| HFE-569sf2 (HFE-7200) Chemical blend | 163702-05-4 | C4F9OC2H5 | 59 |
| 163702-06-5 | (CF3)2CFCF2OC2H5 | ||
| HG'-01 | 73287-23-7 | CH3OCF2CF2OCH3 | b 222 |
| HG'-02 | 485399-46-0 | CH3O(CF2CF2O)2CH3 | b 236 |
| HG'-03 | 485399-48-2 | CH3O(CF2CF2O)3CH3 | b 221 |
| Difluoro(methoxy)methane | 359-15-9 | CH3OCHF2 | b 144 |
| 2-Chloro-1,1,2-trifluoro-1-methoxyethane | 425-87-6 | CH3OCF2CHFCl | b 122 |
| 1-Ethoxy-1,1,2,2,3,3,3-heptafluoropropane | 22052-86-4 | CF3CF2CF2OCH2CH3 | b 61 |
| 2-Ethoxy-3,3,4,4,5-pentafluorotetrahydro-2,5-bis[1,2,2,2-tetrafluoro-1-(trifluoromethyl)ethyl]-furan | 920979-28-8 | C12H5F19O2 | b 56 |
| 1-Ethoxy-1,1,2,3,3,3-hexafluoropropane | 380-34-7 | CF3CHFCF2OCH2CH3 | b 23 |
| Fluoro(methoxy)methane | 460-22-0 | CH3OCH2F | b 13 |
| 1,1,2,2-Tetrafluoro-3-methoxy-propane; Methyl 2,2,3,3-tetrafluoropropyl ether | 60598-17-6 | CHF2CF2CH2OCH3 | b 0.5 |
| 1,1,2,2-Tetrafluoro-1-(fluoromethoxy)ethane | 37031-31-5 | CH2FOCF2CF2H | b 871 |
| Difluoro(fluoromethoxy)methane | 461-63-2 | CH2FOCHF2 | b 617 |
| Fluoro(fluoromethoxy)methane | 462-51-1 | CH2FOCH2F | b 130 |
| Fluorinated Formates | |||
| Trifluoromethyl formate | 85358-65-2 | HCOOCF3 | b 588 |
| Perfluoroethyl formate | 313064-40-3 | HCOOCF2CF3 | b 580 |
| 1,2,2,2-Tetrafluoroethyl formate | 481631-19-0 | HCOOCHFCF3 | b 470 |
| Perfluorobutyl formate | 197218-56-7 | HCOOCF2CF2CF2CF3 | b 392 |
| Perfluoropropyl formate | 271257-42-2 | HCOOCF2CF2CF3 | b 376 |
| 1,1,1,3,3,3-Hexafluoropropan-2-yl formate | 856766-70-6 | HCOOCH(CF3)2 | b 333 |
| 2,2,2-Trifluoroethyl formate | 32042-38-9 | HCOOCH2CF3 | b 33 |
| 3,3,3-Trifluoropropyl formate | 1344118-09-7 | HCOOCH2CH2CF3 | b 17 |
| Fluorinated Acetates | |||
| Methyl 2,2,2-trifluoroacetate | 431-47-0 | CF3COOCH3 | b 52 |
| 1,1-Difluoroethyl 2,2,2-trifluoroacetate | 1344118-13-3 | CF3COOCF2CH3 | b 31 |
| Difluoromethyl 2,2,2-trifluoroacetate | 2024-86-4 | CF3COOCHF2 | b 27 |
| 2,2,2-Trifluoroethyl 2,2,2-trifluoroacetate | 407-38-5 | CF3COOCH2CF3 | b 7 |
| Methyl 2,2-difluoroacetate | 433-53-4 | HCF2COOCH3 | b 3 |
| Perfluoroethyl acetate | 343269-97-6 | CH3COOCF2CF3 | b 2.1 |
| Trifluoromethyl acetate | 74123-20-9 | CH3COOCF3 | b 2.0 |
| Perfluoropropyl acetate | 1344118-10-0 | CH3COOCF2CF2CF3 | b 1.8 |
| Perfluorobutyl acetate | 209597-28-4 | CH3COOCF2CF2CF2CF3 | b 1.6 |
| Ethyl 2,2,2-trifluoroacetate | 383-63-1 | CF3COOCH2CH3 | b 1.3 |
| Carbonofluoridates | |||
| Methyl carbonofluoridate | 1538-06-3 | FCOOCH3 | b 95 |
| 1,1-Difluoroethyl carbonofluoridate | 1344118-11-1 | FCOOCF2CH3 | b 27 |
| Fluorinated Alcohols Other Than Fluorotelomer Alcohols | |||
| Bis(trifluoromethyl)-methanol | 920-66-1 | (CF3)2CHOH | 195 |
| (Octafluorotetramethy-lene) hydroxymethyl group | NA | X-(CF2)4CH(OH)-X | 73 |
| 2,2,3,3,3-Pentafluoropropanol | 422-05-9 | CF3CF2CH2OH | 42 |
| 2,2,3,3,4,4,4-Heptafluorobutan-1-ol | 375-01-9 | C3F7CH2OH | b 25 |
| 2,2,2-Trifluoroethanol | 75-89-8 | CF3CH2OH | b 20 |
| 2,2,3,4,4,4-Hexafluoro-1-butanol | 382-31-0 | CF3CHFCF2CH2OH | b 17 |
| 2,2,3,3-Tetrafluoro-1-propanol | 76-37-9 | CHF2CF2CH2OH | b 13 |
| 2,2-Difluoroethanol | 359-13-7 | CHF2CH2OH | b 3 |
| 2-Fluoroethanol | 371-62-0 | CH2FCH2OH | b 1.1 |
| 4,4,4-Trifluorobutan-1-ol | 461-18-7 | CF3(CH2)2CH2OH | b 0.05 |
| Unsaturated Perfluorocarbons (PFCs) | |||
| PFC-1114; TFE | 116-14-3 | CF2 = CF2; C2F4 | b 0.004 |
| PFC-1216; Dyneon HFP | 116-15-4 | C3F6; CF3CF = CF2 | b 0.05 |
| PFC C-1418 | 559-40-0 | c-C5F8 | b 1.97 |
| Perfluorobut-2-ene | 360-89-4 | CF3CF = CFCF3 | b 1.82 |
| Perfluorobut-1-ene | 357-26-6 | CF3CF2CF = CF2 | b 0.10 |
| Perfluorobuta-1,3-diene | 685-63-2 | CF2 = CFCF = CF2 | b 0.003 |
| Unsaturated Hydrofluorocarbons (HFCs) and Hydrochlorofluorocarbons (HCFCs) | |||
| HFC-1132a; VF2 | 75-38-7 | C2H2F2 , CF2 = CH2 | b 0.04 |
| HFC-1141; VF | 75-02-5 | C2H3F, CH2 = CHF | b 0.02 |
| (E)-HFC-1225ye | 5595-10-8 | CF3CF = CHF(E) | b 0.06 |
| (Z)-HFC-1225ye | 5528-43-8 | CF3CF = CHF(Z) | b 0.22 |
| Solstice 1233zd(E) | 102687-65-0 | C3H2ClF3; CHCl = CHCF3 | b 1.34 |
| HFC-1234yf; HFO-1234yf | 754-12-1 | C3H2F4; CF3CF = CH2 | b 0.31 |
| HFC-1234ze(E) | 1645-83-6 | C3H2F4; trans-CF3CH = CHF | b 0.97 |
| HFC-1234ze(Z) | 29118-25-0 | C3H2F4; cis-CF3CH = CHF; CF3CH = CHF | b 0.29 |
| HFC-1243zf; TFP | 677-21-4 | C3H3F3, CF3CH = CH2 | b 0.12 |
| (Z)-HFC-1336 | 692-49-9 | CF3CH = CHCF3(Z) | b 1.58 |
| HFC-1345zfc | 374-27-6 | C2F5CH = CH2 | b 0.09 |
| Capstone 42-U | 19430-93-4 | C6H3F9, CF3(CF2)3CH = CH2 | b 0.16 |
| Capstone 62-U | 25291-17-2 | C8H3F13, CF3(CF2)5CH = CH2 | b 0.11 |
| Capstone 82-U | 21652-58-4 | C10H3F17, CF3(CF2)7CH = CH2 | b 0.09 |
| Unsaturated Halogenated Ethers | |||
| PMVE; HFE-216 | 1187-93-5 | CF3OCF = CF2 | b 0.17 |
| Fluoroxene | 406-90-6 | CF3CH2OCH = CH2 | b 0.05 |
| Fluorinated Aldehydes | |||
| 3,3,3-Trifluoro-propanal | 460-40-2 | CF3CH2CHO | b 0.01 |
| Fluorinated Ketones | |||
| Novec 1230 (perfluoro (2-methyl-3-pentanone)) | 756-13-8 | CF3CF2C(O)CF (CF3)2 | b 0.1 |
| Fluorotelomer Alcohols | |||
| 3,3,4,4,5,5,6,6,7,7,7-Undecafluoroheptan-1-ol | 185689-57-0 | CF3(CF2)4CH2CH2OH | b 0.43 |
| 3,3,3-Trifluoropropan-1-ol | 2240-88-2 | CF3CH2CH2OH | b 0.35 |
| 3,3,4,4,5,5,6,6,7,7,8,8,9,9,9-Pentadecafluorononan-1-ol | 755-02-2 | CF3(CF2)6CH2CH2OH | b 0.33 |
| 3,3,4,4,5,5,6,6,7,7,8,8,9,9,10,10,11,11,11-Nonadecafluoroundecan-1-ol | 87017-97-8 | CF3(CF2)8CH2CH2OH | b 0.19 |
| Fluorinated GHGs With Carbon-Iodine Bond(s) | |||
| Trifluoroiodomethane | 2314-97-8 | CF3I | b 0.4 |
| Other Fluorinated Compounds | |||
| Dibromodifluoromethane (Halon 1202) | 75-61-6 | CBR2F2 | b 231 |
| 2-Bromo-2-chloro-1,1,1-trifluoroethane (Halon-2311/Halothane) | 151-67-7 | CHBrClCF3 | b 41 |
| Fluorinated GHG Group d | Global warming potential (100 yr.) |
|---|---|
| Default GWPs for Compounds for Which Chemical-Specific GWPs Are Not Listed Above | |
| Fully fluorinated GHGs | 10,000 |
| Saturated hydrofluorocarbons (HFCs) with 2 or fewer carbon-hydrogen bonds | 3,700 |
| Saturated HFCs with 3 or more carbon-hydrogen bonds | 930 |
| Saturated hydrofluoroethers (HFEs) and hydrochlorofluoroethers (HCFEs) with 1 carbon-hydrogen bond | 5,700 |
| Saturated HFEs and HCFEs with 2 carbon-hydrogen bonds | 2,600 |
| Saturated HFEs and HCFEs with 3 or more carbon-hydrogen bonds | 270 |
| Fluorinated formates | 350 |
| Fluorinated acetates, carbonofluoridates, and fluorinated alcohols other than fluorotelomer alcohols | 30 |
| Unsaturated perfluorocarbons (PFCs), unsaturated HFCs, unsaturated hydrochlorofluorocarbons (HCFCs), unsaturated halogenated ethers, unsaturated halogenated esters, fluorinated aldehydes, and fluorinated ketones | 1 |
| Fluorotelomer alcohols | 1 |
| Fluorinated GHGs with carbon-iodine bond(s) | 1 |
| Other fluorinated GHGs | 2,000 |
a The GWP for this compound was updated in the final rule published on November 29, 2013 [78 FR 71904] and effective on January 1, 2014.
b This compound was added to Table A-1 in the final rule published on December 11, 2014, and effective on January 1, 2015.
c The GWP for this compound was updated in the final rule published on December 11, 2014, and effective on January 1, 2015 .
d For electronics manufacturing (as defined in § 98.90), the term “fluorinated GHGs” in the definition of each fluorinated GHG group in § 98.6 shall include fluorinated heat transfer fluids (as defined in § 98.98), whether or not they are also fluorinated GHGs.
Table A-2 to Subpart A of Part 98 - Units of Measure Conversions
40:23.0.1.1.3.1.1.10.12 :
Table A-2 to Subpart A of Part 98 - Units of Measure Conversions| To convert from | To | Multiply by |
|---|---|---|
| Kilograms (kg) | Pounds (lbs) | 2.20462 |
| Pounds (lbs) | Kilograms (kg) | 0.45359 |
| Pounds (lbs) | Metric tons | 4.53592 × 10−4 |
| Short tons | Pounds (lbs) | 2,000 |
| Short tons | Metric tons | 0.90718 |
| Metric tons | Short tons | 1.10231 |
| Metric tons | Kilograms (kg) | 1,000 |
| Cubic meters (m 3) | Cubic feet (ft 3) | 35.31467 |
| Cubic feet (ft 3) | Cubic meters (m 3) | 0.028317 |
| Gallons (liquid, US) | Liters (l) | 3.78541 |
| Liters (l) | Gallons (liquid, US) | 0.26417 |
| Barrels of Liquid Fuel (bbl) | Cubic meters (m 3) | 0.15891 |
| Cubic meters (m 3) | Barrels of Liquid Fuel (bbl) | 6.289 |
| Barrels of Liquid Fuel (bbl) | Gallons (liquid, US) | 42 |
| Gallons (liquid, US) | Barrels of Liquid Fuel (bbl) | 0.023810 |
| Gallons (liquid, US) | Cubic meters (m 3) | 0.0037854 |
| Liters (l) | Cubic meters (m 3) | 0.001 |
| Feet (ft) | Meters (m) | 0.3048 |
| Meters (m) | Feet (ft) | 3.28084 |
| Miles (mi) | Kilometers (km) | 1.60934 |
| Kilometers (km) | Miles (mi) | 0.62137 |
| Square feet (ft 2) | Acres | 2.29568 × 10−5 |
| Square meters (m 2) | Acres | 2.47105 × 10−4 |
| Square miles (mi 2) | Square kilometers (km 2) | 2.58999 |
| Degrees Celsius (°C) | Degrees Fahrenheit (°F) | °C = ( 5/9) × (°F −32) |
| Degrees Fahrenheit (°F) | Degrees Celsius (°C) | °F = ( 9/5) × °C + 32 |
| Degrees Celsius (°C) | Kelvin (K) | K = °C + 273.15 |
| Kelvin (K) | Degrees Rankine (°R) | 1.8 |
| Joules | Btu | 9.47817 × 10−4 |
| Btu | MMBtu | 1 × 10−6 |
| Pascals (Pa) | Inches of Mercury (in Hg) | 2.95334 × 10−4 |
| Inches of Mercury (inHg) | Pounds per square inch (psi) | 0.49110 |
| Pounds per square inch (psi) | Inches of Mercury (in Hg) | 2.03625 |
Table A-3 to Subpart A of Part 98 - Source Category List for § 98.2(a)(1)
40:23.0.1.1.3.1.1.10.13 :
Table A-3 to Subpart A of Part 98 - Source Category List for § 98.2(a)(1)Source Category List for § 98.2(a)(1)
| Source Categories a Applicable in Reporting Year 2010 and Future Years |
| Electricity generation units that report CO2 mass emissions year round through 40 CFR part 75 (subpart D). |
| Adipic acid production (subpart E). |
| Aluminum production (subpart F). |
| Ammonia manufacturing (subpart G). |
| Cement production (subpart H). |
| HCFC-22 production (subpart O). |
| HFC-23 destruction processes that are not collocated with a HCFC-22 production facility and that destroy more than 2.14 metric tons of HFC-23 per year (subpart O). |
| Lime manufacturing (subpart S). |
| Nitric acid production (subpart V). |
| Petrochemical production (subpart X). |
| Petroleum refineries (subpart Y). |
| Phosphoric acid production (subpart Z). |
| Silicon carbide production (subpart BB). |
| Soda ash production (subpart CC). |
| Titanium dioxide production (subpart EE). |
| Municipal solid waste landfills that generate CH4 in amounts equivalent to 25,000 metric tons CO2e or more per year, as determined according to subpart HH of this part. |
| Manure management systems with combined CH4 and N2O emissions in amounts equivalent to 25,000 metric tons CO2e or more per year, as determined according to subpart JJ of this part. |
| Additional Source Categories a Applicable in Reporting Year 2011 and Future Years |
| Electrical transmission and distribution equipment use at facilities where the total nameplate capacity of SF6 and PFC containing equipment exceeds 17,820 pounds, as determined under § 98.301 (subpart DD). |
| Underground coal mines liberating 36,500,000 actual cubic feet of CH4 or more per year (subpart FF). |
| Geologic sequestration of carbon dioxide (subpart RR). |
| Electrical transmission and distribution equipment manufacture or refurbishment (subpart SS). |
| Injection of carbon dioxide (subpart UU). |
a Source categories are defined in each applicable subpart.
Table A-4 to Subpart A of Part 98 - Source Category List for § 98.2(a)(2)
40:23.0.1.1.3.1.1.10.14 :
Table A-4 to Subpart A of Part 98 - Source Category List for § 98.2(a)(2)| Source Categories a Applicable in Reporting Year 2010 and Future Years |
| Ferroalloy production (subpart K). |
| Glass production (subpart N). |
| Hydrogen production (subpart P). |
| Iron and steel production (subpart Q). |
| Lead production (subpart R). |
| Pulp and paper manufacturing (subpart AA). |
| Zinc production (subpart GG). |
| Additional Source Categories a Applicable in Reporting Year 2011 and Future Years |
| Electronics manufacturing (subpart I) |
| Fluorinated gas production (subpart L) |
| Magnesium production (subpart T). |
| Petroleum and Natural Gas Systems (subpart W) |
| Industrial wastewater treatment (subpart II). |
| Industrial waste landfills (subpart TT). |
a Source categories are defined in each applicable subpart.
Table A-5 to Subpart A of Part 98 - Supplier Category List for § 98.2(a)(4)
40:23.0.1.1.3.1.1.10.15 :
Table A-5 to Subpart A of Part 98 - Supplier Category List for § 98.2(a)(4)| Supplier Categories a Applicable in Reporting Year 2010 and Future Years |
| Coal-to-liquids suppliers (subpart LL): |
| (A) All producers of coal-to-liquid products. |
| (B) Importers of an annual quantity of coal-to-liquid products that is equivalent to 25,000 metric tons CO2e or more. |
| (C) Exporters of an annual quantity of coal-to-liquid products that is equivalent to 25,000 metric tons CO2e or more. |
| Petroleum
product suppliers (subpart MM): |
| (A) All petroleum refineries that distill crude oil. |
| (B) Importers of an annual quantity of petroleum products and natural gas liquids that is equivalent to 25,000 metric tons CO2e or more. |
| (C) Exporters of an annual quantity of petroleum products and natural gas liquids that is equivalent to 25,000 metric tons CO2e or more. |
| Natural gas and natural gas liquids suppliers (subpart NN): |
| (A) All fractionators. |
| (B) Local natural gas distribution companies that deliver 460,000 thousand standard cubic feet or more of natural gas per year. |
| Industrial greenhouse gas suppliers (subpart OO): |
| (A) All producers of industrial greenhouse gases. |
| (B) Importers of industrial greenhouse gases with annual bulk imports of N2O, fluorinated GHG, and CO2 that in combination are equivalent to 25,000 metric tons CO2e or more. |
| (C) Exporters of industrial greenhouse gases with annual bulk exports of N2O, fluorinated GHG, and CO2 that in combination are equivalent to 25,000 metric tons CO2e or more. |
| (D) Starting with reporting year 2018, all producers of fluorinated heat transfer fluids. |
| (E) Starting with reporting year 2018, importers of fluorinated heat transfer fluids with annual bulk imports of N2O, fluorinated GHG, fluorinated heat transfer fluids, and CO2 that in combination are equivalent to 25,000 metric tons CO2e or more. |
| (F) Starting with reporting year 2018, exporters of fluorinated heat transfer fluids with annual bulk exports of N2O, fluorinated GHG, fluorinated heat transfer fluids, and CO2 that in combination are equivalent to 25,000 metric tons CO2e or more. |
| (G) Starting with reporting year 2018, facilities that destroy 25,000 mtCO2e or more of fluorinated GHGs or fluorinated heat transfer fluids annually. |
| Carbon dioxide suppliers (subpart PP): |
| (A) All producers of CO2. |
| (B) Importers of CO2 with annual bulk imports of N2O, fluorinated GHG, and CO2 that in combination are equivalent to 25,000 metric tons CO2e or more. |
| (C) Exporters of CO2 with annual bulk exports of N2O, fluorinated GHG, and CO2 that in combination are equivalent to 25,000 metric tons CO2e or more. |
| Additional Supplier Categories Applicable a in Reporting Year 2011 and Future Years |
| Importers and exporters of fluorinated greenhouse gases contained in pre-charged equipment or closed-cell foams (subpart QQ): |
| (A) Importers of an annual quantity of fluorinated greenhouse gases contained in pre-charged equipment or closed-cell foams that is equivalent to 25,000 metric tons CO2e or more. |
| (B) Exporters of an annual quantity of fluorinated greenhouse gases contained in pre-charged equipment or closed-cell foams that is equivalent to 25,000 metric tons CO2e or more. |
a Suppliers are defined in each applicable subpart.
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
40:23.0.1.1.3.1.1.10.16 :
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. |
| 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 CH4 concentration. |
| FF | 98.326(h) | Only weekly volumetric flow used to calculate CH4 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 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 CH4 in landfill gas and methane correction factor (MCF) values. |
| HH | 98.346(f) | Only surface area associated with each cover type. |
| HH | 98.346(g) | All. |
| HH | 98.346(i)(5) | Only annual operating hours for the destruction devices located at the landfill facility, and the destruction efficiency for the destruction devices associated with that measurement location. |
| HH | 98.346(i)(6) | All. |
| HH | 98.346(i)(7) | Only surface area specified in Table HH-3, estimated gas collection system efficiency, and annual operating hours of the gas collection system for each measurement locations. |
| HH | 98.346(i)(9) | Only CH4 generation value. |
| II | 98.356(b)(1) | All. |
| II | 98.356(b)(2) | All. |
| II | 98.356(b)(3) | All. |
| II | 98.356(b)(4) | All. |
| II | 98.356(b)(5) | All. |
| II | 98.356(d)(1) | All. |
| II | 98.356(d)(7) | All. |
| II | 98.356(d)(8) | Only annual operating hours for the primary destruction device, annual operating hours for the backup destruction device, destruction efficiency of the primary destruction device, and destruction efficiency of the backup destruction device. |
| SS | 98.456(a) | All. |
| SS | 98.456(b) | All. |
| SS | 98.456(c) | All. |
| SS | 98.456(d) | All. |
| SS | 98.456(e) | All. |
| SS | 98.456(f) | All. |
| SS | 98.456(g) | All. |
| SS | 98.456(h) | All. |
| SS | 98.456(i) | All. |
| SS | 98.456(j) | All. |
| SS | 98.456(m) | All. |
| SS | 98.456(n) | All. |
| SS | 98.456(o) | All. |
| SS | 98.456(q) | All. |
| SS | 98.456(r) | All. |
| SS | 98.456(s) | All. |
| SS | 98.456(t) | Only for any missing data the substitute parameters used to estimate emissions in their absence. |
| TT | 98.466(a)(2) | All. |
| TT | 98.466(a)(3) | Only last year the landfill accepted waste (for closed landfills using Equation TT-4). |
| TT | 98.466(a)(4) | Only capacity of the landfill in metric tons (for closed landfills using Equation TT-4). |
| TT | 98.466(b)(3) | Only fraction of CH4 in landfill gas. |
| TT | 98.466(b)(4) | Only the methane correction factor (MCF) value used in the calculations. |
| TT | 98.466(c)(4)(i) | All. |
| TT | 98.466(c)(4)(ii) | All. |
| TT | 98.466(c)(4)(iii) | All. |
| TT | 98.466(d)(2) | All. |
| TT | 98.466(d)(3) | Only degradable organic carbon (DOCx) value for each waste stream used in calculations. |
| TT | 98.466(e)(2) | Only surface area (in square meters) at the start of the reporting 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. |
Table A-7 to Subpart A of Part 98 - Data Elements That Are Inputs to Emission Equations and for Which the Reporting Deadline Is March 31, 2015
40:23.0.1.1.3.1.1.10.17 :
Table A-7 to Subpart A of Part 98 - Data Elements That Are Inputs to Emission Equations and for Which the Reporting Deadline Is March 31, 2015| Subpart | Rule citation (40 CFR part 98) |
Specific data elements for
which reporting date is March 31, 2015 (“All” means all data elements in the cited paragraph are not required to be reported until March 31, 2015) |
|---|---|---|
| A | 98.3(d)(3)(v) | All. a |
| C | 98.36(b)(9)(iii) | Only estimate of the heat input. a |
| C | 98.36(c)(2)(ix) | Only estimate of the heat input from each type of fuel listed in Table C-2. a |
| C | 98.36(e)(2)(i) | All. a |
| C | 98.36(e)(2)(ii)(A) | All. a |
| C | 98.36(e)(2)(ii)(C) | Only HHV value for each calendar month in which HHV determination is required. a |
| C | 98.36(e)(2)(ii)(D) | All. a |
| C | 98.36(e)(2)(iv)(A) | All. a |
| C | 98.36(e)(2)(iv)(C) | All. a |
| C | 98.36(e)(2)(iv)(F) | All. a |
| C | 98.36(e)(2)(ix)(D) | All. a |
| C | 98.36(e)(2)(ix)(E) | All. a |
| C | 98.36(e)(2)(ix)(F) | All. a |
| E | 98.56(g) | All. |
| E | 98.56(h) | All. |
| E | 98.56(j)(4) | All. |
| E | 98.56(j)(5) | All. |
| E | 98.56(j)(6) | All. |
| E | 98.56(l) | All. |
| H | 98.86(b)(11) | All. |
| H | 98.86(b)(13) | Name of raw kiln feed or raw material. |
| O | 98.156(d)(2) | All. |
| O | 98.156(d)(3) | All. |
| O | 98.156(d)(4) | All. |
| Q | 98.176(f)(1) | All. |
| W | 98.236(c)(1)(i) | All. |
| W | 98.236(c)(1)(ii) | All. |
| W | 98.236(c)(1)(iii) | All. |
| W | 98.236(c)(2)(i) | All. |
| W | 98.236(c)(3)(i) | All. |
| W | 98.236(c)(3)(ii) | Only Calculation Methodology 2. |
| W | 98.236(c)(3)(iii) | All. |
| W | 98.236(c)(3)(iv) | All. |
| W | 98.236(c)(4)(i)(A) | All. |
| W | 98.236(c)(4)(i)(B) | All. |
| W | 98.236(c)(4)(i)(C) | All. |
| W | 98.236(c)(4)(i)(D) | All. |
| W | 98.236(c)(4)(i)(E) | All. |
| W | 98.236(c)(4)(i)(F) | All. |
| W | 98.236(c)(4)(i)(G) | All. |
| W | 98.236(c)(4)(i)(H) | All. |
| W | 98.236(c)(4)(ii)(A) | All. |
| W | 98.236(c)(5)(i)(D) | All. |
| W | 98.236(c)(5)(ii)(C) | All. |
| W | 98.236(c)(6)(i)(B) | All. b |
| W | 98.236(c)(6)(i)(D) | All. b |
| W | 98.236(c)(6)(i)(E) | All. b |
| W | 98.236(c)(6)(i)(F) | All. b |
| W | 98.236(c)(6)(i)(G) | Only the amount of natural gas required. |
| W | 98.236(c)(6)(i)(H) | Only the amount of natural gas required. |
| W | 98.236(c)(6)(ii)(A) | All. |
| W | 98.236(c)(6)(ii)(B) | All. |
| W | 98.236(c)(7)(i)(A) | Only for Equation W-14A. |
| W | 98.236(c)(8)(i)(F) | All. b |
| W | 98.236(c)(8)(i)(K) | All. |
| W | 98.236(c)(8)(ii)(A) | All. b |
| W | 98.236(c)(8)(ii)(H) | All. |
| W | 98.236(c)(8)(iii)(A) | All. |
| W | 98.236(c)(8)(iii)(B) | All. |
| W | 98.236(c)(8)(iii)(G) | All. |
| W | 98.236(c)(12)(ii) | All. |
| W | 98.236(c)(12)(v) | All. |
| W | 98.236(c)(13)(i)(E) | All. |
| W | 98.236(c)(13)(i)(F) | All. |
| W | 98.236(c)(13)(ii)(A) | All. |
| W | 98.236(c)(13)(ii)(B) | All. |
| W | 98.236(c)(13)(iii)(A) | All. |
| W | 98.236(c)(13)(iii)(B) | All. |
| W | 98.236(c)(13)(v)(A) | All. |
| W | 98.236(c)(14)(i)(B) | All. |
| W | 98.236(c)(14)(ii)(A) | All. |
| W | 98.236(c)(14)(ii)(B) | All. |
| W | 98.236(c)(14)(iii)(A) | All. |
| W | 98.236(c)(14)(iii)(B) | All. |
| W | 98.236(c)(14)(v)(A) | All. |
| W | 98.236(c)(15)(ii)(A) | All. |
| W | 98.236(c)(15)(ii)(B) | All. |
| W | 98.236(c)(16)(viii) | All. |
| W | 98.236(c)(16)(ix) | All. |
| W | 98.236(c)(16)(x) | All. |
| W | 98.236(c)(16)(xi) | All. |
| W | 98.236(c)(16)(xii) | All. |
| W | 98.236(c)(16)(xiii) | All. |
| W | 98.236(c)(16)(xiv) | All. |
| W | 98.236(c)(16)(xv) | All. |
| W | 98.236(c)(16)(xvi) | All. |
| W | 98.236(c)(17)(ii) | All. |
| W | 98.236(c)(17)(iii) | All. |
| W | 98.236(c)(17)(iv) | All. |
| W | 98.236(c)(18)(i) | All. |
| W | 98.236(c)(18)(ii) | All. |
| W | 98.236(c)(19)(iv) | All. |
| W | 98.236(c)(19)(vii) | All. |
| Y | 98.256(h)(5)(i) | Only value of the correction. |
| Y | 98.256(k)(4) | Only mole fraction of methane in coking gas. |
| Y | 98.256(n)(3) | All (if used in Equation Y-21 to calculate emissions from equipment leaks). |
| Y | 98.256(o)(4)(vi) | Only tank-specific methane composition data and gas generation rate data. |
| AA | 98.276(e) | All. |
| CC | 98.296(b)(10)(i) | All. |
| CC | 98.296(b)(10)(ii) | All. |
| CC | 98.296(b)(10)(iii) | All. |
| CC | 98.296(b)(10)(iv) | All. |
| CC | 98.296(b)(10)(v) | All. |
| CC | 98.296(b)(10)(vi) | All. |
| II | 98.356(d)(2) | All (if conducting weekly sampling). |
| II | 98.356(d)(3) | All (if conducting weekly sampling). |
| II | 98.356(d)(4) | Only weekly average temperature (if conducting weekly sampling). |
| II | 98.356(d)(5) | Only weekly average moisture content (if conducting weekly sampling). |
| II | 98.356(d)(6) | Only weekly average pressure (if conducting weekly sampling). |
a Required to be reported only by: (1) Stationary fuel combustion sources (e.g., individual units, aggregations of units, common pipes, or common stacks) subject to subpart C of this part that contain at least one combustion unit connected to a fuel-fired electric generator owned or operated by an entity that is subject to regulation of customer billing rates by the PUC (excluding generators connected to combustion units subject to 40 CFR part 98, subpart D) and that are located at a facility for which the sum of the nameplate capacities for all such electric generators is greater than or equal to 1 megawatt electric output; and (2) stationary fuel combustion sources (e.g., individual units, aggregations of units, common pipes, or common stacks) subject to subpart C of this part that do not meet the criteria in (1) of this footnote that elect to report these data elements, as provided in § 98.36(a), for reporting year 2014.
b This rule citation provides an option to delay reporting of this data element for certain wildcat wells and/or delineation wells.
Table C-1 to Subpart C of Part 98 - Default CO2 Emission Factors and High Heat Values for Various Types of Fuel
40:23.0.1.1.3.3.1.10.18 :
Table C-1 to Subpart C of Part 98 - Default CO2 Emission Factors and High Heat Values for Various Types of FuelDefault CO2 Emission Factors and High Heat Values for Various Types of Fuel
| Fuel type | Default high heat value | Default CO2 emission factor |
|---|---|---|
| Coal and coke | mmBtu/short ton | kg CO2/mmBtu |
| Anthracite | 25.09 | 103.69 |
| Bituminous | 24.93 | 93.28 |
| Subbituminous | 17.25 | 97.17 |
| Lignite | 14.21 | 97.72 |
| Coal Coke | 24.80 | 113.67 |
| Mixed (Commercial sector) | 21.39 | 94.27 |
| Mixed (Industrial coking) | 26.28 | 93.90 |
| Mixed (Industrial sector) | 22.35 | 94.67 |
| Mixed (Electric Power sector) | 19.73 | 95.52 |
| Natural gas | mmBtu/scf | kg CO2/mmBtu |
| (Weighted U.S. Average) | 1.026 × 10−3 | 53.06 |
| Petroleum products - liquid | mmBtu/gallon | kg CO2/mmBtu |
| Distillate Fuel Oil No. 1 | 0.139 | 73.25 |
| Distillate Fuel Oil No. 2 | 0.138 | 73.96 |
| Distillate Fuel Oil No. 4 | 0.146 | 75.04 |
| Residual Fuel Oil No. 5 | 0.140 | 72.93 |
| Residual Fuel Oil No. 6 | 0.150 | 75.10 |
| Used Oil | 0.138 | 74.00 |
| Kerosene | 0.135 | 75.20 |
| Liquefied petroleum gases (LPG) 1 | 0.092 | 61.71 |
| Propane 1 | 0.091 | 62.87 |
| Propylene 2 | 0.091 | 67.77 |
| Ethane 1 | 0.068 | 59.60 |
| Ethanol | 0.084 | 68.44 |
| Ethylene 2 | 0.058 | 65.96 |
| Isobutane 1 | 0.099 | 64.94 |
| Isobutylene 1 | 0.103 | 68.86 |
| Butane 1 | 0.103 | 64.77 |
| Butylene 1 | 0.105 | 68.72 |
| Naphtha (<401 deg F) | 0.125 | 68.02 |
| Natural Gasoline | 0.110 | 66.88 |
| Other Oil (>401 deg F) | 0.139 | 76.22 |
| Pentanes Plus | 0.110 | 70.02 |
| Petrochemical Feedstocks | 0.125 | 71.02 |
| Special Naphtha | 0.125 | 72.34 |
| Unfinished Oils | 0.139 | 74.54 |
| Heavy Gas Oils | 0.148 | 74.92 |
| Lubricants | 0.144 | 74.27 |
| Motor Gasoline | 0.125 | 70.22 |
| Aviation Gasoline | 0.120 | 69.25 |
| Kerosene-Type Jet Fuel | 0.135 | 72.22 |
| Asphalt and Road Oil | 0.158 | 75.36 |
| Crude Oil | 0.138 | 74.54 |
| Petroleum products - solid | mmBtu/short ton | kg CO2/mmBtu. |
| Petroleum Coke | 30.00 | 102.41. |
| Petroleum products - gaseous | mmBtu/scf | kg CO2/mmBtu. |
| Propane Gas | 2.516 × 10−3 | 61.46. |
| Other fuels - solid | mmBtu/short ton | kg CO2/mmBtu |
| Municipal Solid Waste | 9.95 3 | 90.7 |
| Tires | 28.00 | 85.97 |
| Plastics | 38.00 | 75.00 |
| Other fuels - gaseous | mmBtu/scf | kg CO2/mmBtu |
| Blast Furnace Gas | 0.092 × 10−3 | 274.32 |
| Coke Oven Gas | 0.599 × 10−3 | 46.85 |
| Fuel Gas 4 | 1.388 × 10−3 | 59.00 |
| Biomass fuels - solid | mmBtu/short ton | kg CO2/mmBtu |
| Wood and Wood Residuals (dry basis) 5 | 17.48 | 93.80 |
| Agricultural Byproducts | 8.25 | 118.17 |
| Peat | 8.00 | 111.84 |
| Solid Byproducts | 10.39 | 105.51 |
| Biomass fuels - gaseous | mmBtu/scf | kg CO2/mmBtu |
| Landfill Gas | 0.485 × 10−3 | 52.07 |
| Other Biomass Gases | 0.655 × 10−3 | 52.07 |
| Biomass Fuels - Liquid | mmBtu/gallon | kg CO2/mmBtu |
| Ethanol | 0.084 | 68.44 |
| Biodiesel (100%) | 0.128 | 73.84 |
| Rendered Animal Fat | 0.125 | 71.06 |
| Vegetable Oil | 0.120 | 81.55 |
1 The HHV for components of LPG determined at 60 °F and saturation pressure with the exception of ethylene.
2 Ethylene HHV determined at 41 °F (5 °C) and saturation pressure.
3 Use of this default HHV is allowed only for: (a) Units that combust MSW, do not generate steam, and are allowed to use Tier 1; (b) units that derive no more than 10 percent of their annual heat input from MSW and/or tires; and (c) small batch incinerators that combust no more than 1,000 tons of MSW per year.
4 Reporters subject to subpart X of this part that are complying with § 98.243(d) or subpart Y of this part may only use the default HHV and the default CO2 emission factor for fuel gas combustion under the conditions prescribed in § 98.243(d)(2)(i) and (d)(2)(ii) and § 98.252(a)(1) and (a)(2), respectively. Otherwise, reporters subject to subpart X or subpart Y shall use either Tier 3 (Equation C-5) or Tier 4.
5 Use the following formula to calculate a wet basis HHV for use in Equation C-1: HHVw = ((100 − M)/100)*HHVd where HHVw = wet basis HHV, M = moisture content (percent) and HHVd = dry basis HHV from Table C-1.
Table C-2 to Subpart C of Part 98 - Default CH4 and N2O Emission Factors for Various Types of Fuel
40:23.0.1.1.3.3.1.10.19 :
Table C-2 to Subpart C of Part 98 - Default CH4 and N2O Emission Factors for Various Types of Fuel| Fuel type | Default CH4 emission factor (kg CH4/mmBtu) | Default N2O emission factor (kg N2O/mmBtu) |
|---|---|---|
| Coal and Coke (All fuel types in Table C-1) | 1.1 × 10−02 | 1.6 × 10−03 |
| Natural Gas | 1.0 × 10−03 | 1.0 × 10−04 |
| Petroleum Products (All fuel types in Table C-1) | 3.0 × 10−03 | 6.0 × 10−04 |
| Fuel Gas | 3.0 × 10−03 | 6.0 × 10−04 |
| Other Fuels - Solid | 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 × 10−03 | 3.6 × 10−03 |
| Biomass Fuels - Gaseous (All fuel types in Table C-1) | 3.2 × 10−03 | 6.3 × 10−04 |
| Biomass Fuels - Liquid (All fuel types in Table C-1) | 1.1 × 10−03 | 1.1 × 10−04 |
Note: Those employing this table are assumed to fall under the IPCC definitions of the “Energy Industry” or “Manufacturing Industries and Construction”. In all fuels except for coal the values for these two categories are identical. For coal combustion, those who fall within the IPCC “Energy Industry” category may employ a value of 1g of CH4/mmBtu.
Table F-1 to Subpart F of Part 98 - Slope and Overvoltage Coefficients for the Calculation of PFC Emissions From Aluminum Production
40:23.0.1.1.3.6.1.10.20 :
Table F-1 to Subpart F of Part 98 - Slope and Overvoltage Coefficients for the Calculation of PFC Emissions From Aluminum Production| Technology | CF4 slope coefficient [(kg CF4/metric ton Al)/(AE-Mins/cell-day)] |
CF4 overvoltage
coefficient [(kg CF4/metric ton Al)/(mV)] |
Weight fraction C2F6/CF4 [(kg C2F6/kg CF4)] |
|---|---|---|---|
| Center Worked Prebake (CWPB) | 0.143 | 1.16 | 0.121 |
| Side Worked Prebake (SWPB) | 0.272 | 3.65 | 0.252 |
| Vertical Stud Søderberg (VSS) | 0.092 | NA | 0.053 |
| Horizontal Stud Søderberg (HSS) | 0.099 | NA | 0.085 |
Table F-2 to Subpart F of Part 98 - Default Data Sources for Parameters Used for CO2 Emissions
40:23.0.1.1.3.6.1.10.21 :
Table F-2 to Subpart F of Part 98 - Default Data Sources for Parameters Used for CO2 Emissions| Parameter | Data source |
|---|---|
| CO2 Emissions from Prebake Cells (CWPB and SWPB) | |
| MP: metal production (metric tons Al) | Individual facility records. |
| NAC: net annual prebaked anode consumption per metric ton Al (metric tons C/metric tons Al) | Individual facility records. |
| Sa: sulfur content in baked anode (percent weight) | 2.0. |
| Asha: ash content in baked anode (percent weight) | 0.4. |
| CO2 Emissions From Pitch Volatiles Combustion (CWPB and SWPB) | |
| MP: metal production (metric tons Al) | Individual facility records. |
| PC: annual paste consumption (metric ton/metric ton Al) | Individual facility records. |
| CSM: annual emissions of cyclohexane soluble matter (kg/metric ton Al) | HSS: 4.0. VSS: 0.5. |
| BC: binder content of paste (percent weight) | Dry Paste: 24. Wet Paste: 27. |
| Sp: sulfur content of pitch (percent weight) | 0.6. |
| Ashp: ash content of pitch (percent weight) | 0.2. |
| Hp: hydrogen content of pitch (percent weight) | 3.3. |
| Sc: sulfur content in calcined coke (percent weight) | 1.9. |
| Ashc: ash content in calcined coke (percent weight) | 0.2. |
| CD: carbon in skimmed dust from Søderberg cells (metric ton C/metric ton Al) | 0.01. |
| CO2 Emissions from Pitch Volatiles Combustion (VSS and HSS) | |
| GA: initial weight of green anodes (metric tons) | Individual facility records. |
| Hw: annual hydrogen content in green anodes (metric tons) | 0.005 × GA. |
| BA: annual baked anode production (metric tons) | Individual facility records. |
| WT: annual waste tar collected (metric tons) | (a) 0.005 × GA. |
| (a) Riedhammer furnaces | (b) insignificant. |
| (b) all other furnaces | |
| CO2 Emissions From Bake Furnace Packing Materials (CWPB and SWPB) | |
| PCC: annual packing coke consumption (metric tons/metric ton baked anode) | 0.015. |
| BA: annual baked anode production (metric tons) | Individual facility records. |
| Spc: sulfur content in packing coke (percent weight) | 2. |
| Ashpc: ash content in packing coke (percent weight) | 2.5. |
Table I-1 to Subpart I of Part 98 - Default Emission Factors for Threshold Applicability Determination
40:23.0.1.1.3.9.1.10.22 :
Table I-1 to Subpart I of Part 98 - Default Emission Factors for Threshold Applicability Determination| Product type | Emission factors EFi | |||||
|---|---|---|---|---|---|---|
| CF4 | C2F6 | CHF3 | C3F8 | NF3 | SF6 | |
| Semiconductors (kg/m 2) | 0.90 | 1.00 | 0.04 | 0.05 | 0.04 | 0.20 |
| LCD (g/m 2) | 0.50 | NA | NA | NA | 0.90 | 4.00 |
| MEMS (kg/m 2) | NA | NA | NA | NA | NA | 1.02 |
Notes: NA denotes not applicable based on currently available information.
Table I-2 to Subpart I of Part 98 - Examples of Fluorinated GHGs Used by the Electronics Industry
40:23.0.1.1.3.9.1.10.23 :
Table I-2 to Subpart I of Part 98 - Examples of Fluorinated GHGs Used by the Electronics Industry| Product type | Fluorinated GHGs and fluorinated heat transfer fluids used during manufacture |
|---|---|
| Electronics | CF4, C2F6, C3F8, c-C4F8, c-C4F8O, C4F6, C5F8, CHF3, CH2F2, NF3, SF6, and fluorinated HTFs (CF3-(O-CF(CF3)-CF2)n-(O-CF2)m-O-CF3, CnF2n + 2, CnF2n + 1(O)CmF2m + 1, CnF2.O, (CnF2n + 1)3N). |
Table I-3 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for Semiconductor Manufacturing for 150 mm and 200 mm Wafer Sizes
40:23.0.1.1.3.9.1.10.24 :
Table I-3 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for Semiconductor Manufacturing for 150 mm and 200 mm Wafer SizesTable I-3 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for Semiconductor Manufacturing for 150 mm and 200 mm Wafer Sizes
| Process type/sub-type | Process gas i | ||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| CF4 | C2F6 | CHF3 | CH2F2 | C2HF5 | CH3F | C3F8 | C4F8 | NF3 | SF6 | C4F6 | C5F8 | C4F8O | |
| Etching/Wafer Cleaning | |||||||||||||
| 1-Ui | 0.81 | 0.72 | 0.51 | 0.13 | 0.064 | 0.70 | NA | 0.14 | 0.19 | 0.55 | 0.17 | 0.072 | NA |
| BCF4 | NA | 0.10 | 0.085 | 0.079 | 0.077 | NA | NA | 0.11 | 0.0040 | 0.13 | 0.13 | NA | NA |
| BC2F6 | 0.046 | NA | 0.030 | 0.025 | 0.024 | 0.0034 | NA | 0.037 | 0.025 | 0.11 | 0.11 | 0.014 | NA |
| BC4F6 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| BC4F8 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| BC3F8 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| BC5F8 | 0.0012 | NA | 0.0012 | NA | NA | NA | NA | 0.0086 | NA | NA | NA | NA | NA |
| BCHF3 | 0.10 | 0.047 | NA | 0.049 | NA | NA | NA | 0.040 | NA | 0.0012 | 0.066 | 0.0039 | NA |
| Chamber Cleaning | |||||||||||||
| In situ plasma cleaning: | |||||||||||||
| 1-Ui | 0.92 | 0.55 | NA | NA | NA | NA | 0.40 | 0.10 | 0.18 | NA | NA | NA | 0.14 |
| BCF4 | NA | 0.21 | NA | NA | NA | NA | 0.20 | 0.11 | 0.050 | NA | NA | NA | 0.13 |
| BC2F6 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | 0.045 |
| BC3F8 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| Remote plasma cleaning: | |||||||||||||
| 1-Ui | NA | NA | NA | NA | NA | NA | NA | NA | 0.017 | NA | NA | NA | NA |
| BCF4 | NA | NA | NA | NA | NA | NA | NA | NA | 0.015 | NA | NA | NA | NA |
| BC2F6 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| BC3F8 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| In situ thermal cleaning: | |||||||||||||
| 1-Ui | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| BCF4 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| BC2F6 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| BC3F8 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
Notes: NA = Not applicable; i.e., there are no applicable default emission factor measurements for this gas. This does not necessarily imply that a particular gas is not used in or emitted from a particular process sub-type or process type.
Table I-4 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for Semiconductor Manufacturing for 300 mm and 450 mm Wafer Size
40:23.0.1.1.3.9.1.10.25 :
Table I-4 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for Semiconductor Manufacturing for 300 mm and 450 mm Wafer SizeTable I-4 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for Semiconductor Manufacturing for 300 mm and 450 mm Wafer Size
| Process type/sub-type | Process gas i | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| CF4 | C2F6 | CHF3 | CH2F2 | CH3F | C3F8 | C4F8 | NF3 | SF6 | C4F6 | C5F8 | C4F8O | |
| Etching/Wafer Cleaning | ||||||||||||
| 1-Ui | 0.65 | 0.80 | 0.42 | 0.21 | 0.33 | 0.30 | 0.18 | 0.15 | 0.32 | 0.15 | 0.10 | NA |
| BCF4 | NA | 0.21 | 0.095 | 0.049 | 0.045 | 0.21 | 0.045 | 0.046 | 0.040 | 0.059 | 0.11 | NA |
| BC2F6 | 0.079 | NA | 0.064 | 0.052 | 0.00087 | 0.18 | 0.031 | 0.045 | 0.044 | 0.074 | 0.083 | NA |
| BC4F6 | NA | NA | 0.00010 | NA | NA | NA | 0.018 | NA | NA | NA | NA | NA |
| BC4F8 | 0.00063 | NA | 0.00080 | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| BC3F8 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | 0.00012 | NA |
| BCHF3 | 0.011 | NA | NA | 0.050 | 0.0057 | 0.012 | 0.027 | 0.025 | 0.0037 | 0.019 | 0.0069 | NA |
| BCH2F2 | NA | NA | 0.0036 | NA | 0.0023 | NA | 0.0015 | 0.00086 | 0.000029 | 0.000030 | NA | NA |
| BCH3F | 0.0080 | NA | 0.0080 | 0.0080 | NA | 0.00073 | NA | 0.0080 | NA | NA | NA | NA |
| Chamber Cleaning | ||||||||||||
| In situ plasma cleaning: | ||||||||||||
| 1-Ui | NA | NA | NA | NA | NA | NA | NA | 0.23 | NA | NA | NA | NA |
| BCF4 | NA | NA | NA | NA | NA | NA | NA | 0.037 | NA | NA | NA | NA |
| BC2F6 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| BC3F8 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| Remote Plasma Cleaning: | ||||||||||||
| 1-Ui | NA | NA | NA | NA | NA | 0.063 | NA | 0.017 | NA | NA | NA | NA |
| BCF4 | NA | NA | NA | NA | NA | NA | NA | 0.075 | NA | NA | NA | NA |
| BC2F6 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| BC3F8 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| In Situ Thermal Cleaning: | ||||||||||||
| 1-Ui | NA | NA | NA | NA | NA | NA | NA | 0.28 | NA | NA | NA | NA |
| BCF4 | NA | NA | NA | NA | NA | NA | NA | 0.010 | NA | NA | NA | NA |
| BC2F6 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
| BC3F8 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA |
Notes: NA = Not applicable; i.e., there are no applicable default emission factor measurements for this gas. This does not necessarily imply that a particular gas is not used in or emitted from a particular process sub-type or process type.
Table I-5 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for MEMS Manufacturing
40:23.0.1.1.3.9.1.10.26 :
Table I-5 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for MEMS Manufacturing| Process type factors | Process gas i | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| CF4 | C2F6 | CHF3 | CH2F2 | C3F8 | c− C4F8 | NF3 Remote |
NF3 | SF6 | C4F6a | C5F8a | C4F8Oa | |
| Etch 1-Ui | 0.7 | 10.4 | 10.4 | 10.06 | NA | 10.2 | NA | 0.2 | 0.2 | 0.1 | 0.2 | NA |
| Etch BCF4 | NA | 10.4 | 10.07 | 10.08 | NA | 0.2 | NA | NA | NA | 10.3 | 0.2 | NA |
| Etch BC2F6 | NA | NA | NA | NA | NA | 0.2 | NA | NA | NA | 10.2 | 0.2 | NA |
| CVD Chamber Cleaning 1-Ui | 0.9 | 0.6 | NA | NA | 0.4 | 0.1 | 0.02 | 0.2 | NA | NA | 0.1 | 0.1 |
| CVD Chamber Cleaning BCF4 | NA | 0.1 | NA | NA | 0.1 | 0.1 | 20.02 | 20.1 | NA | NA | 0.1 | 0.1 |
| CVD Chamber Cleaning BC3F8 | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | NA | 0.4 |
Notes: NA = Not applicable; i.e., there are no applicable default emission factor measurements for this gas. This does not necessarily imply that a particular gas is not used in or emitted from a particular process sub-type or process type.
1 Estimate includes multi-gas etch processes.
2 Estimate reflects presence of low-k, carbide and multi-gas etch processes that may contain a C-containing fluorinated GHG additive.
Table I-6 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for LCD Manufacturing
40:23.0.1.1.3.9.1.10.27 :
Table I-6 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for LCD Manufacturing| Process type factors | Process gas i | ||||||||
|---|---|---|---|---|---|---|---|---|---|
| CF4 | C2F6 | CHF3 | CH2F2 | C3F8 | c− C4F8 | NF3 Remote |
NF3 | SF6 | |
| Etch 1-Ui | 0.6 | NA | 0.2 | NA | NA | 0.1 | NA | NA | 0.3 |
| Etch BCF4 | NA | NA | 0.07 | NA | NA | 0.009 | NA | NA | NA |
| Etch BCHF3 | NA | NA | NA | NA | NA | 0.02 | NA | NA | NA |
| Etch BC2F4 | NA | NA | 0.05 | NA | NA | NA | NA | NA | NA |
| CVD Chamber Cleaning 1-Ui | NA | NA | NA | NA | NA | NA | 0.03 | 0.3 | 0.9 |
Notes: NA = Not applicable; i.e., there are no applicable default emission factor measurements for this gas. This does not necessarily imply that a particular gas is not used in or emitted from a particular process sub-type or process type.
Table I-7 To Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for PV Manufacturing
40:23.0.1.1.3.9.1.10.28 :
Table I-7 To Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for PV Manufacturing| Process type factors | Process gas i | ||||||||
|---|---|---|---|---|---|---|---|---|---|
| CF4 | C2F6 | CHF3 | CH2F2 | C3F8 | c− C4F8 | NF3 Remote |
NF3 | SF6 | |
| Etch 1-Ui | 0.7 | 0.4 | 0.4 | NA | NA | 0.2 | NA | NA | 0.4 |
| Etch BCF4 | NA | 0.2 | NA | NA | NA | 0.1 | NA | NA | NA |
| Etch BC2F6 | NA | NA | NA | NA | NA | 0.1 | NA | NA | NA |
| CVD Chamber Cleaning 1-Ui | NA | 0.6 | NA | NA | 0.1 | 0.1 | NA | 0.3 | 0.4 |
| CVD Chamber Cleaning BCF4 | NA | 0.2 | NA | NA | 0.2 | 0.1 | NA | NA | NA |
Notes: NA = Not applicable; i.e., there are no applicable default emission factor measurements for this gas. This does not necessarily imply that a particular gas is not used in or emitted from a particular process sub-type or process type.
Table I-8 to Subpart I of Part 98 - Default Emission Factors (1-UN2O,j) for N2O Utilization (UN2O,j)
40:23.0.1.1.3.9.1.10.29 :
Table I-8 to Subpart I of Part 98 - Default Emission Factors (1-UN2O,j) for N2O Utilization (UN2O,j)| Process type factors | N2O |
|---|---|
| CVD 1-Ui | 0.8 |
| Other Manufacturing Process 1-Ui | 1.0 |
Table I-9 to Subpart I of Part 98 - Methods and Procedures for Conducting Emissions Test for Stack Systems
40:23.0.1.1.3.9.1.10.30 :
Table I-9 to Subpart I of Part 98 - Methods and Procedures for Conducting Emissions Test for Stack Systems
[78 FR 68227, Nov.
13, 2013]Table I-10 to Subpart I of Part 98 - Maximum Field Detection Limits Applicable to Fluorinated GHG Concentration Measurements for Stack Systems
40:23.0.1.1.3.9.1.10.31 :
Table I-10 to Subpart I of Part 98 - Maximum Field Detection Limits Applicable to Fluorinated GHG Concentration Measurements for Stack Systems| Fluorinated GHG Analyte | Maximum field detection limit (ppbv) |
|---|---|
| CF4 | 20 |
| C2F6 | 20 |
| C3F8 | 20 |
| C4F6 | 20 |
| C5F8 | 20 |
| c-C4F8 | 20 |
| CH2F2 | 40 |
| CH3F | 40 |
| CHF3 | 20 |
| NF3 | 20 |
| SF6 | 4 |
| Other fully fluorinated GHGs | 20 |
| Other fluorinated GHGs | 40 |
ppbv - Parts per billion by volume.
Table I-11 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for Semiconductor Manufacturing for Use With the Stack Test Method (150 mm and 200 mm Wafers)
40:23.0.1.1.3.9.1.10.32 :
Table I-11 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for Semiconductor Manufacturing for Use With the Stack Test Method (150 mm and 200 mm Wafers)
[78 FR 68229, Nov.
13, 2013]Table I-12 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for Semiconductor Manufacturing for Use With the Stack Test Method (300 mm and 450 mm Wafers)
40:23.0.1.1.3.9.1.10.33 :
Table I-12 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for Semiconductor Manufacturing for Use With the Stack Test Method (300 mm and 450 mm Wafers)
[78 FR 68230, Nov.
13, 2013]Table I-13 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for LCD Manufacturing for Use With the Stack Test Method
40:23.0.1.1.3.9.1.10.34 :
Table I-13 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for LCD Manufacturing for Use With the Stack Test Method
[78 FR 68231, Nov. 13, 2013]Table I-14 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for PV Manufacturing for Use With the Stack Test Method
40:23.0.1.1.3.9.1.10.35 :
Table I-14 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for PV Manufacturing for Use With the Stack Test Method
[78 FR 68232, Nov. 13, 2013]Table I-15 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for MEMS Manufacturing for Use With the Stack Test Method
40:23.0.1.1.3.9.1.10.36 :
Table I-15 to Subpart I of Part 98 - Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for MEMS Manufacturing for Use With the Stack Test Method
[78 FR 68233, Nov. 13, 2013]Table I-16 to Subpart I of Part 98 - Default Emission Destruction or Removal Efficiency (DRE) Factors for Electronics Manufacturing
40:23.0.1.1.3.9.1.10.37 :
Table I-16 to Subpart I of Part 98 - Default Emission Destruction or Removal Efficiency (DRE) Factors for Electronics Manufacturing| Manufacturing type/process type/gas | Default DRE (percent) |
|---|---|
| MEMS, LCDs, and PV Manufacturing | 60 |
| Semiconductor Manufacturing: | |
| Plasma Etch/Wafer Clean Process Type: | |
| CF4 | 75 |
| CH3F | 97 |
| CHF3 | 97 |
| CH2F2 | 97 |
| C2F6 | 97 |
| C3F8 | 97 |
| C4F6 | 97 |
| C4F8 | 97 |
| C5F8 | 97 |
| SF6 | 97 |
| NF3 | 96 |
| All other carbon-based plasma etch/wafer clean fluorinated GHG | 60 |
| Chamber Clean Process Type: | |
| NF3 | 88 |
| All other chamber clean fluorinated GHG | 60 |
| N2O Processes: | |
| CVD and all other N2O-using processes | 60 |
Table I-17 to Subpart I of Part 98 - Expected and Possible By-Products for Electronics Manufacturinglg
40:23.0.1.1.3.9.1.10.38 :
Table I-17 to Subpart I of Part 98 - Expected and Possible By-Products for Electronics Manufacturinglg| For each stack system for which you use the “stack test method” to calculate annual emissions, you must measure the following: | If emissions are detected
intermittently, use the following procedures: |
If emissions are not
detected, use the following procedures: |
|---|---|---|
| Expected
By-products: CF4 C2F6 CHF3 CH2F2 CH3F |
Use the measured concentration for “Xksm” in Equation I-18 when available and use one-half of the field detection limit you determined for the fluorinated GHG according to § 98.94(j)(2) for the value of “Xksm” when the fluorinated GHG is not detected | Use one-half of the field detection limit you determined for the fluorinated GHG according to § 98.94(j)(2) for the value of “Xksm” in Equation I-18. |
| Possible
By-products: C3F8 C4F6 c-C4F8 C5F8 |
Use the measured concentration for “Xksm” in Equation I-18 when available and use one-half of the field detection limit you determined for the fluorinated GHG according to § 98.94(j)(2) for the value of “Xksm” when the fluorinated GHG is not detected | Assume zero emissions for that fluorinated GHG for the tested stack system. |
Appendix A to Subpart I of Part 98 - Alternative Procedures for Measuring Point-of-Use Abatement Device Destruction or Removal Efficiency
40:23.0.1.1.3.9.1.10.39 : Appendix A
Appendix A to Subpart I of Part 98 - Alternative Procedures for Measuring Point-of-Use Abatement Device Destruction or Removal EfficiencyIf you are measuring destruction or removal efficiency of a point-of-use abatement device according to EPA 430-R-10-003 (incorporated by reference, see § 98.7) as specified in § 98.94(f)(4), you may follow the alternative procedures specified in paragraphs (a) through (c) of this appendix.
(a) In place of the Quadrupole Mass Spectrometry protocol requirements specified in section 2.2.4 of EPA 430-R-10-003 (incorporated by reference, see § 98.7), you must conduct mass spectrometry testing in accordance with the provisions in paragraph (a)(1) through (a)(15) of this appendix.
(1) Detection limits. The mass spectrometer chosen for this application must have the necessary sensitivity to detect the selected effluent species at or below the maximum field detection limits specified in Table 3 of section 2.2.7 of EPA 430-R-10-003 (incorporated by reference, see § 98.7).
(2) Sampling location. The sample at the inlet of the point-of-use abatement device must be taken downstream of the process tool and pump package. The sample exhaust must be vented back into the corrosive house ventilation system at a point downstream of the sample inlet location.
(3) Sampling conditions. For etch processes, destruction or removal efficiencies must be determined while etching a substrate (product, dummy, or test). For chemical vapor deposition processes, destruction or removal efficiencies must be determined during a chamber clean after deposition (destruction or removal efficiencies must not be determined in a clean chamber). All sampling must be performed non-intrusively during wafer processing. Samples must be drawn through the mass spectrometer source by an external sample pump. Because of the volatility, vapor pressure, stability and inertness of CF4, C2F6, C3F8, CHF3, NF3, and SF6, the sample lines do not need to be heated.
(4) Mass spectrometer parameters. The specific mass spectrometer operating conditions such as electron energy, secondary electron multiplier voltage, emission current, and ion focusing voltage must be selected according to the specifications provided by the mass spectrometer manufacturer, the mass spectrometer system manual, basic mass spectrometer textbook, or other such sources. The mass spectrometer responses to each of the target analytes must all be calibrated under the same mass spectrometer operating conditions.
(5) Flow rates. A sample flow rate of 0.5-1.5 standard liters per minute (slm) must be drawn from the process tool exhaust stream under study.
(6) Sample frequency. The mass spectrometer sampling frequency for etch processes must be in the range of 0.5 to 1 cycles per second, and for chemical vapor deposition processes must be in the range of 0.25 to 0.5 cycles per second. As an alternative you may use the sampling frequencies specified in section 2.2.4 of EPA 430-R-10-003 (incorporated by reference, see § 98.7).
(7) Dynamic dilution calibration parameters. The quadrupole mass spectrometer must be calibrated for both mass location and response to analytes. A dynamic dilution calibration system may be used to perform both types of mass spectrometer system calibrations using two mass flow controllers. Use one mass flow controller to regulate the flow rate of the standard component used to calibrate the system and the second mass flow controller to regulate the amount of diluent gas used to mix with the standard to generate the calibration curve for each compound of interest. The mass flow controller must be calibrated using the single component gas being used with them, for example, nitrogen (N2) for the diluent. A mass flow controller used with calibration mixtures must be calibrated with the calibration mixture balance gas (for example, N2 or He) if the analyte components are 2 percent or less of the volume of the sample. All calibration mixtures must be National Institute of Standards and Technology Traceable gases or equivalent. They must be calibrated over their range of use and must be operated in their experimentally determined dynamic linear range. If compressed gas standards cannot be brought into the fab, metered gas flows of target compounds into the process chamber, under no thermal or plasma conditions and with no wafer(s) present, and with no process emissions from other tools contributing to the sample location, must then be performed throughout the appropriate concentration ranges to derive calibration curves for the subsequent destruction or removal efficiency tests.
(8) Mass location calibration. A mixture containing 1 percent He, Ar, Kr, and Xe in a balance gas of nitrogen must be used to assure the alignment of the quadrupole mass filter (see EPA Method 205 at 40 CFR part 51, appendix M as reference). The mass spectrometer must be chosen so that the mass range is sufficient to detect the predominant peaks of the components under study.
(9) Quadrupole mass spectrometer response calibration. A calibration curve must be generated for each compound of interest.
(10) Calibration frequency. The mass spectrometer must be calibrated at the start of testing a given process. The calibration must be checked at the end of testing.
(11) Calibration range. The mass spectrometer must be calibrated over the expected concentration range of analytes using a minimum of five concentrations including a zero. The zero point is defined as diluent containing no added analyte.
(12) Operating procedures. You must follow the operating procedures specified in paragraphs (a)(12)(i) through (v) of this appendix.
(i) You must perform a qualitative mass calibration by running a standard (or by flowing chamber gases under non-process conditions) containing stable components such as Ar, Kr, and Xe that provide predominant signals at m/e values distributed throughout the mass range to be used. You must adjust the quadrupole mass filter as needed to align with the inert gas fragments.
(ii) You must quantitatively calibrate the quadrupole mass spectrometer for each analyte of interest. The analyte concentrations during calibration must include the expected concentrations in the process effluent. The calibration must be performed under the same operating conditions, such as inlet pressure, as when sampling process exhaust. If the calibration inlet pressure differs from the sampling inlet pressure then the relationship between inlet pressure and quadrupole mass spectrometer signal response must be empirically determined and applied to correct for any differences between calibration and process emissions monitoring data.
(iii) To determine the response time of the instrument to changes in a process, a process gas such as C2F6 must be turned on at the process tool for a fixed period of time (for example, 20 seconds), after which the gas is shut off. The sample flow rate through the system must be adjusted so that the signal increases to a constant concentration within a few seconds and decreases to background levels also within a few seconds.
(iv) You must sample the process effluent through the quadrupole mass spectrometer and acquire data for the required amount of time to track the process, as determined in paragraph (a)(12)(iii) of this appendix. You must set the sample frequency to monitor the changes in the process as specified in paragraph (a)(6) of this appendix. You must repeat this for at least five substrates on the same process and calculate the average and standard deviation of the analyte concentration.
(v) You must repeat the quantitative calibration at the conclusion of sampling to identify any drifts in quadrupole mass spectrometer sensitivity. If drift is observed, you must use an internal standard to correct for changes in sensitivity.
(13) Sample analysis. To determine the concentration of a specific component in the sample, you must divide the ion intensity of the sample response by the calibrated response factor for each component.
(14) Deconvolution of interfering peaks. The effects of interfering peaks must be deconvoluted from the mass spectra for each target analyte.
(15) Calculations. Plot ion intensity versus analyte concentration for a given compound obtained when calibrating the analytical system. Determine the slope and intercept for each calibrated species to obtain response factors with which to calculate concentrations in the sample. For an acceptable calibration, the R 2 value of the calibration curve must be at least 0.98.
(b) In place of the Fourier Transform Infrared Spectroscopy protocol requirements specified in section 2.2.4 of EPA 430-R-10-003 (incorporated by reference, see § 98.7), you may conduct Fourier Transform Infrared Spectroscopy testing in accordance with the provisions in paragraph (b)(1) through (17) of this appendix, including the laboratory study phase described in paragraphs (b)(1) through (7), and the field study phase described in paragraphs (b)(8) through (17) of this appendix.
(1) Conformance with provisions associated with the Calibration Transfer Standard. This procedure calls for the use of a calibration transfer standard in a number of instances. The use of a calibration transfer standard is necessary to validate optical pathlength and detector response for spectrometers where cell temperature, cell pressure, and cell optical pathlength are potentially variable. For fixed pathlength spectrometers capable of controlling cell temperature and pressure to within ±10 percent of a desired set point, the use of a calibration transfer standard, as described in paragraphs (b)(2) to (17) this appendix is not required.
(2) Defining spectroscopic conditions. Define a set of spectroscopic conditions under which the field studies and subsequent field applications are to be carried out. These include the minimum instrumental line-width, spectrometer wave number range, sample gas temperature, sample gas pressure, absorption pathlength, maximum sampling system volume (including the absorption cell), minimum sample flow rate, and maximum allowable time between consecutive infrared analyses of the effluent.
(3) Criteria for reference spectral libraries. On the basis of previous emissions test results and/or process knowledge (including the documentation of results of any initial and subsequent tests, and the final reports required in § 98.97(d)(4)(i)), estimate the maximum concentrations of all of the analytes in the effluent and their minimum concentrations of interest (those concentrations below which the measurement of the compounds is of no importance to the analysis). Values between the maximum expected concentration and the minimum concentration of interest are referred to below as the “expected concentration range.” A minimum of three reference spectra is sufficient for a small expected concentration range (e.g., a difference of 30 percent of the range between the low and high ends of the range), but a minimum of four spectra are needed where the range is greater, especially for concentration ranges that may differ by orders of magnitude. If the measurement method is not linear then multiple linear ranges may be necessary. If this approach is adopted, then linear range must be demonstrated to pass the required quality control. When the set of spectra is ordered according to absorbance, the absorbance levels of adjacent reference spectra should not differ by more than a factor of six. Reference spectra for each analyte should be available at absorbance levels that bracket the analyte's expected concentration range; minimally, the spectrum whose absorbance exceeds each analyte's expected maximum concentration or is within 30 percent of it must be available. The reference spectra must be collected at or near the same temperature and pressure at which the sample is to be analyzed under. The gas sample pressure and temperature must be continuously monitored during field testing and you must correct for differences in temperature and pressure between the sample and reference spectra. Differences between the sample and reference spectra conditions must not exceed 50 percent for pressure and 40 °C for temperature.
(4) Spectra without reference libraries. If reference spectral libraries meeting the criteria in paragraph (b)(3) of this appendix do not exist for all the analytes and interferants or cannot be accurately generated from existing libraries exhibiting lower minimum instrumental line-width values than those proposed for the testing, prepare the required spectra according to the procedures specified in paragraphs (b)(4)(i) and (ii) of this appendix.
(i) Reference spectra at the same absorbance level (to within 10 percent) of independently prepared samples must be recorded. The reference samples must be prepared from neat forms of the analyte or from gas standards of the highest quality commonly available from commercial sources. Either barometric or volumetric methods may be used to dilute the reference samples to the required concentrations, and the equipment used must be independently calibrated to ensure suitable accuracy. Dynamic and static reference sample preparation methods are acceptable, but dynamic preparations must be used for reactive analytes. Any well characterized absorption pathlength may be employed in recording reference spectra, but the temperature and pressure of the reference samples should match as closely as possible those of the proposed spectroscopic conditions.
(ii) If a mercury cadmium telluride or other potentially non-linear detector (i.e., a detector whose response vs. total infrared power is not a linear function over the range of responses employed) is used for recording the reference spectra, you must correct for the effects of this type of response on the resulting concentration values. As needed, spectra of a calibration transfer standard must be recorded with the laboratory spectrometer system to verify the absorption pathlength and other aspects of the system performance. All reference spectral data must be recorded in interferometric form and stored digitally.
(5) Sampling system preparation. Construct a sampling system suitable for delivering the proposed sample flow rate from the effluent source to the infrared absorption cell. For the compounds of interest, the surfaces of the system exposed to the effluent stream may need to be stainless steel or Teflon; because of the potential for generation of inorganic automated gases, glass surfaces within the sampling system and absorption cell may need to be Teflon-coated. The sampling system should be able to deliver a volume of sample that results in a necessary response time.
(6) Preliminary analytical routines. For the proposed absorption pathlength to be used in actual emissions testing, you must prepare an analysis method containing of all the effluent compounds at their expected maximum concentrations plus the field calibration transfer standard compound at 20 percent of its full concentration as needed.
(7) Documentation. The laboratory techniques used to generate reference spectra and to convert sample spectral information to compound concentrations must be documented. The required level of detail for the documentation is that which allows an independent analyst to reproduce the results from the documentation and the stored interferometric data.
(8) Spectroscopic system performance. The performance of the proposed spectroscopic system, sampling system, and analytical method must be rigorously examined during and after a field study. Several iterations of the analysis method may need to be applied depending on observed concentrations, absorbance intensities, and interferences. During the field study, all the sampling and analytical procedures envisioned for future field applications must be documented. Additional procedures not required during routine field applications, notably dynamic spiking studies of the analyte gases, may be performed during the field study. These additional procedures need to be performed only once if the results are acceptable and if the effluent sources in future field applications prove suitably similar to those chosen for the field study. If changes in the effluent sources in future applications are noted and require substantial changes to the analytical equipment and/or conditions, a separate field study must be performed for the new set of effluent source conditions. All data recorded during the study must be retained and documented, and all spectral information must be permanently stored in interferometric form.
(9) System installation. The spectroscopic and sampling sub-systems must be assembled and installed according to the manufacturers' recommendations. For the field study, the length of the sample lines used must not be less than the maximum length envisioned for future field applications. The system must be given sufficient time to stabilize before testing begins.
(10) Pre-Test calibration. Record a suitable background spectrum using pure nitrogen gas; alternatively, if the analytes of interest are in a sample matrix consistent with ambient air, it is beneficial to use an ambient air background to control interferences from water and carbon dioxide. For variable pathlength Fourier Transform Infrared Spectrometers, introduce a sample of the calibration transfer standard gas directly into the absorption cell at the expected sample pressure and record its absorbance spectrum (the “initial field calibration transfer standard spectrum”). Compare it to the laboratory calibration transfer standard spectra to determine the effective absorption pathlength. If possible, record spectra of field calibration gas standards (single component standards of the analyte compounds) and determine their concentrations using the reference spectra and analytical routines developed in paragraphs (b)(2) through (7) of this appendix; these spectra may be used instead of the reference spectra in actual concentration and uncertainty calculations.
(11) Deriving the calibration transfer standard gas from tool chamber gases. The calibration transfer standard gas may be derived by flowing appropriate semiconductor tool chamber gases under non-process conditions (no thermal or plasma conditions and with no wafer(s) present) if compressed gas standards cannot be brought on-site.
(12) Reactivity and response time checks. While sampling ambient air and continuously recording absorbance spectra, suddenly replace the ambient air flow with calibration transfer standard gas introduced as close as possible to the probe tip. Examine the subsequent spectra to determine whether the flow rate and sample volume allow the system to respond quickly enough to changes in the sampled gas. Should a corrosive or reactive gas be of interest in the sample matrix it would be beneficial to determine the reactivity in a similar fashion, if practical. Examine the subsequent spectra to ensure that the reactivities of the analytes with the exposed surfaces of the sampling system do not limit the time response of the analytical system. If a pressure correction routine is not automated, monitor the absorption cell temperature and pressure; verify that the (absolute) pressure remains within 2 percent of the pressure specified in the proposed system conditions.
(13) Analyte spiking. Analyte spiking must be performed. While sampling actual source effluent, introduce a known flow rate of calibration transfer standard gas into the sample stream as close as possible to the probe tip or between the probe and extraction line. Measure and monitor the total sample flow rate, and adjust the spike flow rate until it represents 10 percent to 20 percent of the total flow rate. After waiting until at least four absorption cell volumes have been sampled, record four spectra of the spiked effluent, terminate the calibration transfer standard spike flow, pause until at least four cell volumes are sampled, and then record four (unspiked) spectra. Repeat this process until 12 spiked and 12 unspiked spectra have been obtained. If a pressure correction routine is not automated, monitor the absorption cell temperature and pressure; verify that the pressure remains within 2 percent of the pressure specified in the proposed system conditions. Calculate the expected calibration transfer standard compound concentrations in the spectra and compare them to the values observed in the spectrum. This procedure is best performed using a spectroscopic tracer to calculate dilution (as opposed to measured flow rates) of the injected calibration transfer standard (or analyte). The spectroscopic tracer should be a component not in the gas matrix that is easily detectable and maintains a linear absorbance over a large concentration range. Repeat this spiking process with all effluent compounds that are potentially reactive with either the sampling system components or with other effluent compounds. The gas spike is delivered by a mass flow controller, and the expected concentration of analyte of interest (AOITheoretical) is calculated as follows:
Where:
AOITheoretical = Theoretical analyte of interest concentration
(parts per million (ppm)). Tracersample = Tracer concentration
(ppm) as seen by the Fourier Transform Infrared Spectrometer during
spiking. Tracercylinder = The concentration (ppm) of tracer
recorded during direct injection of the cylinder to the Fourier
Transform Infrared Spectrometer cell. AOIcylinder = The
supplier-certified concentration (ppm) of the analyte of interest
gas standard. AOInative = The native AOI concentration (ppm) of the
effluent during stable conditions.
(14) Post-test calibration. At the end of a sampling run and at the end of the field study, record the spectrum of the calibration transfer standard gas. The resulting “final field calibration transfer standard spectrum” must be compared to the initial field calibration transfer standard spectrum to verify suitable stability of the spectroscopic system throughout the course of the field study.
(15) Amendment of analytical routines. The presence of unanticipated interferant compounds and/or the observation of compounds at concentrations outside their expected concentration ranges may necessitate the repetition of portions of the procedures in paragraphs (b)(2) through (14) of this appendix. Such amendments are allowable before final analysis of the data, but must be represented in the documentation required in paragraph (b)(16) of this appendix.
(16) Documentation. The sampling and spiking techniques used to generate the field study spectra and to convert sample spectral information to concentrations must be documented at a level of detail that allows an independent analyst to reproduce the results from the documentation and the stored interferometric data.
(17) Method application. When the required laboratory and field studies have been completed and if the results indicate a suitable degree of accuracy, the methods developed may be applied to practical field measurement tasks. During field applications, the procedures demonstrated in the field study specified in paragraphs (b)(8) through (16) of this appendix must be adhered to as closely as possible, with the following exceptions specified in paragraphs (b)(17)(i) through (iii) of this appendix:
(i) The sampling lines employed should be as short as practically possible and not longer than those used in the field study.
(ii) Analyte spiking and reactivity checks are required after the installation of or major repair to the sampling system or major change in sample matrix. In these cases, perform three spiked/unspiked samples with calibration transfer standard or a surrogate analyte on a daily basis if time permits and gas standards are easy to obtain and get on-site.
(iii) Sampling and other operational data must be recorded and documented as during the field study, but only the interferometric data needed to sufficiently reproduce actual test and spiking data must be stored permanently. The format of this data does not need to be interferograms but may be absorbance spectra or single beams.
(c) When using the flow and dilution measurement protocol specified in section 2.2.6 of EPA 430-R-10-003 (incorporated by reference, see § 98.7), you may determine point-of-use abatement device total volume flow with the modifications specified in paragraphs (c)(1) through (3) of this appendix.
(1) You may introduce the non-reactive, non-native gas used for determining total volume flow and dilution across the point-of-use abatement device at a location in the exhaust of the point-of-use abatement device. For abatement systems operating in a mode where specific F-GHG are not readily abated, you may introduce the non-reactive, non-native gas used for determining total volume flow and dilution across the point-of-use abatement device prior to the point-of-use abatement system; in this case, the tracer must be more difficult to destroy than the target compounds being measured based on the thermal stability of the tracer and target.
(2) You may select a location for downstream non-reactive, non-native gas analysis that complies with the requirements in this paragraph (c)(2) of this appendix. The sampling location should be traversed with the sampling probe measuring the non-reactive, non-native gas concentrations to ensure homogeneity of the non-reactive gas and point-of-use abatement device effluent (i.e., stratification test). To test for stratification, measure the non-reactive, non-native gas concentrations at three points on a line passing through the centroidal area. Space the three points at 16.7, 50.0, and 83.3 percent of the measurement line. Sample for a minimum of twice the system response time, determined according to paragraph (c)(3) of this appendix, at each traverse point. Calculate the individual point and mean non-reactive, non-native gas concentrations. If the non-reactive, non-native gas concentration at each traverse point differs from the mean concentration for all traverse points by no more than ±5.0 percent of the mean concentration, the gas stream is considered unstratified and you may collect samples from a single point that most closely matches the mean. If the 5.0 percent criterion is not met, but the concentration at each traverse point differs from the mean concentration for all traverse points by no more than ±10.0 percent of the mean, you may take samples from two points and use the average of the two measurements. Space the two points at 16.7, 50.0, or 83.3 percent of the measurement line. If the concentration at each traverse point differs from the mean concentration for all traverse points by more than ±10.0 percent of the mean but less than 20.0 percent, take samples from three points at 16.7, 50.0, and 83.3 percent of the measurement line and use the average of the three measurements. If the gas stream is found to be stratified because the 20.0 percent criterion for a 3-point test is not met, locate and sample the non-reactive, non-native gas from traverse points for the test in accordance with Sections 11.2 and 11.3 of EPA Method 1 in 40 CFR part 60, Appendix A-1. A minimum of 40 non-reactive gas concentration measurements will be collected at three to five different injected non-reactive gas flow rates for determination of point-of-use abatement device effluent flow. The total volume flow of the point-of-use abatement device exhaust will be calculated consistent with the EPA 430-R-10-003 (incorporated by reference, see § 98.7) Equations 1 through 7.
(3) You must determine the measurement system response time according to paragraphs (c)(3)(i) through (iii) of this appendix.
(i) Before sampling begins, introduce ambient air at the probe upstream of all sample condition components in system calibration mode. Record the time it takes for the measured concentration of a selected compound (for example, carbon dioxide) to reach steady state.
(ii) Introduce nitrogen in the system calibration mode and record the time required for the concentration of the selected compound to reach steady state.
(iii) Observe the time required to achieve 95 percent of a stable response for both nitrogen and ambient air. The longer interval is the measurement system response time.
[78 FR 68234, Nov. 13, 2013]Table K-1 to Subpart K of Part 98 - Electric Arc Furnace (EAF) CH4 Emission Factors
40:23.0.1.1.3.11.1.10.40 :
Table K-1 to Subpart K of Part 98 - Electric Arc Furnace (EAF) CH4 Emission Factors| Alloy product produced in EAF | CH4 emission
factor (kg CH4 per metric ton product) |
||
|---|---|---|---|
| EAF Operation | |||
| Batch-charging | Sprinkle-charging a | Sprinkle-charging and >750 °C b |
|
| Silicon metal | 1.5 | 1.2 | 0.7 |
| Ferrosilicon 90% | 1.4 | 1.1 | 0.6 |
| Ferrosilicon 75% | 1.3 | 1.0 | 0.5 |
| Ferrosilicon 65% | 1.3 | 1.0 | 0.5 |
a Sprinkle-charging is charging intermittently every minute.
b Temperature measured in off-gas channel downstream of the furnace hood.
Table L-1 to Subpart L of Part 98 - Ranges of Effective Destruction Efficiency
40:23.0.1.1.3.12.1.10.41 :
Table L-1 to Subpart L of Part 98 - Ranges of Effective Destruction Efficiency| Range of Reductions |
|---|
| ≥99%. |
| ≥95% to <99%. |
| ≥75% to <95%. |
| ≥0% to <75%. |
Appendix A to Subpart L of Part 98 - Mass Balance Method for Fluorinated Gas Production
40:23.0.1.1.3.12.1.10.42 : Appendix A
Appendix A to Subpart L of Part 98 - Mass Balance Method for Fluorinated Gas Production1. Mass Balance Method for § 98.123(b). [Note: Numbering convention here matches original rule text, 75 FR 74774, December 1, 2010.]
(b) Mass balance method. Before using the mass balance approach to estimate your fluorinated GHG emissions from a process, you must ensure that the process and the equipment and methods used to measure it meet either the error limits described in this paragraph and calculated under paragraph (b)(1) of this section or the requirements specified in paragraph § 98.124(b)(8). If you choose to calculate the error limits, you must estimate the absolute and relative errors associated with using the mass balance approach on that process using Equations L-1 through L-4 of this section in conjunction with Equations L-5 through L-10 of this section. You may use the mass-balance approach to estimate emissions from the process if this calculation results in an absolute error of less than or equal to 3,000 metric tons CO2e per year or a relative error of less than or equal to 30 percent of the estimated CO2e fluorinated GHG emissions. If you do not meet either of the error limits or the requirements of paragraph § 98.124(b)(8), you must use the emission factor approach detailed in paragraphs (c), (d), and (e) of this section to estimate emissions from the process.
(1) Error calculation. To perform the calculation, you must first calculate the absolute and relative errors associated with the quantities calculated using either Equations L-7 through L-10 of this section or Equation L-17 of this section. Alternatively, you may estimate these errors based on the variability of previous process measurements (e.g., the variability of measurements of stream concentrations), provided these measurements are representative of the current process and current measurement devices and techniques. Once errors have been calculated for the quantities in these equations, those errors must be used to calculate the errors in Equations L-6 and L-5 of this section. You may ignore the errors associated with Equations L-11, L-12, and L-13 of this section.
(i) Where the measured quantity is a mass, the error in the mass must be equated to the accuracy or precision (whichever is larger) of the flowmeter, scale, or combination of volumetric and density measurements at the flow rate or mass measured.
(ii) Where the measured quantity is a concentration of a stream component, the error of the concentration must be equated to the accuracy or precision (whichever is larger) with which you estimate the mean concentration of that stream component, accounting for the variability of the process, the frequency of the measurements, and the accuracy or precision (whichever is larger) of the analytical technique used to measure the concentration at the concentration measured. If the variability of process measurements is used to estimate the error, this variability shall be assumed to account both for the variability of the process and the precision of the analytical technique. Use standard statistical techniques such as the student's t distribution to estimate the error of the mean of the concentration measurements as a function of process variability and frequency of measurement.
(iii) Equation L-1 of this section provides the general formula for calculating the absolute errors of sums and differences where the sum, S, is the summation of variables measured, a, b, c, etc. (e.g., S = a + b + c):
Where:
eSA = Absolute error of the sum, expressed as one half of a 95
percent confidence interval. ea = Relative error of a, expressed as
one half of a 95 percent confidence interval. eb = Relative error
of b, expressed as one half of a 95 percent confidence interval. ec
= Relative error of c, expressed as one half of a 95 percent
confidence interval.
(iv) Equation L-2 of this section provides the general formula for calculating the relative errors of sums and differences:
Where:
eSR = Relative error of the sum, expressed as one half of a 95
percent confidence interval. eSA = Absolute error of the sum,
expressed as one half of a 95 percent confidence interval. a + b +
c = Sum of the variables measured.
(v) Equation L-3 of this section provides the general formula for calculating the absolute errors of products (e.g., flow rates of GHGs calculated as the product of the flow rate of the stream and the concentration of the GHG in the stream), where the product, P, is the result of multiplying the variables measured, a, b, c, etc. (e.g., P = a*b*c):
Where:
ePA = Absolute error of the product, expressed as one half of a 95
percent confidence interval. ea = Relative error of a, expressed as
one half of a 95 percent confidence interval. eb = Relative error
of b, expressed as one half of a 95 percent confidence interval. ec
= Relative error of c, expressed as one half of a 95 percent
confidence interval.
(vi) Equation L-4 of this section provides the general formula for calculating the relative errors of products:
Where:
ePR = Relative error of the product, expressed as one half of a 95
percent confidence interval. ePA = Absolute error of the product,
expressed as one half of a 95 percent confidence interval. a*b*c =
Product of the variables measured.
(vii) Calculate the absolute error of the emissions estimate in terms of CO2e by performing a preliminary estimate of the annual CO2e emissions of the process using the method in paragraph (b)(1)(viii) of this section. Multiply this result by the relative error calculated for the mass of fluorine emitted from the process in Equation L-6 of this section.
(viii) To estimate the annual CO2e emissions of the process for use in the error estimate, apply the methods set forth in paragraphs (b)(2) through (7) and (b)(9) through (16) of this section to representative process measurements. If these process measurements represent less than one year of typical process activity, adjust the estimated emissions to account for one year of typical process activity. To estimate the terms FERd, FEP, and FEBk for use in the error estimate for Equations L-11, L-12, and L-13 of this section, you must either use emission testing, monitoring of emitted streams, and/or engineering calculations or assessments, or in the alternative assume that all fluorine is emitted in the form of the fluorinated GHG that has the highest GWP among the fluorinated GHGs that occur in more than trace concentrations in the process. To convert the fluorinated GHG emissions to CO2e, use Equation A-1 of § 98.2. For fluorinated GHGs whose GWPs are not listed in Table A-1 to subpart A of this part, use a default GWP of 2,000.
(2) The total mass of each fluorinated GHG emitted annually from each fluorinated gas production and each fluorinated GHG transformation process must be estimated by using Equation L-5 of this section.
Where:
EFGHGf = Total mass of each fluorinated GHG f emitted annually from
production or transformation process i (metric tons). ERp-FGHGf =
Total mass of fluorinated GHG reactant f emitted from production
process i over the period p (metric tons, calculated in Equation
L-11 of this section). EPp-FGHGf = Total mass of the fluorinated
GHG product f emitted from production process i over the period p
(metric tons, calculated in Equation L-12 of this section).
EBp-FGHGf = Total mass of fluorinated GHG by-product f emitted from
production process i over the period p (metric tons, calculated in
Equation L-13 of this section). n = Number of concentration and
flow measurement periods for the year.
(3) The total mass of fluorine emitted from process i over the period p must be estimated at least monthly by calculating the difference between the total mass of fluorine in the reactant(s) (or inputs, for processes that do not involve a chemical reaction) and the total mass of fluorine in the product (or outputs, for processes that do not involve a chemical reaction), accounting for the total mass of fluorine in any destroyed or recaptured streams that contain reactants, products, or by-products (or inputs or outputs). This calculation must be performed using Equation L-6 of this section. An element other than fluorine may be used in the mass-balance equation, provided the element occurs in all of the fluorinated GHGs fed into or generated by the process. In this case, the mass fractions of the element in the reactants, products, and by-products must be calculated as appropriate for that element.
Where: EF
= Total mass of fluorine emitted from process i over the period p
(metric tons). Rd = Total mass of the fluorine-containing reactant
d that is fed into process i over the period p (metric tons). P =
Total mass of the fluorine-containing product produced by process i
over the period p (metric tons). MFFRd = Mass fraction of fluorine
in reactant d, calculated in Equation L-14 of this section. MFFP =
Mass fraction of fluorine in the product, calculated in Equation
L-15 of this section. FD = Total mass of fluorine in destroyed or
recaptured streams from process i containing fluorine-containing
reactants, products, and by-products over the period p, calculated
in Equation L-7 of this section. v = Number of fluorine-containing
reactants fed into process i.
(4) The mass of total fluorine in destroyed or recaptured streams containing fluorine-containing reactants, products, and by-products must be estimated at least monthly using Equation L-7 of this section unless you use the alternative approach provided in paragraph (b)(15) of this section.
Where: FD
= Total mass of fluorine in destroyed or recaptured streams from
process i containing fluorine-containing reactants, products, and
by-products over the period p. Pj = Mass of the fluorine-containing
product removed from process i in stream j and destroyed over the
period p (calculated in Equation L-8 or L-9 of this section). Bkj =
Mass of fluorine-containing by-product k removed from process i in
stream j and destroyed over the period p (calculated in Equation
L-8 or L-9 of this section). Bkl = Mass of fluorine-containing
by-product k removed from process i in stream l and recaptured over
the period p. Rdj = Mass of fluorine-containing reactant d removed
from process i in stream j and destroyed over the period p
(calculated in Equation L-8 or L-9 of this section). MFFRd = Mass
fraction of fluorine in reactant d, calculated in Equation L-14 of
this section. MFFP = Mass fraction of fluorine in the product,
calculated in Equation L-15 of this section. MFFBk = Mass fraction
of fluorine in by-product k, calculated in Equation L-16 of this
section. q = Number of streams destroyed in process i. x = Number
of streams recaptured in process i. u = Number of
fluorine-containing by-products generated in process i. v = Number
of fluorine-containing reactants fed into process i.
(5) The mass of each fluorinated GHG removed from process i in stream j and destroyed over the period p (i.e., Pj, Bkj, or Rdj, as applicable) must be estimated by applying the destruction efficiency (DE) of the device that has been demonstrated for the fluorinated GHG f to fluorinated GHG f using Equation L-8 of this section:
Where:
MFGHGfj = Mass of fluorinated GHG f removed from process i in
stream j and destroyed over the period p. (This may be Pj, Bkj, or
Rdj, as applicable.) DEFGHGf = Destruction efficiency of the device
that has been demonstrated for fluorinated GHG f in stream j
(fraction). CFGHGfj = Concentration (mass fraction) of fluorinated
GHG f in stream j removed from process i and fed into the
destruction device over the period p. If this concentration is only
a trace concentration, cF-GHGfj is equal to zero. Sj = Mass removed
in stream j from process i and fed into the destruction device over
the period p (metric tons).
(6) The mass of each fluorine-containing compound that is not a fluorinated GHG and that is removed from process i in stream j and destroyed over the period p (i.e., Pj, Bkj, or Rdj, as applicable) must be estimated using Equation L-9 of this section.
Where:
MFCgj = Mass of non-GHG fluorine-containing compound g removed from
process i in stream j and destroyed over the period p. (This may be
Pj, Bkj, or Rdj, as applicable). cFCgj = Concentration (mass
fraction) of non-GHG fluorine-containing compound g in stream j
removed from process i and fed into the destruction device over the
period p. If this concentration is only a trace concentration,
cFCgj is equal to zero. Sj = Mass removed in stream j from process
i and fed into the destruction device over the period p (metric
tons).
(7) The mass of fluorine-containing by-product k removed from process i in stream l and recaptured over the period p must be estimated using Equation L-10 of this section:
Where:
Bkl = Mass of fluorine-containing by-product k removed from process
i in stream l and recaptured over the period p (metric tons). cBkl
= Concentration (mass fraction) of fluorine-containing by-product k
in stream l removed from process i and recaptured over the period
p. If this concentration is only a trace concentration, cBkl is
equal to zero. Sl = Mass removed in stream l from process i and
recaptured over the period p (metric tons).
(8) To estimate the terms FERd, FEP, and FEBk for Equations L-11, L-12, and L-13 of this section, you must assume that the total mass of fluorine emitted, EF, estimated in Equation L-6 of this section, occurs in the form of the fluorinated GHG that has the highest GWP among the fluorinated GHGs that occur in more than trace concentrations in the process unless you possess emission characterization measurements showing otherwise. These emission characterization measurements must meet the requirements in paragraph (8)(i), (ii), or (iii) of this section, as appropriate. The sum of the terms must equal 1. You must document the data and calculations that are used to speciate individual compounds and to estimate FERd, FEP, and FEBk. Exclude from your calculations the fluorine included in FD. For example, exclude fluorine-containing compounds that are not fluorinated GHGs and that result from the destruction of fluorinated GHGs by any destruction devices (e.g., the mass of HF created by combustion of an HFC). However, include emissions of fluorinated GHGs that survive the destruction process.
(i) If the calculations under paragraph (b)(1)(viii) of this section, or any subsequent measurements and calculations under this subpart, indicate that the process emits 25,000 metric tons CO2e or more, estimate the emissions from each process vent, considering controls, using the methods in § 98.123(c)(1). You must characterize the emissions of any process vent that emits 25,000 metric tons CO2e or more as specified in § 98.124(b)(4).
(ii) For other vents, including vents from processes that emit less than 25,000 metric tons CO2e, you must characterize emissions as specified in § 98.124(b)(5).
(iii) For fluorine emissions that are not accounted for by vent estimates, you must characterize emissions as specified in § 98.124(b)(6).
(9) The total mass of fluorine-containing reactant d emitted must be estimated at least monthly based on the total fluorine emitted and the fraction that consists of fluorine-containing reactants using Equation L-11 of this section. If the fluorine-containing reactant d is a non-GHG, you may assume that FERd is zero.
Where:
ER-ip = Total mass of fluorine-containing reactant d that is
emitted from process i over the period p (metric tons). FERd = The
fraction of the mass emitted that consists of the
fluorine-containing reactant d. EF = Total mass of fluorine
emissions from process i over the period p (metric tons),
calculated in Equation L-6 of this section. FEP = The fraction of
the mass emitted that consists of the fluorine-containing product.
FEBk = The fraction of the mass emitted that consists of
fluorine-containing by-product k. MFFRd = Mass fraction of fluorine
in reactant d, calculated in Equation L-14 of this section. MFFP =
Mass fraction of fluorine in the product, calculated in Equation
L-15 of this section. MFFBk = Mass fraction of fluorine in
by-product k, calculation in Equation L-16 of this section. u =
Number of fluorine-containing by-products generated in process i. v
= Number of fluorine-containing reactants fed into process i.
(10) The total mass of fluorine-containing product emitted must be estimated at least monthly based on the total fluorine emitted and the fraction that consists of fluorine-containing products using Equation L-12 of this section. If the fluorine-containing product is a non-GHG, you may assume that FEP is zero.
Where:
EP-ip = Total mass of fluorine-containing product emitted from
process i over the period p (metric tons). FEP = The fraction of
the mass emitted that consists of the fluorine-containing product.
EF = Total mass of fluorine emissions from process i over the
period p (metric tons), calculated in Equation L-6 of this section.
FERd = The fraction of the mass emitted that consists of
fluorine-containing reactant d. FEBk = The fraction of the mass
emitted that consists of fluorine-containing by-product k. MFFRd =
Mass fraction of fluorine in reactant d, calculated in Equation
L-14 of this section. MFFP = Mass fraction of fluorine in the
product, calculated in Equation L-15 of this section. MFFBk = Mass
fraction of fluorine in by-product k, calculation in Equation L-16
of this section. u = Number of fluorine-containing by-products
generated in process i. v = Number of fluorine-containing reactants
fed into process i.
(11) The total mass of fluorine-containing by-product k emitted must be estimated at least monthly based on the total fluorine emitted and the fraction that consists of fluorine-containing by-products using Equation L-13 of this section. If fluorine-containing by-product k is a non-GHG, you may assume that FEBk is zero.
Where:
EBk-ip = Total mass of fluorine-containing by-product k emitted
from process i over the period p (metric tons). FEBk = The fraction
of the mass emitted that consists of fluorine-containing by-product
k. FERd = The fraction of the mass emitted that consists of
fluorine-containing reactant d. FEP = The fraction of the mass
emitted that consists of the fluorine-containing product. EF =
Total mass of fluorine emissions from process i over the period p
(metric tons), calculated in Equation L-6 of this section. MFFRd =
Mass fraction of fluorine in reactant d, calculated in Equation
L-14 of this section. MFFP = Mass fraction of fluorine in the
product, calculated in Equation L-15 of this section. MFFBk = Mass
fraction of fluorine in by-product k, calculation in Equation L-16
of this section. u = Number of fluorine-containing by-products
generated in process i. v = Number of fluorine-containing reactants
fed into process i.
(12) The mass fraction of fluorine in reactant d must be estimated using Equation L-14 of this section:
Where:
MFFRd = Mass fraction of fluorine in reactant d (fraction). MFRd =
Moles fluorine per mole of reactant d. AWF = Atomic weight of
fluorine. MWRd = Molecular weight of reactant d.
(13) The mass fraction of fluorine in the product must be estimated using Equation L-15 of this section:
Where:
MFFP = Mass fraction of fluorine in the product (fraction). MFP =
Moles fluorine per mole of product. AWF = Atomic weight of
fluorine. MWP = Molecular weight of the product produced.
(14) The mass fraction of fluorine in by-product k must be estimated using Equation L-16 of this section:
Where:
MFFBk = Mass fraction of fluorine in the product (fraction). MFBk =
Moles fluorine per mole of by-product k. AWF = Atomic weight of
fluorine. MWBk = Molecular weight of by-product k.
(15) Alternative for determining the mass of fluorine destroyed or recaptured. As an alternative to using Equation L-7 of this section as provided in paragraph (b)(4) of this section, you may estimate at least monthly the total mass of fluorine in destroyed or recaptured streams containing fluorine-containing compounds (including all fluorine-containing reactants, products, and byproducts) using Equation L-17 of this section.
Where: FD
= Total mass of fluorine in destroyed or recaptured streams from
process i containing fluorine-containing reactants, products, and
by-products over the period p. DEavgj = Weighted average
destruction efficiency of the destruction device for the
fluorine-containing compounds identified in destroyed stream j
under § 98.124(b)(4)(ii) and (5)(ii) (calculated in Equation L-18
of this section)(fraction). cTFj = Concentration (mass fraction) of
total fluorine in stream j removed from process i and fed into the
destruction device over the period p. If this concentration is only
a trace concentration, cTFj is equal to zero. Sj = Mass removed in
stream j from process i and fed into the destruction device over
the period p (metric tons). cTFl = Concentration (mass fraction) of
total fluorine in stream l removed from process i and recaptured
over the period p. If this concentration is only a trace
concentration, cBkl is equal to zero. Sl = Mass removed in stream l
from process i and recaptured over the period p. q = Number of
streams destroyed in process i. x = Number of streams recaptured in
process i.
(16) Weighted average destruction efficiency. For purposes of Equation L-17 of this section, calculate the weighted average destruction efficiency applicable to a destroyed stream using Equation L-18 of this section.
Where:
DEavgj = Weighted average destruction efficiency of the destruction
device for the fluorine-containing compounds identified in
destroyed stream j under 98.124(b)(4)(ii) or (b)(5)(ii), as
appropriate. DEFGHGf = Destruction efficiency of the device that
has been demonstrated for fluorinated GHG f in stream j (fraction).
cFGHGfj = Concentration (mass fraction) of fluorinated GHG f in
stream j removed from process i and fed into the destruction device
over the period p. If this concentration is only a trace
concentration, cF-GHGfj is equal to zero. cFCgj = Concentration
(mass fraction) of non-GHG fluorine-containing compound g in stream
j removed from process i and fed into the destruction device over
the period p. If this concentration is only a trace concentration,
cFCgj is equal to zero. Sj = Mass removed in stream j from process
i and fed into the destruction device over the period p (metric
tons). MFFFGHGf = Mass fraction of fluorine in fluorinated GHG f,
calculated in Equation L-14, L-15, or L-16 of this section, as
appropriate. MFFFCg = Mass fraction of fluorine in non-GHG
fluorine-containing compound g, calculated in Equation L-14, L-15,
or L-16 of this section, as appropriate. w = Number of fluorinated
GHGs in destroyed stream j. y = Number of non-GHG
fluorine-containing compounds in destroyed stream j.
2. Mass Balance Method for § 98.124(b). [Note: Numbering convention here matches original rule text, 75 FR 74774, December 1, 2010.]
(b) Mass balance monitoring. If you determine fluorinated GHG emissions from any process using the mass balance method under § 98.123(b), you must estimate the total mass of each fluorinated GHG emitted from that process at least monthly. Only streams that contain greater than trace concentrations of fluorine-containing reactants, products, or by-products must be monitored under this paragraph. If you use an element other than fluorine in the mass-balance equation pursuant to § 98.123(b)(3), substitute that element for fluorine in the monitoring requirements of this paragraph.
(1) Mass measurements. Measure the following masses on a monthly or more frequent basis using flowmeters, weigh scales, or a combination of volumetric and density measurements with accuracies and precisions that allow the facility to meet the error criteria in § 98.123(b)(1):
(i) Total mass of each fluorine-containing product produced. Account for any used fluorine-containing product added into the production process upstream of the output measurement as directed at §§ 98.413(b) and 98.414(b). For each product, the mass produced used for the mass-balance calculation must be the same as the mass produced that is reported under subpart OO of this part, where applicable.
(ii) Total mass of each fluorine-containing reactant fed into the process.
(iii) The mass removed from the process in each stream fed into the destruction device.
(iv) The mass removed from the process in each recaptured stream.
(2) Concentration measurements for use with § 98.123(b)(4). If you use § 98.123(b)(4) to estimate the mass of fluorine in destroyed or recaptured streams, measure the following concentrations at least once each calendar month during which the process is operating, on a schedule to ensure that the measurements are representative of the full range of process conditions (e.g., catalyst age). Measure more frequently if this is necessary to meet the error criteria in § 98.123(b)(1). Use equipment and methods (e.g., gas chromatography) that comply with paragraph (e) of this section and that have an accuracy and precision that allow the facility to meet the error criteria in § 98.123(b)(1). Only fluorine-containing reactants, products, and by-products that occur in a stream in greater than trace concentrations must be monitored under this paragraph.
(i) The concentration (mass fraction) of the fluorine-containing product in each stream that is fed into the destruction device.
(ii) The concentration (mass fraction) of each fluorine-containing by-product in each stream that is fed into the destruction device.
(iii) The concentration (mass fraction) of each fluorine-containing reactant in each stream that is fed into the destruction device.
(iv) The concentration (mass fraction) of each fluorine-containing by-product in each stream that is recaptured (cBkl).
(3) Concentration measurements for use with § 98.123(b)(15). If you use § 98.123(b)(15) to estimate the mass of fluorine in destroyed or recaptured streams, measure the concentrations listed in paragraphs (b)(3)(i) and (ii) of this section at least once each calendar month during which the process is operating, on a schedule to ensure that the measurements are representative of the full range of process conditions (e.g., catalyst age). Measure more frequently if this is necessary to meet the error criteria in § 98.123(b)(1). Use equipment and methods (e.g., gas chromatography) that comply with paragraph (e) of this section and that have an accuracy and precision that allow the facility to meet the error criteria in § 98.123(b)(1). Only fluorine-containing reactants, products, and by-products that occur in a stream in greater than trace concentrations must be monitored under this paragraph.
(i) The concentration (mass fraction) of total fluorine in each stream that is fed into the destruction device.
(ii) The concentration (mass fraction) of total fluorine in each stream that is recaptured.
(4) Emissions characterization: process vents emitting 25,000 metric tons CO2e or more. To characterize emissions from any process vent emitting 25,000 metric tons CO2e or more, comply with paragraphs (b)(4)(i) through (b)(4)(v) of this section, as appropriate. Only fluorine-containing reactants, products, and by-products that occur in a stream in greater than trace concentrations must be monitored under this paragraph.
(i) Uncontrolled emissions. If emissions from the process vent are not routed through a destruction device, sample and analyze emissions at the process vent or stack or sample and analyze emitted streams before the process vent. If the process has more than one operating scenario, you must either perform the emission characterization for each operating scenario or perform the emission characterization for the operating scenario that is expected to have the largest emissions and adjust the emission characterization for other scenarios using engineering calculations and assessments as specified in § 98.123(c)(4). To perform the characterization, take three samples under conditions that are representative for the operating scenario. Measure the concentration of each fluorine-containing compound in each sample. Use equipment and methods that comply with paragraph (e) of this section. Calculate the average concentration of each fluorine-containing compound across all three samples.
(ii) Controlled emissions using § 98.123(b)(15). If you use § 98.123(b)(15) to estimate the total mass of fluorine in destroyed or recaptured streams, and if the emissions from the process vent are routed through a destruction device, characterize emissions as specified in paragraph (b)(4)(i) of this section before the destruction device. Apply the destruction efficiency demonstrated for each fluorinated GHG in the destroyed stream to that fluorinated GHG. Exclude from the characterization fluorine-containing compounds that are not fluorinated GHGs.
(iii) Controlled emissions using § 98.123(b)(4). If you use § 98.123(b)(4) to estimate the mass of fluorine in destroyed or recaptured streams, and if the emissions from the process vent are routed through a destruction device, characterize the process vent's emissions monthly (or more frequently) using the monthly (or more frequent) measurements under paragraphs (b)(1)(iii) and (b)(2)(i) through (iii) of this section. Apply the destruction efficiency demonstrated for each fluorinated GHG in the destroyed stream to that fluorinated GHG. Exclude from the characterization fluorine-containing compounds that are not fluorinated GHGs.
(iv) Emissions characterization frequency. You must repeat emission characterizations performed under paragraph (b)(4)(i) and (ii) of this section under paragraph (b)(4)(iv)(A) or (B) of this section, whichever occurs first:
(A) 10-year revision. Repeat the emission characterization every 10 years. In the calculations under § 98.123, apply the revised emission characterization to the process activity that occurs after the revision.
(B) Operating scenario change that affects the emission characterization. For planned operating scenario changes, you must estimate and compare the emission calculation factors for the changed operating scenario and for the original operating scenario whose process vent specific emission factor was measured. Use the engineering calculations and assessments specified in § 98.123(c)(4). If the share of total fluorine-containing compound emissions represented by any fluorinated GHG changes under the changed operating scenario by 15 percent or more of the total, relative to the previous operating scenario (this includes the cumulative change in the emission calculation factor since the last emissions test), you must repeat the emission characterization. Perform the emission characterization before February 28 of the year that immediately follows the change. In the calculations under § 98.123, apply the revised emission characterization to the process activity that occurs after the operating scenario change.
(v) Subsequent measurements. If a process vent with fluorinated GHG emissions less than 25,000 metric tons CO2e, per § 98.123(c)(2), is later found to have fluorinated GHG emissions of 25,000 metric tons CO2e or greater, you must perform an emission characterization under this paragraph during the following year.
(5) Emissions characterization: Process vents emitting less than 25,000 metric tons CO2e. To characterize emissions from any process vent emitting less than 25,000 metric tons CO2e, comply with paragraphs (b)(5)(i) through (iii) of this section, as appropriate. Only fluorine-containing reactants, products, and by-products that occur in a stream in greater than trace concentrations must be monitored under this paragraph.
(i) Uncontrolled emissions. If emissions from the process vent are not routed through a destruction device, emission measurements must consist of sampling and analysis of emissions at the process vent or stack, sampling and analysis of emitted streams before the process vent, previous test results, provided the tests are representative of current operating conditions of the process, or bench-scale or pilot-scale test data representative of the process operating conditions.
(ii) Controlled emissions using § 98.123(b)(15). If you use § 98.123(b)(15) to estimate the total mass of fluorine in destroyed or recaptured streams, and if the emissions from the process vent are routed through a destruction device, characterize emissions as specified in paragraph (b)(5)(i) of this section before the destruction device. Apply the destruction efficiency demonstrated for each fluorinated GHG in the destroyed stream to that fluorinated GHG. Exclude from the characterization fluorine-containing compounds that are not fluorinated GHGs.
(iii) Controlled emissions using § 98.123(b)(4). If you use § 98.123(b)(4) to estimate the mass of fluorine in destroyed or recaptured streams, and if the emissions from the process vent are routed through a destruction device, characterize the process vent's emissions monthly (or more frequently) using the monthly (or more frequent) measurements under paragraphs (b)(1)(iii) and (b)(2)(i) through (iii) of this section. Apply the destruction efficiency demonstrated for each fluorinated GHG in the destroyed stream to that fluorinated GHG. Exclude from the characterization fluorine-containing compounds that are not fluorinated GHGs.
(6) Emissions characterization: Emissions not accounted for by process vent estimates. Calculate the weighted average emission characterization across the process vents before any destruction devices. Apply the weighted average emission characterization for all the process vents to any fluorine emissions that are not accounted for by process vent estimates.
(7) Impurities in reactants. If any fluorine-containing impurity is fed into a process along with a reactant (or other input) in greater than trace concentrations, this impurity shall be monitored under this section and included in the calculations under § 98.123 in the same manner as reactants fed into the process, fed into the destruction device, recaptured, or emitted, except the concentration of the impurity in the mass fed into the process shall be measured, and the mass of the impurity fed into the process shall be calculated as the product of the concentration of the impurity and the mass fed into the process. The mass of the reactant fed into the process may be reduced to account for the mass of the impurity.
(8) Alternative to error calculation. As an alternative to calculating the relative and absolute errors associated with the estimate of emissions under § 98.123(b), you may comply with the precision, accuracy, measurement and calculation frequency, and fluorinated GHG throughput requirements of paragraph (b)(8)(i) through (iv) of this section.
(i) Mass measurements. Measure the masses specified in paragraph (b)(1) of this section using flowmeters, weigh scales, or a combination of volumetric and density measurements with accuracies and precisions of ±0.2 percent of full scale or better.
(ii) Concentration measurements. Measure the concentrations specified in paragraph (b)(2) or (3) of this section, as applicable, using analytical methods with accuracies and precisions of ±10 percent or better.
(iii) Measurement and calculation frequency. Perform the mass measurements specified in paragraph (b)(1) of this section and the concentration measurements specified in paragraph (b)(2) or (3) of this section, as applicable, at least weekly, and calculate emissions at least weekly.
(iv) Fluorinated-GHG throughput limit. You may use the alternative to the error calculation specified in paragraph (b)(8) of this section only if the total annual CO2-equivalent fluorinated GHG throughput of the process is 500,000 mtCO2e or less. The total throughput is the sum of the masses of the fluorinated GHG reactants, products, and by-products fed into and generated by the process. To convert these masses to CO2e, use Equation A-1 of § 98.2. For fluorinated GHGs whose GWPs are not listed in Table A-1 to subpart A of this part, use a default GWP of 2,000.
[79 FR 73789, Dec. 11, 2014]Table N-1 to Subpart N of Part 98 - CO2 Emission Factors for Carbonate-Based Raw Materials
40:23.0.1.1.3.14.1.10.43 :
Table N-1 to Subpart N of Part 98 - CO2 Emission Factors for Carbonate-Based Raw Materials| Carbonate-based raw material - mineral |
CO2 emission factor a |
|---|---|
| Limestone - CaCO3 | 0.440 |
| Dolomite - CaMg(CO3)2 | 0.477 |
| Sodium carbonate/soda ash - Na2CO3 | 0.415 |
| Barium carbonate - BaCO3 | 0.223 |
| Potassium carbonate - K2CO3 | 0.318 |
| Lithium carbonate (Li2CO3) | 0.596 |
| Strontium carbonate (SrCO3) | 0.298 |
a Emission factors in units of metric tons of CO2 emitted per metric ton of carbonate-based raw material charged to the furnace.
Table O-1 to Subpart O of Part 98 - Emission Factors for Equipment Leaks
40:23.0.1.1.3.15.1.10.44 :
Table O-1 to Subpart O of Part 98 - Emission Factors for Equipment Leaks| Equipment type | Service | Emission
factor (kg/hr/source) |
|
|---|---|---|---|
| ≥10,000 ppmv | <10,000 ppmv | ||
| Valves | Gas | 0.0782 | 0.000131 |
| Valves | Light liquid | 0.0892 | 0.000165 |
| Pump seals | Light liquid | 0.243 | 0.00187 |
| Compressor seals | Gas | 1.608 | 0.0894 |
| Pressure relief valves | Gas | 1.691 | 0.0447 |
| Connectors | All | 0.113 | 0.0000810 |
| Open-ended lines | All | 0.01195 | 0.00150 |
Table S-1 to Subpart S of Part 98 - Basic Parameters for the Calculation of Emission Factors for Lime Production
40:23.0.1.1.3.19.1.10.45 :
Table S-1 to Subpart S of Part 98 - Basic Parameters for the Calculation of Emission Factors for Lime Production| Variable | Stoichiometric ratio |
|---|---|
| SRCaO | 0.7848 |
| SRMgO | 1.0918 |
Table U-1 to Subpart U of Part 98 - CO2 Emission Factors for Common Carbonates
40:23.0.1.1.3.21.1.10.46 :
Table U-1 to Subpart U of Part 98 - CO2 Emission Factors for Common Carbonates| Mineral name - carbonate | CO2 emission factor (tons CO2/ton carbonate) |
|---|---|
| Limestone - CaCO3 | 0.43971 |
| Magnesite - MgCO3 | 0.52197 |
| Dolomite - CaMg(CO3)2 | 0.47732 |
| Siderite - FeCO3 | 0.37987 |
| Ankerite - Ca(Fe, Mg, Mn)(CO3)2 | 0.47572 |
| Rhodochrosite - MnCO3 | 0.38286 |
| Sodium Carbonate/Soda Ash - Na2CO3 | 0.41492 |
Table W-1A to Subpart W of Part 98 - Default Whole Gas Emission Factors for Onshore Petroleum and Natural Gas Production Facilities and Onshore Petroleum and Natural Gas Gathering and Boosting Facilities
40:23.0.1.1.3.23.1.10.47 :
Table W-1A to Subpart W of Part 98 - Default Whole Gas Emission Factors for Onshore Petroleum and Natural Gas Production Facilities and Onshore Petroleum and Natural Gas Gathering and Boosting FacilitiesTable W-1A to Subpart W of Part 98 - Default Whole Gas Emission Factors for Onshore Petroleum and Natural Gas Production Facilities and Onshore Petroleum and Natural Gas Gathering and Boosting Facilities
| Onshore petroleum and natural gas production and Onshore petroleum and natural gas gathering and boosting | Emission factor (scf/hour/component) |
|---|---|
| Eastern U.S. | |
| Population Emission Factors - All Components, Gas Service 1 | |
| Valve | 0.027 |
| Connector | 0.003 |
| Open-ended Line | 0.061 |
| Pressure Relief Valve | 0.040 |
| Low Continuous Bleed Pneumatic Device Vents 2 | 1.39 |
| High Continuous Bleed Pneumatic Device Vents 2 | 37.3 |
| Intermittent Bleed Pneumatic Device Vents 2 | 13.5 |
| Pneumatic Pumps 3 | 13.3 |
| Population Emission Factors - All Components, Light Crude Service 4 | |
| Valve | 0.05 |
| Flange | 0.003 |
| Connector | 0.007 |
| Open-ended Line | 0.05 |
| Pump | 0.01 |
| Other 5 | 0.30 |
| Population Emission Factors - All Components, Heavy Crude Service 6 | |
| Valve | 0.0005 |
| Flange | 0.0009 |
| Connector (other) | 0.0003 |
| Open-ended Line | 0.006 |
| Other 5 | 0.003 |
| Population Emission Factors - Gathering Pipelines, by Material Type 7 | |
| Protected Steel | 0.47 |
| Unprotected Steel | 16.59 |
| Plastic/Composite | 2.50 |
| Cast Iron | 27.60 |
| Western U.S. | |
| Population Emission Factors - All Components, Gas Service 1 | |
| Valve | 0.121 |
| Connector | 0.017 |
| Open-ended Line | 0.031 |
| Pressure Relief Valve | 0.193 |
| Low Continuous Bleed Pneumatic Device Vents 2 | 1.39 |
| High Continuous Bleed Pneumatic Device Vents 2 | 37.3 |
| Intermittent Bleed Pneumatic Device Vents 2 | 13.5 |
| Pneumatic Pumps 3 | 13.3 |
| Population Emission Factors - All Components, Light Crude Service 4 | |
| Valve | 0.05 |
| Flange | 0.003 |
| Connector (other) | 0.007 |
| Open-ended Line | 0.05 |
| Pump | 0.01 |
| Other 5 | 0.30 |
| Population Emission Factors - All Components, Heavy Crude Service 6 | |
| Valve | 0.0005 |
| Flange | 0.0009 |
| Connector (other) | 0.0003 |
| Open-ended Line | 0.006 |
| Other 5 | 0.003 |
| Population Emission Factors - Gathering Pipelines by Material Type 7 | |
| Protected Steel | 0.47 |
| Unprotected Steel | 16.59 |
| Plastic/Composite | 2.50 |
| Cast Iron | 27.60 |
1 For multi-phase flow that includes gas, use the gas service emissions factors.
2 Emission Factor is in units of “scf/hour/device.”
3 Emission Factor is in units of “scf/hour/pump.”
4 Hydrocarbon liquids greater than or equal to 20°API are considered “light crude.”
5 “Others” category includes instruments, loading arms, pressure relief valves, stuffing boxes, compressor seals, dump lever arms, and vents.
6 Hydrocarbon liquids less than 20°API are considered “heavy crude.”
7 Emission factors are in units of “scf/hour/mile of pipeline.”
Table W-1B to Subpart W of Part 98 - Default Average Component Counts for Major Onshore Natural Gas Production Equipment and Onshore Petroleum and Natural Gas Gathering and Boosting Equipment
40:23.0.1.1.3.23.1.10.48 :
Table W-1B to Subpart W of Part 98 - Default Average Component Counts for Major Onshore Natural Gas Production Equipment and Onshore Petroleum and Natural Gas Gathering and Boosting Equipment| Major equipment | Valves | Connectors | Open-ended lines | Pressure relief valves |
|---|---|---|---|---|
| Eastern U.S. | ||||
| Wellheads | 8 | 38 | 0.5 | 0 |
| Separators | 1 | 6 | 0 | 0 |
| Meters/piping | 12 | 45 | 0 | 0 |
| Compressors | 12 | 57 | 0 | 0 |
| In-line heaters | 14 | 65 | 2 | 1 |
| Dehydrators | 24 | 90 | 2 | 2 |
| Western U.S. | ||||
| Wellheads | 11 | 36 | 1 | 0 |
| Separators | 34 | 106 | 6 | 2 |
| Meters/piping | 14 | 51 | 1 | 1 |
| Compressors | 73 | 179 | 3 | 4 |
| In-line heaters | 14 | 65 | 2 | 1 |
| Dehydrators | 24 | 90 | 2 | 2 |
Table W-1C to Subpart W of Part 98 - Default Average Component Counts For Major Crude Oil Production Equipment
40:23.0.1.1.3.23.1.10.49 :
Table W-1C to Subpart W of Part 98 - Default Average Component Counts For Major Crude Oil Production Equipment| Major equipment | Valves | Flanges | Connectors | Open-ended lines | Other components |
|---|---|---|---|---|---|
| Eastern U.S. | |||||
| Wellhead | 5 | 10 | 4 | 0 | 1 |
| Separator | 6 | 12 | 10 | 0 | 0 |
| Heater-treater | 8 | 12 | 20 | 0 | 0 |
| Header | 5 | 10 | 4 | 0 | 0 |
| Western U.S. | |||||
| Wellhead | 5 | 10 | 4 | 0 | 1 |
| Separator | 6 | 12 | 10 | 0 | 0 |
| Heater-treater | 8 | 12 | 20 | 0 | 0 |
| Header | 5 | 10 | 4 | 0 | 0 |
Table W-1D to Subpart W of Part 98 - Designation Of Eastern And Western U.S.
40:23.0.1.1.3.23.1.10.50 :
Table W-1D to Subpart W of Part 98 - Designation Of Eastern And Western U.S.| Eastern U.S. | Western U.S. |
|---|---|
| Connecticut | Alabama |
| Delaware | Alaska |
| Florida | Arizona |
| Georgia | Arkansas |
| Illinois | California |
| Indiana | Colorado |
| Kentucky | Hawaii |
| Maine | Idaho |
| Maryland | Iowa |
| Massachusetts | Kansas |
| Michigan | Louisiana |
| New Hampshire | Minnesota |
| New Jersey | Mississippi |
| New York | Missouri |
| North Carolina | Montana |
| Ohio | Nebraska |
| Pennsylvania | Nevada |
| Rhode Island | New Mexico |
| South Carolina | North Dakota |
| Tennessee | Oklahoma |
| Vermont | Oregon |
| Virginia | South Dakota |
| West Virginia | Texas |
| Wisconsin | Utah |
| Washington | |
| Wyoming |
Table W-1E to Subpart W of Part 98 - Default Whole Gas Leaker Emission Factors for Onshore Petroleum and Natural Gas Production and Onshore Petroleum and Natural Gas Gathering and Boosting
40:23.0.1.1.3.23.1.10.51 :
Table W-1E to Subpart W of Part 98 - Default Whole Gas Leaker Emission Factors for Onshore Petroleum and Natural Gas Production and Onshore Petroleum and Natural Gas Gathering and Boosting| Equipment components | Emission
factor (scf/hour/component) |
|
|---|---|---|
| If you survey using any of
the methods in § 98.234(a)(1) through (6) |
If you survey using Method
21 as specified in § 98.234(a)(7) |
|
| Leaker Emission Factors - All Components, Gas Service 1 | ||
| Valve | 4.9 | 3.5 |
| Flange | 4.1 | 2.2 |
| Connector (other) | 1.3 | 0.8 |
| Open-Ended Line 2 | 2.8 | 1.9 |
| Pressure Relief Valve | 4.5 | 2.8 |
| Pump Seal | 3.7 | 1.4 |
| Other 3 | 4.5 | 2.8 |
| Leaker Emission Factors - All Components, Light Crude Service 1 | ||
| Valve | 3.2 | 2.2 |
| Flange | 2.7 | 1.4 |
| Connector (other) | 1.0 | 0.6 |
| Open-Ended Line | 1.6 | 1.1 |
| Pump | 3.7 | 2.6 |
| Agitator Seal | 3.7 | 2.6 |
| Other 3 | 3.1 | 2.0 |
| Leaker Emission Factors - All Components, Heavy Crude Service 1 | ||
| Valve | 3.2 | 2.2 |
| Flange | 2.7 | 1.4 |
| Connector (other) | 1.0 | 0.6 |
| Open-Ended Line | 1.6 | 1.1 |
| Pump | 3.7 | 2.6 |
| Agitator Seal | 3.7 | 2.6 |
| Other 3 | 3.1 | 2.0 |
1 For multi-phase flow that includes gas, use the gas service emission factors.
2 The open-ended lines component type includes blowdown valve and isolation valve leaks emitted through the blowdown vent stack for centrifugal and reciprocating compressors.
3 “Others” category includes any equipment leak emission point not specifically listed in this table, as specified in § 98.232(c)(21) and (j)(10).
4 Hydrocarbon liquids greater than or equal to 20°API are considered “light crude.”
5 Hydrocarbon liquids less than 20°API are considered “heavy crude.”
Table W-2 to Subpart W of Part 98 - Default Total Hydrocarbon Emission Factors for Onshore Natural Gas Processing
40:23.0.1.1.3.23.1.10.52 :
Table W-2 to Subpart W of Part 98 - Default Total Hydrocarbon Emission Factors for Onshore Natural Gas Processing| Onshore natural gas processing plants | Emission factor
(scf/hour/ component) |
|---|---|
| Leaker Emission Factors - Compressor Components, Gas Service | |
| Valve 1 | 14.84 |
| Connector | 5.59 |
| Open-Ended Line | 17.27 |
| Pressure Relief Valve | 39.66 |
| Meter | 19.33 |
| Leaker Emission Factors - Non-Compressor Components, Gas Service | |
| Valve 1 | 6.42 |
| Connector | 5.71 |
| Open-Ended Line | 11.27 |
| Pressure Relief Valve | 2.01 |
| Meter | 2.93 |
1 Valves include control valves, block valves and regulator valves.
Table W-3A to Subpart W of Part 98 - Default Total Hydrocarbon Leaker Emission Factors for Onshore Natural Gas Transmission Compression
40:23.0.1.1.3.23.1.10.53 :
Table W-3A to Subpart W of Part 98 - Default Total Hydrocarbon Leaker Emission Factors for Onshore Natural Gas Transmission Compression| Onshore natural gas transmission compression | Emission
factor (scf/hour/component) |
|
|---|---|---|
| If you survey using any of
the methods in § 98.234(a)(1) through (6) |
If you survey using Method 21
as specified in § 98.234(a)(7) |
|
| Leaker Emission Factors - Compressor Components, Gas Service | ||
| Valve 1 | 14.84 | 9.51 |
| Connector | 5.59 | 3.58 |
| Open-Ended Line | 17.27 | 11.07 |
| Pressure Relief Valve | 39.66 | 25.42 |
| Meter or Instrument | 19.33 | 12.39 |
| Other 2 | 4.1 | 2.63 |
| Leaker Emission Factors - Non-Compressor Components, Gas Service | ||
| Valve 1 | 6.42 | 4.12 |
| Connector | 5.71 | 3.66 |
| Open-Ended Line | 11.27 | 7.22 |
| Pressure Relief Valve | 2.01 | 1.29 |
| Meter or Instrument | 2.93 | 1.88 |
| Other 2 | 4.1 | 2.63 |
1 Valves include control valves, block valves and regulator valves.
2 Other includes any potential equipment leak emission point in gas service that is not specifically listed in this table, as specified in § 98.232(e)(8).
Table W-3B to Subpart W of Part 98 - Default Total Hydrocarbon Population Emission Factors for Onshore Natural Gas Transmission Compression
40:23.0.1.1.3.23.1.10.54 :
Table W-3B to Subpart W of Part 98 - Default Total Hydrocarbon Population Emission Factors for Onshore Natural Gas Transmission CompressionTable W-3B to Subpart W of Part 98 - Default Total Hydrocarbon Population Emission Factors for Onshore Natural Gas Transmission Compression
| Population emission factors - gas service onshore natural gas transmission compression | Emission factor (scf/hour/component) |
|---|---|
| Low Continuous Bleed Pneumatic Device Vents 1 | 1.37 |
| High Continuous Bleed Pneumatic Device Vents 1 | 18.20 |
| Intermittent Bleed Pneumatic Device Vents 1 | 2.35 |
1 Emission Factor is in units of “scf/hour/device.”
Table W-4A to Subpart W of Part 98 - Default Total Hydrocarbon Leaker Emission Factors for Underground Natural Gas Storage
40:23.0.1.1.3.23.1.10.55 :
Table W-4A to Subpart W of Part 98 - Default Total Hydrocarbon Leaker Emission Factors for Underground Natural Gas Storage| Underground natural gas storage | Emission
factor (scf/hour/component) |
|
|---|---|---|
| If you survey using any of
the methods in § 98.234(a)(1) through (6) |
If you survey using Method 21
as specified in § 98.234(a)(7) |
|
| Leaker Emission Factors - Storage Station, Gas Service | ||
| Valve 1 | 14.84 | 9.51 |
| Connector (other) | 5.59 | 3.58 |
| Open-Ended Line | 17.27 | 11.07 |
| Pressure Relief Valve | 39.66 | 25.42 |
| Meter and Instrument | 19.33 | 12.39 |
| Other 2 | 4.1 | 2.63 |
| Leaker Emission Factors - Storage Wellheads, Gas Service | ||
| Valve 1 | 4.5 | 3.2 |
| Connector (other than flanges) | 1.2 | 0.7 |
| Flange | 3.8 | 2.0 |
| Open-Ended Line | 2.5 | 1.7 |
| Pressure Relief Valve | 4.1 | 2.5 |
| Other 2 | 4.1 | 2.5 |
1 Valves include control valves, block valves and regulator valves.
2 Other includes any potential equipment leak emission point in gas service that is not specifically listed in this table, as specified in § 98.232(f)(6) and (8).
Table W-4B to Subpart W of Part 98 - Default Total Hydrocarbon Population Emission Factors for Underground Natural Gas Storage
40:23.0.1.1.3.23.1.10.56 :
Table W-4B to Subpart W of Part 98 - Default Total Hydrocarbon Population Emission Factors for Underground Natural Gas StorageTable W-4B to Subpart W of Part 98 - Default Total Hydrocarbon Population Emission Factors for Underground Natural Gas Storage
| Underground natural gas storage | Emission factor (scf/hour/component) |
|---|---|
| Population Emission Factors - Storage Wellheads, Gas Service | |
| Connector | 0.01 |
| Valve | 0.1 |
| Pressure Relief Valve | 0.17 |
| Open-Ended Line | 0.03 |
| Population Emission Factors - Other Components, Gas Service | |
| Low Continuous Bleed Pneumatic Device Vents 1 | 1.37 |
| High Continuous Bleed Pneumatic Device Vents 1 | 18.20 |
| Intermittent Bleed Pneumatic Device Vents 1 | 2.35 |
1 Emission Factor is in units of “scf/hour/device.”
Table W-5A to Subpart W of Part 98 - Default Methane Leaker Emission Factors for Liquefied Natural Gas (LNG) Storage
40:23.0.1.1.3.23.1.10.57 :
Table W-5A to Subpart W of Part 98 - Default Methane Leaker Emission Factors for Liquefied Natural Gas (LNG) Storage| LNG storage | Emission
factor (scf/hour/component) |
|
|---|---|---|
| If you survey using any of
the methods in § 98.234(a)(1) through (6) |
If you survey using Method 21
as specified in § 98.234(a)(7) |
|
| Leaker Emission Factors - LNG Storage Components, LNG Service | ||
| Valve | 1.19 | 0.23 |
| Pump Seal | 4.00 | 0.73 |
| Connector | 0.34 | 0.11 |
| Other 1 | 1.77 | 0.99 |
| Leaker Emission Factors - LNG Storage Components, Gas Service | ||
| Valve 2 | 14.84 | 9.51 |
| Connector | 5.59 | 3.58 |
| Open-Ended Line | 17.27 | 11.07 |
| Pressure Relief Valve | 39.66 | 25.42 |
| Meter and Instrument | 19.33 | 12.39 |
| Other 3 | 4.1 | 2.63 |
1 “Other” equipment type for components in LNG service should be applied for any equipment type other than connectors, pumps, or valves.
2 Valves include control valves, block valves and regulator valves.
3 “Other” equipment type for components in gas service should be applied for any equipment type other than valves, connectors, flanges, open-ended lines, pressure relief valves, and meters and instruments, as specified in § 98.232(g)(6) and (7).
Table W-5B to Subpart W of Part 98 - Default Methane Population Emission Factors for Liquefied Natural Gas (LNG) Storage
40:23.0.1.1.3.23.1.10.58 :
Table W-5B to Subpart W of Part 98 - Default Methane Population Emission Factors for Liquefied Natural Gas (LNG) Storage| LNG storage | Emission factor (scf/hour/component) |
|---|---|
| Population Emission Factors - LNG Storage Compressor, Gas Service | |
| Vapor Recovery Compressor 1 | 4.17 |
1 Emission Factor is in units of “scf/hour/device.”
Table W-6A to Subpart W of Part 98 - Default Methane Leaker Emission Factors for LNG Import and Export Equipment
40:23.0.1.1.3.23.1.10.59 :
Table W-6A to Subpart W of Part 98 - Default Methane Leaker Emission Factors for LNG Import and Export Equipment| LNG import and export equipment | Emission
factor (scf/hour/component) |
|
|---|---|---|
| If you survey using any of
the methods in § 98.234(a)(1) through (6) |
If you survey using Method 21
as specified in § 98.234(a)(7) |
|
| Leaker Emission Factors - LNG Terminals Components, LNG Service | ||
| Valve | 1.19 | 0.23 |
| Pump Seal | 4.00 | 0.73 |
| Connector | 0.34 | 0.11 |
| Other 1 | 1.77 | 0.99 |
| Leaker Emission Factors - LNG Terminals Components, Gas Service | ||
| Valve 2 | 14.84 | 9.51 |
| Connector | 5.59 | 3.58 |
| Open-Ended Line | 17.27 | 11.07 |
| Pressure Relief Valve | 39.66 | 25.42 |
| Meter and Instrument | 19.33 | 12.39 |
| Other 3 | 4.1 | 2.63 |
1 “Other” equipment type for components in LNG service should be applied for any equipment type other than connectors, pumps, or valves.
2 Valves include control valves, block valves and regulator valves.
3 “Other” equipment type for components in gas service should be applied for any equipment type other than valves, connectors, flanges, open-ended lines, pressure relief valves, and meters and instruments, as specified in § 98.232(h)(7) and (8).
Table W-6B to Subpart W of Part 98 - Default Methane Population Emission Factors for LNG Import and Export Equipment
40:23.0.1.1.3.23.1.10.60 :
Table W-6B to Subpart W of Part 98 - Default Methane Population Emission Factors for LNG Import and Export EquipmentTable W-6B to Subpart W of Part 98 - Default Methane Population Emission Factors for LNG Import and Export Equipment
| LNG import and export equipment | Emission factor (scf/hour/component) |
|---|---|
| Population Emission Factors - LNG Terminals Compressor, Gas Service | |
| Vapor Recovery Compressor 1 | 4.17 |
1 Emission Factor is in units of “scf/hour/compressor.”
Table W-7 to Subpart W of Part 98 - Default Methane Emission Factors for Natural Gas Distribution
40:23.0.1.1.3.23.1.10.61 :
Table W-7 to Subpart W of Part 98 - Default Methane Emission Factors for Natural Gas Distribution| Natural gas distribution | Emission factor
(scf/hour/ component) |
|---|---|
| Leaker Emission Factors - Transmission-Distribution Transfer Station 1 Components, Gas Service | |
| Connector | 1.69 |
| Block Valve | 0.557 |
| Control Valve | 9.34 |
| Pressure Relief Valve | 0.27 |
| Orifice Meter | 0.212 |
| Regulator | 0.772 |
| Open-ended Line | 26.131 |
| Population Emission Factors - Below Grade Metering-Regulating station 1 Components, Gas Service 2 | |
| Below Grade M&R Station, Inlet Pressure >300 psig | 1.30 |
| Below Grade M&R Station, Inlet Pressure 100 to 300 psig | 0.20 |
| Below Grade M&R Station, Inlet Pressure <100 psig | 0.10 |
| Population Emission Factors - Distribution Mains, Gas Service 3 | |
| Unprotected Steel | 12.58 |
| Protected Steel | 0.35 |
| Plastic | 1.13 |
| Cast Iron | 27.25 |
| Population Emission Factors - Distribution Services, Gas Service 4 | |
| Unprotected Steel | 0.19 |
| Protected Steel | 0.02 |
| Plastic | 0.001 |
| Copper | 0.03 |
1 Excluding customer meters.
2 Emission Factor is in units of “scf/hour/station.”
3 Emission Factor is in units of “scf/hour/mile.”
4 Emission Factor is in units of “scf/hour/number of services.”
Table Z-1 to Subpart Z of Part 98 - Default Chemical Composition of Phosphate Rock by Origin
40:23.0.1.1.3.26.1.10.62 :
Table Z-1 to Subpart Z of Part 98 - Default Chemical Composition of Phosphate Rock by Origin| Origin | Total carbon (percent by weight) |
|---|---|
| Central Florida | 1.6 |
| North Florida | 1.76 |
| North Carolina (Calcined) | 0.76 |
| Idaho (Calcined) | 0.60 |
| Morocco | 1.56 |
Table AA-1 to Subpart AA of Part 98 - Kraft Pulping Liquor Emissions Factors for Biomass-Based CO2, CH4, and N2O
40:23.0.1.1.3.27.1.10.63 :
Table AA-1 to Subpart AA of Part 98 - Kraft Pulping Liquor Emissions Factors for Biomass-Based CO2, CH4, and N2O| Wood furnish | Biomass-based
emissions factors (kg/mmBtu HHV) |
||
|---|---|---|---|
| a CO2 | CH4 | N2O | |
| North American Softwood | 94.4 | 0.0019 | 0.00042 |
| North American Hardwood | 93.7 | 0.0019 | 0.00042 |
| Bagasse | 95.5 | 0.0019 | 0.00042 |
| Bamboo | 93.7 | 0.0019 | 0.00042 |
| Straw | 95.1 | 0.0019 | 0.00042 |
a Includes emissions from both the recovery furnace and pulp mill lime kiln.
Table AA-2 to Subpart AA of Part 98 - Kraft Lime Kiln and Calciner Emissions Factors for CH4 and N2O
40:23.0.1.1.3.27.1.10.64 :
Table AA-2 to Subpart AA of Part 98 - Kraft Lime Kiln and Calciner Emissions Factors for CH4 and N2O| Fuel | Fossil fuel-based emissions factors (kg/mmBtu HHV) | |||
|---|---|---|---|---|
| Kraft rotary lime kilns | Kraft calciners a | |||
| CH4 | N2O | CH4 | N2O | |
| Residual Oil (any type) | 0.0027 | 0 | 0.0027 | 0.0003 |
| Distillate Oil (any type) | 0.0027 | 0 | 0.0027 | 0.0004 |
| Natural Gas | 0.0027 | 0 | 0.0027 | 0.0001 |
| Biogas | 0.0027 | 0 | 0.0027 | 0.0001 |
| Petroleum coke | 0.0027 | 0 | b NA | b NA |
| Other Fuels | See Table C-2 | 0 | See Table C-2 | See Table C-2 |
a Includes, for example, fluidized bed calciners at kraft mills.
b Emission factors for kraft calciners are not available.
Table HH-1 to Subpart HH of Part 98 - Emissions Factors, Oxidation Factors and Methods
40:23.0.1.1.3.34.1.10.65 :
Table HH-1 to Subpart HH of Part 98 - Emissions Factors, Oxidation Factors and Methods| Factor | Default value | Units |
|---|---|---|
| DOC and k values - Bulk waste option | ||
| DOC (bulk waste) | 0.20 | Weight fraction, wet basis. |
| k (precipitation plus recirculated leachate a <20 inches/year) | 0.02 | yr −1 |
| k (precipitation plus recirculated leachate a 20-40 inches/year) | 0.038 | yr −1 |
| k (precipitation plus recirculated leachate a >40 inches/year) | 0.057 | yr −1 |
| DOC and k values - Modified bulk MSW option | ||
| DOC (bulk MSW, excluding inerts and C&D waste) | 0.31 | Weight fraction, wet basis. |
| DOC (inerts, e.g., glass, plastics, metal, concrete) | 0.00 | Weight fraction, wet basis. |
| DOC (C&D waste) | 0.08 | Weight fraction, wet basis. |
| k (bulk MSW, excluding inerts and C&D waste) | 0.02 to 0.057 b | yr −1 |
| k (inerts, e.g., glass, plastics, metal, concrete) | 0.00 | yr −1 |
| k (C&D waste) | 0.02 to 0.04 b | yr −1 |
| DOC and k values - Waste composition option | ||
| DOC (food waste) | 0.15 | Weight fraction, wet basis. |
| DOC (garden) | 0.2 | Weight fraction, wet basis. |
| DOC (paper) | 0.4 | Weight fraction, wet basis. |
| 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. | |
| DOCF | 0.5 | |
| F | 0.5 | |
| OX | See Table HH-4 of this subpart | |
| DE | 0.99 | |
a Recirculated leachate (in inches/year) is the total volume of leachate recirculated from company records or engineering estimates divided by the area of the portion of the landfill containing waste with appropriate unit conversions. 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.
Table HH-2 to Subpart HH of Part 98 - U.S. Per Capita Waste Disposal Rates
40:23.0.1.1.3.34.1.10.66 :
Table HH-2 to Subpart HH of Part 98 - U.S. Per Capita Waste Disposal Rates| Year | Waste per capita ton/cap/yr |
|---|---|
| 1950 | 0.63 |
| 1951 | 0.63 |
| 1952 | 0.63 |
| 1953 | 0.63 |
| 1954 | 0.63 |
| 1955 | 0.63 |
| 1956 | 0.63 |
| 1957 | 0.63 |
| 1958 | 0.63 |
| 1959 | 0.63 |
| 1960 | 0.63 |
| 1961 | 0.64 |
| 1962 | 0.64 |
| 1963 | 0.65 |
| 1964 | 0.65 |
| 1965 | 0.66 |
| 1966 | 0.66 |
| 1967 | 0.67 |
| 1968 | 0.68 |
| 1969 | 0.68 |
| 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 | 0.98 |
| 2006 | 0.95 |
| 2007 | 0.95 |
| 2008 | 0.95 |
| 2009 and all later years | 0.95 |
Table HH-3 to Subpart HH of Part 98 - Landfill Gas Collection Efficiencies
40:23.0.1.1.3.34.1.10.67 :
Table HH-3 to Subpart HH of Part 98 - Landfill Gas Collection Efficiencies| Description | Landfill Gas Collection Efficiency |
|---|---|
| A1: Area with no waste in-place | Not applicable; do not use this area in the calculation. |
| A2: Area without active gas collection, regardless of cover type | CE2: 0%. |
| A3: Area with daily soil cover and active gas collection | CE3: 60%. |
| A4: Area with an intermediate soil cover, or a final soil cover not meeting the criteria for A5 below, and active gas collection | CE4: 75%. |
| A5: Area with a final soil cover of 3 feet or thicker of clay or final cover (as approved by the relevant agency) and/or geomembrane cover system and active gas collection | CE5: 95%. |
| Weighted average collection efficiency for landfills: | |
| Area weighted average collection efficiency for landfills | CEave1 = (A2*CE2 + A3*CE3 + A4*CE4 + A5*CE5) / (A2 + A3 + A4 + A5). |
Table HH-4 to Subpart HH of Part 98 - Landfill Methane Oxidation Fractions
40:23.0.1.1.3.34.1.10.68 :
Table HH-4 to Subpart HH of Part 98 - Landfill Methane Oxidation Fractions| Under these conditions: | Use this landfill methane
oxidation fraction: |
|---|---|
| I. For all reporting years prior to the 2013 reporting year | |
| C1: For all landfills regardless of cover type or methane flux | 0.10 |
| II. For the 2013 reporting year and all subsequent years | |
| C2: For landfills that have a geomembrane (synthetic) cover or other non-soil barrier meeting the definition of final cover with less than 12 inches of cover soil for greater than 50% of the landfill area containing waste | 0.0 |
| C3: For landfills that do not meet the conditions in C2 above and for which you elect not to determine methane flux | 0.10 |
| C4: For landfills that do not meet the conditions in C2 or C3 above and that do not have final cover, or intermediate or interim cover a for greater than 50% of the landfill area containing waste | 0.10 |
| C5: For landfills that do not meet the conditions in C2 or C3 above and that have final cover, or intermediate or interim cover a for greater than 50% of the landfill area containing waste and for which the methane flux rate b is less than 10 grams per square meter per day (g/m 2/d) | 0.35 |
| C6: For landfills that do not meet the conditions in C2 or C3 above and that have final cover or intermediate or interim cover a for greater than 50% of the landfill area containing waste and for which the methane flux rate b is 10 to 70 g/m 2/d | 0.25 |
| C7: For landfills that do not meet the conditions in C2 or C3 above and that have final cover or intermediate or interim cover a for greater than 50% of the landfill area containing waste and for which the methane flux rate b is greater than 70 g/m 2/d | 0.10 |
a Where a landfill is located in a state that does not have an intermediate or interim cover requirement, the landfill must have soil cover of 12 inches or greater in order to use an oxidation fraction of 0.25 or 0.35.
b 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:
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). GCH4 =
Modeled methane generation rate in reporting year from Equation
HH-1 of this subpart or Equation TT-1 of subpart TT of this part,
as applicable, except for application with Equation HH-6 of this
subpart (metric tons CH4). For application with Equation HH-6 of
this subpart, the greater of the modeled methane generation rate in
reporting year from Equation HH-1 of this subpart or Equation TT-1
of this part, as applicable, and the quantity of recovered CH4 from
Equation HH-4 of this subpart (metric tons CH4). CE = Collection
efficiency estimated at landfill, taking into account system
coverage, operation, and cover system materials from Table HH-3 of
this subpart. If area by soil cover type information is not
available, use default value of 0.75 (CE4 in table HH-3 of this
subpart) for all areas under active influence of the collection
system. N = Number of landfill gas measurement locations
(associated with a destruction device or gas sent off-site). If a
single monitoring location is used to monitor volumetric flow and
CH4 concentration of the recovered gas sent to one or multiple
destruction devices, then N = 1. Rn = Quantity of recovered CH4
from Equation HH-4 of this subpart for the nth measurement location
(metric tons). fRec,n = Fraction of hours the recovery system
associated with the nth measurement location was operating (annual
operating hours/8760 hours per year or annual operating hours/8784
hours per year for a leap year). [78 FR 71971, Nov. 29, 2013, as
amended at 81 FR 89266, Dec. 9, 2016]Table II-1 to Subpart II of Part 98 - Emission Factors
40:23.0.1.1.3.35.1.10.69 :
Table II-1 to Subpart II of Part 98 - Emission Factors| Factors | Default value | Units |
|---|---|---|
| B0 - for facilities monitoring COD | 0.25 | Kg CH4/kg COD |
| B0 - for facilities monitoring BOD5 | 0.60 | Kg CH4/kg BOD5 |
| MCF - anaerobic reactor | 0.8 | Fraction. |
| MCF - anaerobic deep lagoon (depth more than 2 m) | 0.8 | Fraction. |
| MCF - anaerobic shallow lagoon (depth less than 2 m) | 0.2 | Fraction. |
Table II-2 to Subpart II of Part 98 - Collection Efficiencies of Anaerobic Processes
40:23.0.1.1.3.35.1.10.70 :
Table II-2 to Subpart II of Part 98 - Collection Efficiencies of Anaerobic Processes| Anaerobic process type | Cover type | Methane collection efficiency |
|---|---|---|
| Covered anaerobic lagoon (biogas capture) | Bank to bank, impermeable | 0.975 |
| Modular, impermeable | 0.70 | |
| Anaerobic sludge digester; anaerobic reactor | Enclosed Vessel | 0.99 |
Table JJ-1 to Subpart JJ of Part 98 - Animal Population Threshold Level Below Which Facilities Are Not Required To Report Emissions Under Subpart JJ 1 2
40:23.0.1.1.3.36.1.10.71 :
Table JJ-1 to Subpart JJ of Part 98 - Animal Population Threshold Level Below Which Facilities Are Not Required To Report Emissions Under Subpart JJ 1 2| Animal group | Average annual animal population (Head) 3 |
|---|---|
| Beef | 29,300 |
| Dairy | 3,200 |
| Swine | 34,100 |
| Poultry: | |
| Layers | 723,600 |
| Broilers | 38,160,000 |
| Turkeys | 7,710,000 |
1 The threshold head populations in this table were calculated using the most conservative assumptions (high VS and N values, maximum ambient temperatures, and the application of an uncertainty factor) to ensure that facilities at or near the 25,000 metric ton CO2e threshold level were not excluded from reporting.
2 For facilities with more than one animal group present refer to § 98.360 (2) to estimate the combined animal group factor (CAGF), which is used to determine if a facility may be required to report.
3 For all animal groups except dairy, the average annual animal population represents the total number of animals present at the facility. For dairy facilities, the average annual animal population represents the number of mature dairy cows present at the facility (note that heifers and calves were included in the emission estimates for dairy facilities using the assumption that the average annual animal population of heifers and calves at dairy facilities are equal to 30 percent of the mature dairy cow average annual animal population, therefore the average annual population for dairy facilities should not include heifers and calves, only dairy cows).
Table JJ-2 to Subpart JJ of Part 98 - Waste Characteristics Data
40:23.0.1.1.3.36.1.10.72 :
Table JJ-2 to Subpart JJ of Part 98 - Waste Characteristics Data| Animal type | Typical animal mass (kg) |
Volatile solids excretion
rate (kg VS/day/1000 kg animal mass) |
Nitrogen excretion rate (kg N/day/1000 kg animal mass) |
Maximum methane generation
potential, Bo (m 3 CH4/kg VS added) |
|---|---|---|---|---|
| Dairy Cows | 604 | See Table JJ-3 | See Table JJ-3 | 0.24 |
| Dairy Heifers | 476 | See Table JJ-3 | See Table JJ-3 | 0.17 |
| Dairy Calves | 118 | 6.41 | 0.30 | 0.17 |
| Feedlot Steers | 420 | See Table JJ-3 | See Table JJ-3 | 0.33 |
| Feedlot heifers | 420 | See Table JJ-3 | See Table JJ-3 | 0.33 |
| Market Swine <60 lbs | 16 | 8.80 | 0.60 | 0.48 |
| Market Swine 60-119 lbs | 41 | 5.40 | 0.42 | 0.48 |
| Market Swine 120-179 lbs | 68 | 5.40 | 0.42 | 0.48 |
| Market Swine >180 lbs | 91 | 5.40 | 0.42 | 0.48 |
| Breeding Swine | 198 | 2.60 | 0.24 | 0.48 |
| Feedlot Sheep | 25 | 9.20 | 0.42 | 0.36 |
| Goats | 64 | 9.50 | 0.45 | 0.17 |
| Horses | 450 | 10.00 | 0.30 | 0.33 |
| Hens >/= 1 yr | 1.8 | 10.09 | 0.83 | 0.39 |
| Pullets | 1.8 | 10.09 | 0.62 | 0.39 |
| Other Chickens | 1.8 | 10.80 | 0.83 | 0.39 |
| Broilers | 0.9 | 15.00 | 1.10 | 0.36 |
| Turkeys | 6.8 | 9.70 | 0.74 | 0.36 |
Table JJ-3 to Subpart JJ of Part 98 - State-Specific Volatile Solids (VS) and Nitrogen (N) Excretion Rates for Cattle
40:23.0.1.1.3.36.1.10.73 :
Table JJ-3 to Subpart JJ of Part 98 - State-Specific Volatile Solids (VS) and Nitrogen (N) Excretion Rates for Cattle| State | Volatile solids excretion rate (kg VS/day/1000 kg animal mass) | Nitrogen excretion rate (kg VS/day/1000 kg animal mass) | ||||||
|---|---|---|---|---|---|---|---|---|
| Dairy cows | Dairy heifers | Feedlot steer | Feedlot heifers | Dairy cows | Dairy heifers | Feedlot steer | Feedlot heifers | |
| Alabama | 8.40 | 8.35 | 4.27 | 4.74 | 0.50 | 0.46 | 0.36 | 0.38 |
| Alaska | 7.30 | 8.35 | 4.15 | 4.58 | 0.45 | 0.46 | 0.35 | 0.37 |
| Arizona | 10.37 | 8.35 | 3.91 | 4.27 | 0.58 | 0.46 | 0.33 | 0.34 |
| Arkansas | 7.59 | 8.35 | 3.98 | 4.35 | 0.46 | 0.46 | 0.33 | 0.35 |
| California | 10.02 | 8.35 | 3.96 | 4.33 | 0.56 | 0.46 | 0.33 | 0.34 |
| Colorado | 10.25 | 8.35 | 3.97 | 4.34 | 0.58 | 0.46 | 0.33 | 0.35 |
| Connecticut | 9.22 | 8.35 | 4.41 | 4.93 | 0.53 | 0.46 | 0.37 | 0.40 |
| Delaware | 8.63 | 8.35 | 4.19 | 4.64 | 0.51 | 0.46 | 0.35 | 0.37 |
| Florida | 8.90 | 8.35 | 4.15 | 4.58 | 0.52 | 0.46 | 0.35 | 0.37 |
| Georgia | 9.07 | 8.35 | 4.18 | 4.63 | 0.53 | 0.46 | 0.35 | 0.37 |
| Hawaii | 7.00 | 8.35 | 4.15 | 4.58 | 0.44 | 0.46 | 0.35 | 0.37 |
| Idaho | 10.11 | 8.35 | 4.03 | 4.42 | 0.57 | 0.46 | 0.34 | 0.35 |
| Illinois | 9.07 | 8.35 | 4.15 | 4.59 | 0.52 | 0.46 | 0.35 | 0.37 |
| Indiana | 9.38 | 8.35 | 3.98 | 4.35 | 0.54 | 0.46 | 0.33 | 0.35 |
| Iowa | 9.46 | 8.35 | 3.93 | 4.28 | 0.54 | 0.46 | 0.33 | 0.34 |
| Kansas | 9.63 | 8.35 | 3.97 | 4.35 | 0.55 | 0.46 | 0.33 | 0.35 |
| Kentucky | 7.89 | 8.35 | 4.20 | 4.65 | 0.48 | 0.46 | 0.35 | 0.37 |
| Louisiana | 7.39 | 8.35 | 4.07 | 4.48 | 0.45 | 0.46 | 0.34 | 0.36 |
| Maine | 8.99 | 8.35 | 4.07 | 4.47 | 0.52 | 0.46 | 0.34 | 0.36 |
| Maryland | 9.02 | 8.35 | 4.05 | 4.45 | 0.52 | 0.46 | 0.34 | 0.35 |
| Massachusetts | 8.63 | 8.35 | 4.15 | 4.58 | 0.51 | 0.46 | 0.35 | 0.37 |
| Michigan | 10.05 | 8.35 | 4.00 | 4.38 | 0.57 | 0.46 | 0.34 | 0.35 |
| Minnesota | 9.17 | 8.35 | 3.89 | 4.24 | 0.53 | 0.46 | 0.33 | 0.34 |
| Mississippi | 8.19 | 8.35 | 4.14 | 4.57 | 0.49 | 0.46 | 0.35 | 0.37 |
| Missouri | 8.02 | 8.35 | 4.08 | 4.49 | 0.48 | 0.46 | 0.34 | 0.36 |
| Montana | 9.03 | 8.35 | 4.23 | 4.69 | 0.52 | 0.46 | 0.36 | 0.38 |
| Nebraska | 9.09 | 8.35 | 3.98 | 4.35 | 0.53 | 0.46 | 0.33 | 0.35 |
| Nevada | 9.65 | 8.35 | 4.07 | 4.48 | 0.55 | 0.46 | 0.34 | 0.36 |
| New Hampshire | 9.44 | 8.35 | 3.94 | 4.30 | 0.54 | 0.46 | 0.33 | 0.34 |
| New Jersey | 8.51 | 8.35 | 3.98 | 4.36 | 0.50 | 0.46 | 0.33 | 0.35 |
| New Mexico | 10.34 | 8.35 | 3.88 | 4.22 | 0.58 | 0.46 | 0.32 | 0.33 |
| New York | 9.42 | 8.35 | 3.75 | 4.05 | 0.54 | 0.46 | 0.31 | 0.32 |
| North Carolina | 9.38 | 8.35 | 4.20 | 4.65 | 0.55 | 0.46 | 0.35 | 0.37 |
| North Dakota | 8.40 | 8.35 | 3.88 | 4.22 | 0.50 | 0.46 | 0.32 | 0.34 |
| Ohio | 9.01 | 8.35 | 3.96 | 4.33 | 0.52 | 0.46 | 0.33 | 0.34 |
| Oklahoma | 8.58 | 8.35 | 3.98 | 4.35 | 0.50 | 0.46 | 0.33 | 0.35 |
| Oregon | 9.40 | 8.35 | 4.06 | 4.46 | 0.54 | 0.46 | 0.34 | 0.36 |
| Pennsylvania | 9.26 | 8.35 | 3.98 | 4.35 | 0.53 | 0.46 | 0.33 | 0.35 |
| Rhode Island | 8.94 | 8.35 | 4.36 | 4.87 | 0.52 | 0.46 | 0.37 | 0.39 |
| South Carolina | 9.05 | 8.35 | 4.15 | 4.58 | 0.53 | 0.46 | 0.35 | 0.37 |
| South Dakota | 9.45 | 8.35 | 4.01 | 4.39 | 0.54 | 0.46 | 0.34 | 0.35 |
| Tennessee | 8.60 | 8.35 | 4.48 | 5.02 | 0.51 | 0.46 | 0.38 | 0.40 |
| Texas | 9.51 | 8.35 | 3.95 | 4.32 | 0.54 | 0.46 | 0.33 | 0.34 |
| Utah | 9.70 | 8.35 | 3.88 | 4.22 | 0.55 | 0.46 | 0.32 | 0.34 |
| Vermont | 9.03 | 8.35 | 4.10 | 4.52 | 0.52 | 0.46 | 0.34 | 0.36 |
| Virginia | 9.02 | 8.35 | 3.98 | 4.35 | 0.53 | 0.46 | 0.33 | 0.35 |
| Washington | 10.36 | 8.35 | 4.07 | 4.47 | 0.58 | 0.46 | 0.34 | 0.36 |
| West Virginia | 8.13 | 8.35 | 4.65 | 5.25 | 0.48 | 0.46 | 0.40 | 0.42 |
| Wisconsin | 9.34 | 8.35 | 3.95 | 4.31 | 0.54 | 0.46 | 0.33 | 0.34 |
| Wyoming | 9.29 | 8.35 | 4.17 | 4.61 | 0.53 | 0.46 | 0.35 | 0.37 |
Table JJ-4 to Subpart JJ of Part 98 - Volatile Solids and Nitrogen Removal through Solids Separation
40:23.0.1.1.3.36.1.10.74 :
Table JJ-4 to Subpart JJ of Part 98 - Volatile Solids and Nitrogen Removal through Solids Separation| Type of solids separation | Volatile solids removal (decimal) | Nitrogen removal (decimal) |
|---|---|---|
| Gravity | 0.60 | 0.60 |
| Mechanical: | ||
| Stationary Screen | 0.20 | 0.10 |
| Vibrating Screen | 0.15 | 0.15 |
| Screw Press | 0.25 | 0.15 |
| Centrifuge | 0.50 | 0.25 |
| Roller drum | 0.25 | 0.15 |
| Belt press/screen | 0.50 | 0.30 |
Table JJ-6 to Subpart JJ of Part 98 - Collection Efficiencies of Anaerobic Digesters
40:23.0.1.1.3.36.1.10.75 :
Table JJ-6 to Subpart JJ of Part 98 - Collection Efficiencies of Anaerobic Digesters| Anaerobic digester type | Cover type | Methane collection efficiency |
|---|---|---|
| Covered anaerobic lagoon (biogas capture) | Bank to bank, impermeable | 0.975 |
| Modular, impermeable | 0.70 | |
| Complete mix, fixed film, or plug flow digester | Enclosed Vessel | 0.99 |
Table JJ-7 to Subpart JJ of Part 98 - Nitrous Oxide Emission Factors (kg N2O-N/kg Kjdl N)
40:23.0.1.1.3.36.1.10.76 :
Table JJ-7 to Subpart JJ of Part 98 - Nitrous Oxide Emission Factors (kg N2O-N/kg Kjdl N)| Manure management system component | N2O emission factor |
|---|---|
| Uncovered anaerobic lagoon | 0 |
| Liquid/Slurry (with crust cover) | 0.005 |
| Liquid/Slurry (without crust cover) | 0 |
| Storage pits | 0.002 |
| Digesters | 0 |
| Solid manure storage | 0.005 |
| Dry lots (including feedlots) | 0.02 |
| High-rise house for poultry (poultry without litter) | 0.001 |
| Poultry production with litter | 0.001 |
| Deep bedding for cattle and swine (active mix) | 0.07 |
| Deep bedding for cattle and swine (no mix) | 0.01 |
| Manure Composting (in vessel) | 0.006 |
| Manure Composting (intensive) | 0.1 |
| Manure Composting (passive) | 0.01 |
| Manure Composting (static) | 0.006 |
| Aerobic Treatment (forced aeration) | 0.005 |
| Aerobic Treatment (natural aeration) | 0.01 |
Table MM-1 to Subpart MM of Part 98 - Default Factors for Petroleum Products and Natural Gas Liquids 1 2
40:23.0.1.1.3.39.1.10.77 :
Table MM-1 to Subpart MM of Part 98 - Default Factors for Petroleum Products and Natural Gas Liquids 1 2| Products | Column A: density (metric tons/bbl) |
Column B: carbon share (% of mass) |
Column C: emission factor (metric tons CO2/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 |
| 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 (a.k.a. Bunker C) | 0.1528 | 84.67 | 0.4744 |
| Kerosene-Type Jet Fuel | 0.1294 | 86.30 | 0.4095 |
| Kerosene | 0.1346 | 86.40 | 0.4264 |
| Diesel - Other | 0.1452 | 86.47 | 0.4604 |
| Petrochemical Feedstocks | |||
| Naphthas (<401 °F) | 0.1158 | 84.11 | 0.3571 |
| Other Oils (>401 °F) | 0.1390 | 87.30 | 0.4450 |
| Unfinished Oils | |||
| Heavy Gas Oils | 0.1476 | 85.80 | 0.4643 |
| Residuum | 0.1622 | 85.70 | 0.5097 |
| Other Petroleum Products and Natural Gas Liquids | |||
| Aviation Gasoline | 0.1120 | 85.00 | 0.3490 |
| Special Naphthas | 0.1222 | 84.76 | 0.3798 |
| Lubricants | 0.1428 | 85.80 | 0.4492 |
| Waxes | 0.1285 | 85.30 | 0.4019 |
| Petroleum Coke | 0.1818 | 92.28 | 0.6151 |
| Asphalt and Road Oil | 0.1634 | 83.47 | 0.5001 |
| Still Gas | 0.1405 | 77.70 | 0.4003 |
| Ethane 3 | 0.0579 | 79.89 | 0.170 |
| Ethylene 4 | 0.0492 | 85.63 | 0.154 |
| Propane 3 | 0.0806 | 81.71 | 0.241 |
| Propylene 3 | 0.0827 | 85.63 | 0.260 |
| Butane 3 | 0.0928 | 82.66 | 0.281 |
| Butylene 3 | 0.0972 | 85.63 | 0.305 |
| Isobutane 3 | 0.0892 | 82.66 | 0.270 |
| Isobutylene 3 | 0.0949 | 85.63 | 0.298 |
| Isobutylene | 0.0936 | 85.63 | 0.2939 |
| Pentanes Plus | 0.1055 | 83.63 | 0.3235 |
| Miscellaneous Products | 0.1380 | 85.49 | 0.4326 |
1 In the case of products blended with some portion of biomass-based fuel, the carbon share in Table MM-1 of this subpart represents only the petroleum-based components.
2 Products that are derived entirely from 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 60 degrees Fahrenheit and saturation pressure (LPGs other than ethylene).
4 The density and emission factor for ethylene determined at 41 degrees Fahrenheit and saturation pressure.
Table MM-2 to Subpart MM of Part 98 - Default Factors for Biomass-Based Fuels and Biomass
40:23.0.1.1.3.39.1.10.78 :
Table MM-2 to Subpart MM of Part 98 - Default Factors for Biomass-Based Fuels and Biomass| Biomass-based fuel and biomass | Column A: Density (metric tons/bbl) |
Column B: Carbon share (% of mass) |
Column C: Emission factor (metric tons CO2/bbl) |
|---|---|---|---|
| Ethanol (100%) | 0.1267 | 52.14 | 0.2422 |
| Biodiesel (100%, methyl ester) | 0.1396 | 77.30 | 0.3957 |
| Rendered Animal Fat | 0.1333 | 76.19 | 0.3724 |
| Vegetable Oil | 0.1460 | 76.77 | 0.4110 |
Table NN-1 to Subpart NN of Part 98 - Default Factors for Calculation Methodology 1 of This Subpart
40:23.0.1.1.3.40.1.10.79 :
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 CO2 emission factor (kg CO2/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 MMBtu/bbl are 60 °F and saturation pressure.
Table NN-2 to Subpart NN of Part 98 - Default Factors for Calculation Methodology 2 of This Subpart
40:23.0.1.1.3.40.1.10.80 :
Table NN-2 to Subpart NN of Part 98 - Default Factors for Calculation Methodology 2 of This Subpart| Fuel | Unit | Default CO2 emission
factor (MT CO2/Unit) 1 |
|---|---|---|
| Natural Gas | Mscf | 0.0544 |
| Propane | Barrel | 0.241 |
| Normal butane | Barrel | 0.281 |
| Ethane | Barrel | 0.170 |
| Isobutane | Barrel | 0.270 |
| Pentanes plus | Barrel | 0.324 |
1 Conditions for emission value presented in MT CO2/bbl are 60 °F and saturation pressure.
Table TT-1 to Subpart TT of Part 98 - Default DOC and Decay Rate Values for Industrial Waste Landfills
40:23.0.1.1.3.46.1.10.81 :
Table TT-1 to Subpart TT of Part 98 - Default DOC and Decay Rate Values for Industrial Waste Landfills| Industry/Waste Type | DOC (weight fraction, wet basis) |
k [dry climate a] (yr−1) |
k [moderate climate a] (yr−1) |
k [wet climate a] (yr−1) |
|---|---|---|---|---|
| Food Processing (other than industrial sludge) | 0.22 | 0.06 | 0.12 | 0.18 |
| Pulp and Paper Industry: | ||||
| Pulp and paper wastes segregated into separate streams: | ||||
| Boiler Ash | 0.06 | 0.02 | 0.03 | 0.04 |
| Wastewater Sludge | 0.12 | 0.02 | 0.04 | 0.06 |
| Kraft Recovery Wastes b | 0.025 | 0.02 | 0.03 | 0.04 |
| Other Pulp and Paper Wastes (not otherwise listed) | 0.20 | 0.02 | 0.03 | 0.04 |
| Pulp and paper wastes not segregated into separate streams: | ||||
| Pulp and paper manufacturing wastes, general (other than industrial sludge) | 0.15 | 0.02 | 0.03 | 0.04 |
| Wood and Wood Product (other than industrial sludge) | 0.43 | 0.02 | 0.03 | 0.04 |
| Construction and Demolition | 0.08 | 0.02 | 0.03 | 0.04 |
| Industrial Sludge c | 0.09 | 0.02 | 0.04 | 0.06 |
| Inert Waste [i.e., wastes listed in § 98.460(c)(2)] | 0 | 0 | 0 | 0 |
| Other Industrial Solid Waste (not otherwise listed) | 0.20 | 0.02 | 0.04 | 0.06 |
a The applicable climate classification is determined based on the annual rainfall plus the recirculated leachate application rate. Recirculated leachate application rate (in inches/year) is the total volume of leachate recirculated from company records or engineering estimates and applied to the landfill divided by the area of the portion of the landfill containing waste [with appropriate unit conversions].
Dry climate = precipitation plus recirculated leachate less than 20 inches/year;
Moderate climate = precipitation plus recirculated leachate from 20 to 40 inches/year (inclusive);
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.
b Kraft Recovery Wastes include green liquor dregs, slaker grits, and lime mud, which may also be referred to collectively as causticizing or recausticizing wastes.
c A facility that can segregate out pulp and paper industry wastewater sludge must apply the 0.12 DOC value to that portion of the sludge.