The designated representative or alternate designated representative must sign (i.e., agree to) this certification statement. If you are an agent and you click on "SUBMIT", you are not agreeing to the certification statement, but are submitting the certification statement on behalf of the designated representative or alternate designated representative who is agreeing to the certification statement. An agent is only authorized to make the electronic submission on behalf of the designated representative, not to sign (i.e., agree to) the certification statement. 2022 519991 Subpart W Test Facility 1710 SAIC Dr McLean VA 20010 N 221210 SAIC 1710 SAIC Dr. Virigina VA 22102 100 322551.4 0 0 N Carbon Dioxide 233195.9 Methane 3570.86 Nitrous Oxide 0.282 2 Onshore petroleum and natural gas production [98.230(a)(2)] Sample workbook for Onshore petroleum and natural gas production 233195.9 322551.4 3570.86 0.282 Onshore Production [98.236(aa)(1)] Yes Facility Overview [98.236(aa)(2-11)] No Natural Gas Pneumatic Devices [98.236(b)] Yes 53.3 773.90 Natural Gas Driven Pneumatic Pumps [98.236(c)] Yes 142.0 51.85 Acid Gas Removal Units [98.236(d)] Yes 182427.1 Dehydrators [98.236(e)] Yes 162.7 348.24 0.010 Well Venting for Liquids Unloading [98.236(f)] Yes 7.5 320.01 Completions and Workovers with Hydraulic Fracturing [98.236(g)] Yes 2077.3 171.30 0.010 Completions and Workovers without Hydraulic Fracturing [98.236(h)] Yes 242.7 445.10 0.100 Blowdown Vent Stacks [98.236(i)] No 0.0 0.00 Atmospheric Storage Tanks [98.236(j)] Yes 128.6 119.68 0.001 Transmission Storage Tanks [98.236(k)] No 0.0 0.00 0.000 Well Testing [98.236(l)] Yes 3627.5 56.19 0.010 Associated Gas Venting and Flaring [98.236(m)] Yes 3630.0 126.40 0.010 Flare Stacks [98.236(n)] Yes 13960.4 76.70 0.071 Centrifugal Compressors [98.236(o)] Yes 111.5 921.60 Reciprocating Compressors [98.236(p)] Yes 4.5 29.67 Equipment Leaks Surveys and Population Counts [98.236(q,r)] Yes 47.5 129.70 Offshore Petroleum and Natural Gas Production [98.236(s)] No 0.0 0.00 0.000 Enhanced Oil Recovery Injection Pumps [98.236(w)] Yes 186.8 Enhanced Oil Recovery Hydrocarbon Liquids [98.236(x)] Yes 246.5 Combustion Equipment at Onshore Petroleum and Natural Gas Production Facilities, Onshore Petroleum and Natural Gas Gathering and Boosting Facilities, and Natural gas Distribution Facilities [98.236(z)] Yes 26140.0 0.53 0.070 100 - New England Province 3000500002 Depth of the Well (feet) N/A (i.e., activity data parameters that are determined but not measured) Engineering estimate based on best available data 30-009-00001 Flow volume during the separation period, FVs,p Weekly 200 Calculated from averaging flow volume before and after missing operating log entry 91000000 53000000 5500000 BERKSHIRE, MA (3) Oil 100 - BERKSHIRE, MA (3) - Oil 55 500 102 7 2 1 1 0 0.7 0.3 BRISTOL, MA (5) Shale gas 100 - BRISTOL, MA (5) - Shale gas 2 1 1 1 1 0.8 0.2 ESSEX, MA (9) Coal seam 100 - ESSEX, MA (9) - Coal seam 5 1 1 3 2 0.7 0.3 30-003-00001 Not Applicable 100 - BERKSHIRE, MA (3) - Oil Producing Acquired Not applicable Completed Not applicable Calculation Methodology 2 [98.233(f)(2)] Completions Horizontal No No Gas Equation W-10B 13 16 Completions No No W-17B No No No No 30-003-00001 Yes Workovers Horizontal No No Gas Equation W-10B 2 3 No completions/workover without hydraulic fracturing reporting required for this well per 98.236(h) 3000500001 Not Applicable 100 - BRISTOL, MA (5) - Shale gas Producing Acquired Not applicable Completed Not applicable Calculation Methodology 3 [98.233(f)(3)] No completions/workover with hydraulic fracturing reporting required for this well per 98.236(g) Completions No Yes No well testing reporting required for this well per 98.236(l) No associated gas reporting required for this well per 98.236(m) 3000500002 Not Applicable 100 - BRISTOL, MA (5) - Shale gas Producing Not applicable Divested Not applicable Out of Production Calculation Methodology 1 [98.233(f)(1)] - Tested Well <1 inch, <25 psig Yes 65 5 45 1 No completions/workover with hydraulic fracturing reporting required for this well per 98.236(g) Completions Yes Yes W-17A Yes Yes Yes No 30-009-00001 Not Applicable 100 - ESSEX, MA (9) - Coal seam Producing Acquired Not applicable Not applicable Not applicable Calculation Methodology 2 [98.233(f)(2)] Completions Vertical Yes Yes Oil Equation W-10A, measured well, and Equation W-12C No 75 66 Workovers Yes No W-17B No Yes No Yes 88 30-009-00002 Not Applicable 100 - ESSEX, MA (9) - Coal seam Producing Not applicable Divested Not applicable Out of Production Calculation Methodology 3 [98.233(f)(3)] Workovers Horizontal No No Gas Equation W-10A, calculated well Completions No Yes No well testing reporting required for this well per 98.236(l) No associated gas reporting required for this well per 98.236(m) 30-009-00003 Not Applicable 100 - ESSEX, MA (9) - Coal seam Producing Not applicable Not applicable Completed Not applicable Calculation Methodology 2 and 3 [98.233(f)(2-3)] Completions Vertical Yes Yes Oil Equation W-10A, measured well, and Equation W-12C No 85 77 No completions/workover without hydraulic fracturing reporting required for this well per 98.236(h) W-17A No Yes Yes Yes 99 30-003-00002 Not Applicable 100 - BERKSHIRE, MA (3) - Oil Producing Acquired Divested Not applicable Not applicable Calculation Methodology 1 [98.233(f)(1)] - Tested Well >1 inch and <2.375 inches, >25 psig and <60 psig No 77 10 500 2 No completions/workover with hydraulic fracturing reporting required for this well per 98.236(g) Workovers No No W-17B No Yes No No 30-009-00004 Not Applicable 100 - ESSEX, MA (9) - Coal seam Producing Not applicable Not applicable Completed Not applicable Calculation Methodology 1 [98.233(f)(1)] - Calculated Well >1 inch and <2.375 inches, >25 psig and <60 psig No Completions Vertical No No Gas Equation W-10A, calculated well Workovers No Yes No well testing reporting required for this well per 98.236(l) No associated gas reporting required for this well per 98.236(m) 30-009-00005 Not Applicable 100 - ESSEX, MA (9) - Coal seam Producing Not applicable Not applicable Completed Out of Production No liquids unloading reporting required for this well per 98.236(f) Completions Horizontal Yes Yes Oil Equation W-10B 13 16 No completions/workover without hydraulic fracturing reporting required for this well per 98.236(h) W-17A Yes No Yes Yes 30-009-00005 Yes No liquids unloading reporting required for this well per 98.236(f) Completions Horizontal Yes Yes Oil Equation W-10B 22 44 No completions/workover without hydraulic fracturing reporting required for this well per 98.236(h) W-17A Yes No Yes Yes 30-009-00005 Yes No liquids unloading reporting required for this well per 98.236(f) Workovers Horizontal Yes Yes Oil Equation W-10B 100 120 No completions/workover without hydraulic fracturing reporting required for this well per 98.236(h) W-17A Yes No Yes Yes Yes 53.3 773.90 Yes Yes Yes Yes High-bleed Pneumatic Devices 31 Yes First 47 131 28 8760 3 Intermittent Bleed Pneumatic Devices 388 Yes First 6 640 0 8760 388 Low-Bleed Pneumatic Devices 18 Yes First 0.3 2.9 0 8008 18 High-bleed Pneumatic Devices Concentration of CO2 in produced or processed natural gas Quarterly 3 Estimated from subsequent month that monitoring device was working Intermittent Bleed Pneumatic Devices Concentration of CH4 in produced or processed natural gas Hourly 20 Average of the concentration from quarter before and quarter after Total count of natural gas driven pneumatic pumps Quarterly 2 Averaged count from quarter before and quarter after Concentration of CO2 in produced natural gas Daily 50 Substituted next availble measurement of Co2 142.0 51.85 No Yes Natural Gas Driven Pneumatic Pumps 142.042 51.84859 24 8460 AGR test 4 Annual volume of gas vented from the acid gas removal unit Continuous 100 Averaged measurements from 100 hours before and after the missing hours AGR test 5 Volume fraction of CO2 used to calculate the annual average fraction of CO2 content in the vent from the acid gas removal unit Quarterly 1 Averaged quarterly measurements taken before and after the missing quarter 182427.1 Yes Yes AGR test 4 100 - BERKSHIRE, MA (3) - Oil 16585 Calculation Methodology 1 [98.233(d)(1)] No 1613.8449801 AGR test 5 100 - BRISTOL, MA (5) - Shale gas 23338 Calculation Methodology 2 [98.233(d)(2)] No 76960 AGR test 6 100 - ESSEX, MA (9) - Coal seam 11160 Calculation Methodology 4 [98.233(d)(4)] Yes 16540 AGR test 7A 100 - BERKSHIRE, MA (3) - Oil 19715 Calculation Methodology 3 [98.233(d)(3)] Yes 11138.6573577 AGR test 7B 100 - BERKSHIRE, MA (3) - Oil 19715 Calculation Methodology 3 [98.233(d)(3)] Yes 76174.6020119 AGR test 4 0.865 35469900 AGR test 5 1 1096050000 Actual 70 20 AGR test 7A W-4A 0.15 0.05 1971500000 Actual 60 15 AGR test 7B W-4B 0.0065 0 87600000000 Standard 30 35 AGR test 6 API 4679 AmineCalc 95 1075 21100 3.8 0 8760 95 1075 95 120 8 Desiccant Dehydrator Number of desiccant dehydrators venting to vapor recovery Annually Reviewed operational records and previous year reporting to estimate number Small Glycol Dehydrator Number of small glycol dehydrators venting to other control devices (specify) Quarterly 1 Calculated based on activity data from following quarter Large Glycol Dehydrator Dehydrator test 10 For Calculation Method 3, concentration of CO2 in produced or processed natural gas (mole fraction) Weekly 180 Calculated from averaging measurements before and after device malfunction 162.7 348.24 0.010 Yes Yes Yes Yes 5 4 Yes 2 Yes 6 Yes 10 0.1 0 0.1 4 Yes 2 Yes 2 Yes 3.4 0.04 0 0.1 0.2 Dehydrator test 8 100 - BERKSHIRE, MA (3) - Oil 27.1 301.4 18 76 7 Natural gas pneumatic Yes Yes 1 Triethylene glycol (TEG) 8760 77 300 0.01 0.96 Yes No Yes Dehydrator test 9 100 - BRISTOL, MA (5) - Shale gas 115 0.5 0.01 30 79 7 Air pneumatic No No 1 Diethylene glycol (DEG) 8760 105 900 0.01 0.93 No Yes No Dehydrator test 10 100 - ESSEX, MA (9) - Coal seam 7 42 1 44 2 Electric Yes Yes 1 Ethylene glycol (EG) 8760 90 1005 0.02 0.95 Yes No Yes BTEX Condenser 3 Vapor Recovery 2 1 100 - BERKSHIRE, MA (3) - Oil >1 inch and <2.375 inches, >110 psig and <200 psig Cumulative amount of time wells were vented (hours) Quarterly 2 Calculated from averaging measurements before and after device malfunction 100 - BRISTOL, MA (5) - Shale gas >1 inch and <2.375 inches, >200 psig Number of wells vented for liquids unloading Monthly 8760 Calculated from averaging measurements before and after device malfunction 7.5 320.01 Yes Yes Yes Yes Yes 100 - BERKSHIRE, MA (3) - Oil >1 inch and <2.375 inches, >110 psig and <200 psig Yes 0 38 2 14 7825 1 0.12 100 - BRISTOL, MA (5) - Shale gas >1 inch and <2.375 inches, >200 psig No 0 55 68 68 853950 0 16 100 - ESSEX, MA (9) - Coal seam >1 inch and <2.375 inches, <25 psig Yes 0 38 38 38 1189800 0.4 18 100 - BERKSHIRE, MA (3) - Oil Calculation Methodology 3 [98.233(f)(3)] Yes 4 31 370770 0.1 6.89 2.4 100 - BRISTOL, MA (5) - Shale gas Calculation Methodology 2 [98.233(f)(2)] No 5 21 14396000 4 273 7.8 100 - ESSEX, MA (9) - Coal seam Calculation Methodology 3 [98.233(f)(3)] Yes 21 273 332680 2 6 2.2 2077.3 171.30 0.010 Yes Yes 100 - BERKSHIRE, MA (3) - Oil Vertical Yes Yes Oil 3 Equation W-10A Yes 25184150 1660 8 0 100 - BRISTOL, MA (5) - Shale gas Horizontal No No Gas 2 Equation W-10A No 350 135 9291000 2.4 130 100 - ESSEX, MA (9) - Coal seam Vertical Yes No Oil 6 Equation W-10B 5684500 400 2 0 100 - BERKSHIRE, MA (3) - Oil Vertical Yes Yes Oil 1 Equation W-10A No 65 0 533762 13 4 0 100 - BRISTOL, MA (5) - Shale gas Horizontal No Yes Gas 1 Equation W-10B 1587500 1.4 27 100 - ESSEX, MA (9) - Coal seam Vertical Yes No Oil 5 Equation W-10A No 47 47 676500 0.5 0.3 0.01 100 - BERKSHIRE, MA (3) - Oil Vertical No No Oil Workover Equation W-10A Volume of N2 injected gas Weekly 200 Calculated from averaging measurements before and after device malfunction 100 - BERKSHIRE, MA (3) - Oil Vertical No No Oil Workover Equation W-10A Cumulative workover gas flow back time, Sum of Tp,s values (hours) Quarterly 4 Calculated based on activity data from following quarter 100 - BERKSHIRE, MA (3) - Oil Vertical No No Oil Completion Equation W-10B Volume of N2 injected gas Biannually Calculated from averaging measurements before and after device malfunction 100 - BERKSHIRE, MA (3) - Oil Completion Vertical No No 200 400 10000 20-003-00001 242.7 445.10 0.100 Yes Yes 100 - BRISTOL, MA (5) - Shale gas 3 384 No 40900 5 110 100 - BRISTOL, MA (5) - Shale gas 12 1463 No 195200 0 320 100 - ESSEX, MA (9) - Coal seam 1 29 Yes 0 11 100 - BRISTOL, MA (5) - Shale gas 1 90 Yes 12 0.1 0 100 - BRISTOL, MA (5) - Shale gas 3 3 No 2210 0.3 0 0 100 - ESSEX, MA (9) - Coal seam 1 40 Yes 225 1 0.1 100 - BRISTOL, MA (5) - Shale gas No 51 0.1 0 0 100 - BRISTOL, MA (5) - Shale gas No 2 0.1 0 0 100 - ESSEX, MA (9) - Coal seam Yes 46 0.1 3 3 0.1 0 0 100 - ESSEX, MA (9) - Coal seam Completion Without Flaring Annual gas production volume (scf), used to determine Vp Other measurement frequency 20 Calculated from averaging measurements before and after device malfunction 100 - ESSEX, MA (9) - Coal seam Workover With Flaring Total count of workovers that vented gas to the atmosphere without flaring Annually Count taken at nex available time early in the subsequent year 100 - BRISTOL, MA (5) - Shale gas Completion With Flaring Flow rate during first 30 days of production (scf/hr), used to determine Vp Quarterly 3 Calculated based on activity data from following quarter 100 - BERKSHIRE, MA (3) - Oil Separator or non-separator equipment oil composition Quarterly 2 Calculated based on activity data from following quarter 100 - BRISTOL, MA (5) - Shale gas Total time the dump valves did not close properly, Tn (hours) Daily 500 Calculated from averaging measurements before and after device malfunction 128.6 119.68 0.001 Yes Yes Yes Yes Yes Yes 100 - BERKSHIRE, MA (3) - Oil Calculation Methodology 1 E&P Tanks 7 111 38 45 1 2 7 0.49 0.68 0 0.01 0.3 33.96 10 0.1 0.001 No 62415 1 2 0.1 0.2 Yes Yes Yes 7 4 100 - BRISTOL, MA (5) - Shale gas Calculation Methodology 2 44 97 26 106 50 0.2 0.355 0.05 0.08 1.2 50.5 No 59000 No Yes No 50 0 100 - ESSEX, MA (9) - Coal seam Calculation Methodology 1 Pack 2 73 96 27 107 51 0.615 0.695 0.05 0.1 0.01 0.02 Yes No Yes No 51 3 100 - BERKSHIRE, MA (3) - Oil 22 3.2 1.8 100 - BRISTOL, MA (5) - Shale gas 9 1.32552 2.9 100 - ESSEX, MA (9) - Coal seam 31 4.56568 10.47552 100 - BERKSHIRE, MA (3) - Oil 21 35 0.6 0 100 - BRISTOL, MA (5) - Shale gas 17 71 1.1 0 100 - ESSEX, MA (9) - Coal seam 4 0.7 0.01 0 100 - BERKSHIRE, MA (3) - Oil 3 7 0.3 4 100 - BRISTOL, MA (5) - Shale gas 16 29 0.9 14 100 - ESSEX, MA (9) - Coal seam 5 87 0 0.01 0.38 0 104 104 0 No 362000 100 - BERKSHIRE, MA (3) - Oil 25200 13322 30-003-00002 100 - BRISTOL, MA (5) - Shale gas 26660 10120 30-005-00001 100 - ESSEX, MA (9) - Coal seam 21388 55900 30-009-00004 Annual production rate for well(s) tested (cubic feet per day), used to calculate averages W-17A Vented Quarterly 3 Calculated based on activity data from following quarter Mole fraction of CH4 in natural gas W-17B Flared Daily 40 Calculated from averaging measurements before and after device malfunction 3627.5 Yes 56.19 0.010 Yes W-17A Vented 2 621 7 No 100 Actual 102 65 1.5 41 W-17B Flared 9 1 No 11563000 Standard 60 15 3625.9664967 15.19 0.0098973 W-17A 100 500 Actual 102 65 test 5 W-17B 15630000 12000000 100 - BERKSHIRE, MA (3) - Oil Mole fraction of CH4 in natural gas Quarterly 2 Calculated based on activity data from following quarter 100 - BRISTOL, MA (5) - Shale gas Mole fraction of CO2 in natural gas Weekly 300 Calculated from averaging measurements before and after device malfunction 3630.0 126.40 0.010 Yes Yes 100 - BERKSHIRE, MA (3) - Oil Vented No 117 13029 1 137 0 0.21 100 - BRISTOL, MA (5) - Shale gas Flared No 158600 90146000 20 1399 3625.9664967 26.19 0.0098973 100 - ESSEX, MA (9) - Coal seam Vented Yes 2 2761 4 100 100 - ESSEX, MA (9) - Coal seam 117 13029 2000300001 13960.4 76.70 0.071 Yes Yes Stack 10 Yes 3015.8 Stack 11 Yes No No 20820063 0.98 0.8933 0.01971 0 980.3038053 7.1418479 0.0025713 Stack 12 No Yes No 114010000 0.98 0.7944 0.05227 0 4982.1381761 34.7787049 0.034203 Stack 13 - Assc NG Flare No No No 80140069 0.98 0.8511 0.0261 0 0 0 0 Stack 14 - Workover with HF Yes 0 Stack 15- Workover with HF Yes 0 Stack 16 - Completion with HF Yes 0 Stack 17 - Completion WC with HF Yes 0 Stack 18 - Completion without HF Yes 0 Stack 19 - Completion without HF Yes 0 Stack 20 - Completion without HF Yes 0 Stack 21 - Workover without HF Yes 0 Stack 22 - Workover without HF Yes 0 Stack 23 - Workover without HF Yes 0 Stack 24 - Production Tank Yes 0 Stack 25 - Production Tank Yes 0 Stack 26 - Production Tank Yes 0 Stack 27 -Assoc Gas No Yes No 114010000 0.98 0.7944 0.05227 0 4982.1381761 34.7787049 0.034203 Stacl 28 - Well Testing No No No 80140069 0.98 0.8511 0.0261 0 0 0 0 Count of Centrifugal Compressors Semiannually 3000 Calculated from averaging measurements before and after device malfunction Count of Centrifugal Compressors Quarterly 3 Calculated based on activity data from following quarter 111.5 921.60 Yes Yes 111.5 921.6 4 Count of Reciprocating Compressors Quarterly 3 Calculated based on activity data from following quarter Count of Reciprocating Compressors Monthly 8760 Calculated from averaging measurements before and after device malfunction 4.5 29.67 Yes Yes 4.5 29.67 163 Gas Service - Valves Eastern U.S. Total number of emission source type, Counte Quarterly 3 Calculated using measurements from following quarter Gas Service - Connectors Western U.S. Concentration of CO2 in produced natural gas Weekly 8760 Calculated from averaging measurements before and after device malfunction Wellhead Eastern U.S. Count of Major Equipment Type Quarterly 3 Calculated using measurements from following quarter Separator Western U.S. Count of Major Equipment Type Weekly 8400 Calculated from averaging measurements before and after device malfunction Onshore Production or GB Components, Gas Service - Valve Onshore Production or GB Components, Gas Service - Valve Onshore Production or GB Components, Gas Service - Valve Concentration of CO2 in the feed natural gas Quarterly 3 Calculated using measurements from following quarter Onshore Production or GB Components, Gas Service - Flange Onshore Production or GB Components, Gas Service - Flange Onshore Production or GB Components, Gas Service - Flange Concentration of CH4 in the feed natural gas Weekly 8760 Calculated from averaging measurements before and after device malfunction 47.5 129.70 Yes Yes Yes Yes 1 Yes No No No No No Component Count Method 1 Gas Service - Valves Eastern U.S. 312 8760 0.8 1.13 Gas Service - Connectors Eastern U.S. 1434 8760 0.4 0.58 Gas Service - Open ended lines Eastern U.S. 36 8760 0.2023728 0.3 Gas Service - Pressure relief valves Western U.S. 200 1100 0.22 0.815 Light crude service - Valves Western U.S. 2000 8700 4.58 16.7 Light crude service - Flanges Western U.S. 30000 8700 4.12 15 Light crude service - Connectors Western U.S. 30000 8700 9.61 35 Light crude service - Open ended lines Eastern U.S. 1500 8700 3.43 12.5 Light crude service - Pumps Eastern U.S. 200 1100 0.01 0.04 Light crude service - Other equipment leak sources (such as instruments, loading arms, stuffing boxes, compressor seals, dump lever arms, breather caps) Eastern U.S. 200 1100 10.3 1.27 Heavy crude service - Valves Eastern U.S. 350 8760 0.0080636 0.0264902 Heavy crude service - Flanges Eastern U.S. 300 8760 0.012441 0.0408707 Heavy crude service - Connectors Eastern U.S. 250 8760 0.0034558 0.011353 Heavy crude service - Open ended lines Eastern U.S. 200 8760 0.0552931 0.1816474 Heavy crude service - Other equipment leak sources (such as instruments, loading arms, stuffing boxes, compressor seals, dump lever arms, breather caps) Eastern U.S. 150 8760 0.0207349 0.0681178 Wellhead Yes 8 3 Separators No Meters/piping Yes 2 Compressors No In-line heaters Yes 16 Dehydrators No Wellhead Yes 822 Separators No Heater-treater Yes 193 Header No Onshore Production or GB Components, Gas Service - Valve 200 500 2.58 9.408 Onshore Production or GB Components, Gas Service - Flange 10 40 0.01 0.0028 Onshore Production or GB Components, Gas Service - Connector (other) 20 100 0.01 0.00499 Onshore Production or GB Components, Gas Service - Open-Ended Line 18 4000 1.060416 3.483648 Onshore Production or GB Components, Gas Service - Pressure Relief Valve 17 4000 1.60956 5.28768 Onshore Production or GB Components, Gas Service - Pump Seal 16 4000 1.245568 4.091904 Onshore Production or GB Components, Gas Service - Other 15 4000 1.4202 4.6656 Onshore Production or GB Components, Light Crude Service - Valve 14 4000 0.942592 3.096576 Onshore Production or GB Components, Light Crude Service - Flange 13 4000 0.738504 2.426112 Onshore Production or GB Components, Light Crude Service - Connector (other) 12 4000 0.25248 0.82944 Onshore Production or GB Components, Light Crude Service - Open-Ended Line 11 4000 0.370304 1.216512 Onshore Production or GB Components, Light Crude Service - Pump 10 4000 0.77848 2.55744 Onshore Production or GB Components, Light Crude Service - Agitator Seal 9 4000 0.700632 2.301696 Onshore Production or GB Components, Light Crude Service - Other 8 4000 0.521792 1.714176 Onshore Production or GB Components, Heavy Crude Service - Valve 7 4000 0.471296 1.548288 Onshore Production or GB Components, Heavy Crude Service - Flange 6 4000 0.340848 1.119744 Onshore Production or GB Components, Heavy Crude Service - Connector (other) 5 4000 0.1052 0.3456 Onshore Production or GB Components, Heavy Crude Service - Open-Ended Line 4 4000 0.134656 0.442368 Onshore Production or GB Components, Heavy Crude Service - Pump 3 4000 0.233544 0.767232 Onshore Production or GB Components, Heavy Crude Service - Agitator Seal 2 4000 0.155696 0.511488 Onshore Production or GB Components, Heavy Crude Service - Other 1 4000 0.065224 0.214272 Pump 1 100 - BERKSHIRE, MA (3) - Oil Total volume of EOR injection pump system equipment chambers (cubic feet) Quarterly 3 Calculated using measurements from following quarter Pump 1 100 - BERKSHIRE, MA (3) - Oil Number of blowdowns per year Weekly 200 Calculated from averaging measurements before and after device malfunction 186.8 Yes Yes Yes 100 - BERKSHIRE, MA (3) - Oil Pump 1 520 185.8 3440 2 27 1 100 - BRISTOL, MA (5) - Shale gas Pump 2 3300 1 4900 2 0.1 1 100 - ESSEX, MA (9) - Coal seam Pump 3 8000 0 60 0 0.1 0.9 100 - BERKSHIRE, MA (3) - Oil Volume of hydrocarbon liquid produced (barrels per year) Quarterly 3 Calculated using measurements from following quarter 100 - BERKSHIRE, MA (3) - Oil Average CO2 retained in hydrocarbon liquids (mt CO2 per barrel) Weekly 8760 Calculated from averaging measurements before and after device malfunction 246.5 Yes Yes 100 - BERKSHIRE, MA (3) - Oil 246.5 1232627 0.0002 External fuel combustion units with a rated heat capacity greater than 5 mmBtu/hr Field gas, process gas, and/or natural gas that is not of pipeline quality Quantity of fuel combusted in calendar year Weekly 8760 Calculated from averaging measurements before and after device malfunction Internal fuel combustion units that are not compressor-drivers, with a rated heat capacity greater than 1 mmBtu/hr Natural gas (pipeline quality) Concentration of C2 hydrocarbons in gas sent to unit Quarterly 3 Calculated using measurements from following quarter 26140.0 0.53 0.070 Yes Yes Yes Yes 370 Yes Yes No External fuel combustion units with a rated heat capacity greater than 5 mmBtu/hr Natural gas (pipeline quality) 440700 thousand standard cubic feet 24150 0.45 0.05 Internal fuel combustion units that are not compressor-drivers, with a rated heat capacity greater than 1 mmBtu/hr Petroleum products: distillate fuel oil No. 1 195000 gallons 1990 0.08 0.02 2022-01-01 2022-12-31 2022-12-13T11:36:26