Address: 1717 Main Street Suite 5200
City: Dallas
State: TX
Postal Code: 75201

CO2 equivalent emissions from facility subparts C-II, SS, and TT (metric tons):61,678.8
CO2 equivalent emissions from supplier subparts LL-QQ (metric tons):
Biogenic CO2 emissions from facility subparts C-II, SS, and TT (metric tons):0
Cogeneration Unit Emissions Indicator:N
GHG Report Start Date:2020-01-01
GHG Report End Date:2020-12-31
Description of Changes to Calculation Methodology:
Plant Code Indicator:N
Primary NAICS Code:211130
Second Primary NAICS Code:

Parent Company Details:

Subpart W: Petroleum and Natural Gas Systems

SubpartWSummaryDetails:

Industry Segment Number	9
Industry Segment Name	Onshore petroleum and natural gas gathering and boosting [98.230(a)(9)]
Total Reported CO2 Emissions (mt CO2)	37652.9
Total CO2e Emissions (mt CO2e)	61678.7
Total Reported CH4 Emissions (mt CH4)	960.19
Total Reported N2O Emissions (mt N2O)	0.071

SubpartWSourceReportingFormRowDetails:

Source Reporting Form	Onshore Production [98.236(aa)(1)]
Required for Selected Industry Segment	No
Source Reporting Form	Facility Overview [98.236(aa)(2-11)]
Required for Selected Industry Segment	Yes
Source Reporting Form	Natural Gas Pneumatic Devices [98.236(b)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	18.0
Total Reported CH4 Emissions (mt CH4)	278.47
Source Reporting Form	Natural Gas Driven Pneumatic Pumps [98.236(c)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	4.8
Total Reported CH4 Emissions (mt CH4)	75.97
Source Reporting Form	Acid Gas Removal Units [98.236(d)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	0.0
Source Reporting Form	Dehydrators [98.236(e)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	3.4
Total Reported CH4 Emissions (mt CH4)	3.56
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Well Venting for Liquids Unloading [98.236(f)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Source Reporting Form	Completions and Workovers with Hydraulic Fracturing [98.236(g)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Completions and Workovers without Hydraulic Fracturing [98.236(h)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Blowdown Vent Stacks [98.236(i)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	7.4
Total Reported CH4 Emissions (mt CH4)	118.74
Source Reporting Form	Atmospheric Storage Tanks [98.236(j)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	365.9
Total Reported CH4 Emissions (mt CH4)	0.43
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Transmission Storage Tanks [98.236(k)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Well Testing [98.236(l)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Associated Gas Venting and Flaring [98.236(m)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Flare Stacks [98.236(n)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	111.2
Total Reported CH4 Emissions (mt CH4)	0.46
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Centrifugal Compressors [98.236(o)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Source Reporting Form	Reciprocating Compressors [98.236(p)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	0.7
Total Reported CH4 Emissions (mt CH4)	4.37
Source Reporting Form	Equipment Leaks Surveys and Population Counts [98.236(q,r)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	14.8
Total Reported CH4 Emissions (mt CH4)	477.50
Source Reporting Form	Offshore Petroleum and Natural Gas Production [98.236(s)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Enhanced Oil Recovery Injection Pumps [98.236(w)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Source Reporting Form	Enhanced Oil Recovery Hydrocarbon Liquids [98.236(x)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Source Reporting Form	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)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	37126.7
Total Reported CH4 Emissions (mt CH4)	0.70
Total Reported N2O Emissions (mt N2O)	0.070

FacilityOverviewDetails:


FacilityOverviewOnshorePetroleumAndNaturalGasGatheringAndBoostingRowDetails:

Select the basin associated with this facility [98.236(a)(9)]	220 - Gulf Coast Basin (LA, TX)
Quantity of gas received by the gathering and boosting facility in the calendar year (thousand standard cubic feet) [98.236(aa)(10)(i)]	15690672
Quantity of gas transported to a natural gas processing facility, a natural gas transmission pipeline, a natural gas distribution pipeline, or another gathering and boosting facility in the calendar year (thousand standard cubic feet) [98.236(aa)(10)(ii)]	14880503
Quantity of all hydrocarbon liquids received by the gathering and boosting facility in the calendar year (barrels) [98.236(aa)(10)(iii)]	0
Quantity of all hydrocarbon liquids transported to a natural gas processing facility, a natural gas transmission pipeline, a natural gas distribution pipeline, or another gathering and boosting facility in the calendar year (barrels) [98.236(aa)(10)(iv)]	6629

PneumaticDeviceVentingDetails:

mt CO2	18.0
mt CH4	278.47
Did the Facility have any continuous high-bleed pneumatic devices subject to reporting under 98.232 [98.236(b)]?	No
Did the Facility have any intermittent bleed pneumatic devices subject to reporting under 98.232 [98.236(b)]?	Yes
Did the Facility have any continuous low-bleed pneumatic devices subject to reporting under 98.232 [98.236(b)]?	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

PneumaticDeviceTypesRowDetails:

Type of Pneumatic Device	High-bleed Pneumatic Devices
Type of Pneumatic Device	Intermittent Bleed Pneumatic Devices
Total Number, Countt [98.236(b)(1)(i)]	168
Is the Total Number estimated? (Yes / No) [98.236(b)(1)(ii)]	No
Total CO2 Emissions (mt CO2) [98.236(b)(3)]	17.98542
Total CH4 Emissions (mt CH4) [98.236(b)(4)]	278.4674
Estimated average number of hours in the calendar year that the pneumatic devices were operating, Tt (hours) [98.236(b)(2)]	8784
Type of Pneumatic Device	Low-Bleed Pneumatic Devices

NaturalGasDrivenPneumaticPumpsDetails:

mt CO2	4.8
mt CH4	75.97
Did the Facility have any natural gas driven pneumatic pumps subject to reporting under 98.232 [98.236(c)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

PneumaticPumpTypesRowDetails:

Type of Pneumatic Pump	Natural Gas Driven Pneumatic Pumps
Total count of natural gas driven pneumatic pumps, Count [98.236(c)(1)]	46
Average estimated number of hours in the calendar year that the natural gas driven pneumatic pumps were operated, T (hours) [98.236(c)(2)]	8784
Total CO2 Emissions (mt CO2) [98.236(c)(3)]	4.815838
Total CH4 Emissions (mt CH4) [98.236(c)(4)]	75.966

AcidGasRemovalUnitsDetails:

mt CO2	0.0
Did the Facility have any acid gas removal units that vent directly to the atmosphere, to a flare or engine, or to a sulfur recovery plant subject to reporting under 98.232 [98.236(d)]?	No

DehydratorsDetails:

mt CO2	3.4
mt CH4	3.56
mt N2O	0.000
Did the facility have any glycol dehydrators with annual average daily natural gas throughputs greater than or equal to 0.4MMscfd subject to reporting under 98.232 [98.236(e)]?	Yes
Did the facility have any glycol dehydrators with annual average daily natural gas throughputs less than 0.4MMscfd subject to reporting under 98.232 [98.236(e)]?	No
Did the facility have any desiccant dehydrators subject to reporting under 98.232 [98.236(e)]?	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

SmallGlycolDehydrators:

Emissions vented to flare or regenerator firebox/fire tubes

Emissions that were not vented to a flare or regenerator firebox/fire tubes

DessicantDehydrators:

Emissions vented to flare or regenerator firebox/fire tubes

Emissions that were not vented to a flare or regenerator firebox/fire tubes

GlycolDehydratorsMoreThanSpecifiedValueRowDetails:

Unit ID or Name [98.236(e)(1)(i)]	Barracuda-DEHY-1
County and State [98.236(e)(1)(xviii)]	MC MULLEN, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	6
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	79.84
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	4.28
Glycol dehydrator absorbent circulation pump type [98.236(e)(1)(v)]	Natural gas pneumatic
Dehydrator absorbent circulation rate (gallons per minute) [98.236(e)(1)(vi)]	7.5
Report type of absorbent used [98.236(e)(1)(vii)]	Triethylene glycol (TEG)
Report whether stripper gas is used in glycol dehydrator [98.236(e)(1)(viii)]	No
Report whether a flash tank separator is used in glycol dehydrator [98.236(e)(1)(ix)]	Yes
Total time the glycol dehydrator is operating (hours) [98.236(e)(1)(x)]	8784
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	120
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	1440
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.014
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.65
Were any dehydrator emissions vented to a vapor recovery device? [98.236(e)(1)(xv)]	No
Were any dehydrator emissions vented to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvi)]	No
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	Yes
CO2 Emissions from Venting (mt CO2) [98.236(e)(1)(xvii)(A)]	0.57
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	0.6
Unit ID or Name [98.236(e)(1)(i)]	Comet- DEHY-1
County and State [98.236(e)(1)(xviii)]	FRIO, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	8
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	101.64
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	5.5
Glycol dehydrator absorbent circulation pump type [98.236(e)(1)(v)]	Natural gas pneumatic
Dehydrator absorbent circulation rate (gallons per minute) [98.236(e)(1)(vi)]	9.45
Report type of absorbent used [98.236(e)(1)(vii)]	Triethylene glycol (TEG)
Report whether stripper gas is used in glycol dehydrator [98.236(e)(1)(viii)]	No
Report whether a flash tank separator is used in glycol dehydrator [98.236(e)(1)(ix)]	Yes
Total time the glycol dehydrator is operating (hours) [98.236(e)(1)(x)]	8784
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	120
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	1000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.018
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.7
Were any dehydrator emissions vented to a vapor recovery device? [98.236(e)(1)(xv)]	Yes
Were any dehydrator emissions vented to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvi)]	No
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	Yes
CO2 Emissions from Venting (mt CO2) [98.236(e)(1)(xvii)(A)]	1.01
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	1.06
Unit ID or Name [98.236(e)(1)(i)]	El Dorado-DEHY-1
County and State [98.236(e)(1)(xviii)]	LA SALLE, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	22
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	101.64
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	6.76
Glycol dehydrator absorbent circulation pump type [98.236(e)(1)(v)]	Natural gas pneumatic
Dehydrator absorbent circulation rate (gallons per minute) [98.236(e)(1)(vi)]	9.54
Report type of absorbent used [98.236(e)(1)(vii)]	Triethylene glycol (TEG)
Report whether stripper gas is used in glycol dehydrator [98.236(e)(1)(viii)]	No
Report whether a flash tank separator is used in glycol dehydrator [98.236(e)(1)(ix)]	Yes
Total time the glycol dehydrator is operating (hours) [98.236(e)(1)(x)]	8784
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	120
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	1000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.016
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.75
Were any dehydrator emissions vented to a vapor recovery device? [98.236(e)(1)(xv)]	Yes
Were any dehydrator emissions vented to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvi)]	No
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	Yes
CO2 Emissions from Venting (mt CO2) [98.236(e)(1)(xvii)(A)]	1.82
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	1.9

BlowdownVentStacksDetails:

mt CO2	7.4
mt CH4	118.74
Did the facility have any blowdown vent stacks subject to reporting under 98.232 [98.236(i)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No
How were emissions determined? [98.236(i)]	Combination of flow meters and calculating by equipment or event type

BlowdownEquipmentOrEventEmissionsRowDetails:

Equipment or event type [98.236(i)(1)] [98.236(i)(2)]	Compressors
Total number of blowdowns for equipment or event type, N [98.236(i)(1)(i)]	988
Annual total CO2 emissions for each equipment or event type (mt CO2) [98.236(i)(1)(ii)]	0.41
Annual total CH4 emissions for each equipment or event type (mt CH4) [98.236(i)(1)(iii)]	6.58

BlowdownVentStacksEmissionsRowDetails:

Annual total CO2 emissions calculated by flow meter (mt CO2) [98.236(i)(2)(i)]	6.9758583
Annual total CH4 emissions calculated by flow meter (mt CH4) [98.236(i)(2)(ii)]	112.1593728

AtmosphericTanksDetails:

mt CO2	365.9
mt CH4	0.43
mt N2O	0.000
Did the facility send hydrocarbon liquids to atmospheric storage tanks that are subject to reporting under 98.232 [98.236(j)]?	Yes
Was Calculation Method 1 used to calculate emissions [(98.233(j)(1)]?	No
Was Calculation Method 2 used to calculate emissions [(98.233(j)(2)]?	Yes
Was Calculation Method 3 used to calculate emissions [(98.233(j)(3)]?	Yes
If Calculation Method 1 or 2 were used, were any atmospheric tanks observed to have malfunctioning dump valves during the calendar year?	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

AtmosphericTanksCalculationMethodOneOrTwoSubBasinRowDetails:

County and State [98.236(j)(1)(i)]	MC MULLEN, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	32.9
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	30
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	74.6
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	3
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.124
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.01
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	69.0169131
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.0083851
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.0000543
Total volume of oil sent to tanks from all gas-liquid separators and direct from wells or non-separator equipment (bbl per yr) [98.236(j)(1)(iii)]	5646
Were any emissions from atmospheric tanks controlled with vapor recovery systems? [98.236(j)(1)(xii)]	No
Were any emissions from atmospheric tanks vented directly to the atmosphere? [98.236(j)(1)(xiii)(A)]	No
Were any emissions from atmospheric tanks vented to flare(s)? [98.236(j)(1)(xiv)]	Yes
Count of atmospheric tanks [98.236(j)(1)(x)]	3
County and State [98.236(j)(1)(i)]	LA SALLE, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	100
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	70
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	88.94
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	4
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.0571
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.0279
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	232.5928669
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.0096161
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.0001628
Total volume of oil sent to tanks from all gas-liquid separators and direct from wells or non-separator equipment (bbl per yr) [98.236(j)(1)(iii)]	4639
Were any emissions from atmospheric tanks controlled with vapor recovery systems? [98.236(j)(1)(xii)]	No
Were any emissions from atmospheric tanks vented directly to the atmosphere? [98.236(j)(1)(xiii)(A)]	No
Were any emissions from atmospheric tanks vented to flare(s)? [98.236(j)(1)(xiv)]	Yes
Count of atmospheric tanks [98.236(j)(1)(x)]	4

AtmosphericTanksCalculationMethodThreeRowDetails:

Estimate of fraction of oil/condensate throughput sent to tanks in basin with flaring [98.236(j)(2)(i)(B)]	1
Estimate of fraction of oil/condensate throughput sent to tanks with vapor recovery system control measures [98.236(j)(2)(i)(C)]	0
Count of atmospheric tanks in basin [98.236(j)(2)(i)(D)]	12
Total annual oil/condensate throughput that is sent to all atmospheric tanks (barrels per year) [98.236(j)(2)(i)(A)]	2979

AtmosphericTanksCalcMethodThreeNoFlaringRowDetails:

County and State [98.236(j)(2)(ii)(A)]	FRIO, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	0
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0

AtmosphericTanksCalcMethodThreeWithFlaringRowDetails:

County and State [98.236(j)(2)(iii)(A)]	FRIO, TX
Count of tanks with flaring emission control measures [98.236(j)(2)(iii)(B)]	12
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(2)(iii)(C)]	64.3254253
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(2)(iii)(D)]	0.4124768
Annual N2O emissions from flaring (mt N2O) [98.236(j)(2)(iii)(E)]	0.0001537

FlareStacksDetails:

mt CO2	111.2
mt CH4	0.46
mt N2O	0.000
Did the facility have flare stacks subject to reporting under 98.232 [98.236(n)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

UniqueFlareStacksRowDetails:

Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Barracuda-FL-1
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	No
Does the flare stack have a continuous gas analyzer on gas to the flare? [98.236(n)(3)]	No
Were CEMS used to measure CO2 emissions for the flare stack? [98.233(n)(8)] [98.236(n)(12)]	No
Volume of gas sent to flare, Vs (standard cubic feet) [98.236(n)(4)]	42270.15
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.6575
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0146
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	3.0943324
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.0106724
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000052
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Comet- FL-1
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	No
Does the flare stack have a continuous gas analyzer on gas to the flare? [98.236(n)(3)]	No
Were CEMS used to measure CO2 emissions for the flare stack? [98.233(n)(8)] [98.236(n)(12)]	No
Volume of gas sent to flare, Vs (standard cubic feet) [98.236(n)(4)]	62514.62
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.6722
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0181
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	5.1424371
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.0161366
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000077
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Corvair- FL-1
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	No
Does the flare stack have a continuous gas analyzer on gas to the flare? [98.236(n)(3)]	No
Were CEMS used to measure CO2 emissions for the flare stack? [98.233(n)(8)] [98.236(n)(12)]	No
Volume of gas sent to flare, Vs (standard cubic feet) [98.236(n)(4)]	252437.9
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.7276
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0152
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	18.6371293
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.0705307
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000312
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Cyclone- FL-1
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	No
Does the flare stack have a continuous gas analyzer on gas to the flare? [98.236(n)(3)]	No
Were CEMS used to measure CO2 emissions for the flare stack? [98.233(n)(8)] [98.236(n)(12)]	No
Volume of gas sent to flare, Vs (standard cubic feet) [98.236(n)(4)]	319.9837
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.7685
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0152
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	0.0218828
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.0000944
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	El Dorado- FL-1
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	No
Does the flare stack have a continuous gas analyzer on gas to the flare? [98.236(n)(3)]	No
Were CEMS used to measure CO2 emissions for the flare stack? [98.233(n)(8)] [98.236(n)(12)]	No
Volume of gas sent to flare, Vs (standard cubic feet) [98.236(n)(4)]	814902.1
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.752
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.016
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	57.8345046
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.2353176
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0001006
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Hornet-FL-1
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	No
Does the flare stack have a continuous gas analyzer on gas to the flare? [98.236(n)(3)]	No
Were CEMS used to measure CO2 emissions for the flare stack? [98.233(n)(8)] [98.236(n)(12)]	No
Volume of gas sent to flare, Vs (standard cubic feet) [98.236(n)(4)]	198424.9
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.8346
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0124
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	12.5992805
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.0635925
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000245
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Urban-FL-1
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	No
Does the flare stack have a continuous gas analyzer on gas to the flare? [98.236(n)(3)]	No
Were CEMS used to measure CO2 emissions for the flare stack? [98.233(n)(8)] [98.236(n)(12)]	No
Volume of gas sent to flare, Vs (standard cubic feet) [98.236(n)(4)]	126522.8
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.7694
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0157
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	8.7108475
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.0373811
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000156
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Oppenheimer-FL-1
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	No
Does the flare stack have a continuous gas analyzer on gas to the flare? [98.236(n)(3)]	No
Were CEMS used to measure CO2 emissions for the flare stack? [98.233(n)(8)] [98.236(n)(12)]	No
Volume of gas sent to flare, Vs (standard cubic feet) [98.236(n)(4)]	91482.92
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.7522
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0248
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	5.1323761
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.0264244
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000113

CentrifugalCompressorsDetails:

mt CO2	0.0
mt CH4	0.00
Did the facility have any centrifugal compressors subject to reporting under 98.232 [98.236(o)]?	No

ReciprocatingCompressorsDetails:

mt CO2	0.7
mt CH4	4.37
Did the facility have any reciprocating compressors subject to reporting under 98.232 [98.236(p)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No
Total annual Reciprocating Compressor emissions CO2 Emissions (mt CO2) [98.236(p)(5)(ii)]	0.7
Total annual Reciprocating Compressor emissions CH4 Emissions (mt CH4) [98.236(p)(5)(iii)]	4.37
Count of Reciprocating Compressors [98.236(p)(5)(i)]	24

OtherEmissionsFromEquipmentLeaksDetails:

mt CO2	14.8
mt CH4	477.50
Did this facility use leak surveys to calculate emissions from equipment leaks in accordance with 98.232 [per 98.236(q)]?	No
Did this facility use population counts to calculate emissions from equipment leaks in accordance with 98.232 [per 98.236(r)]?	Yes
Did the facility elect to comply with 98.236(q) according to 98.233(q)(1)(iv) for any components at the facility [per 98.236(q)(1)(iv)]?	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No
Component count calculation method for all emission source types in Table R.1 other than gathering pipelines [98.236(r)(3)(i)]	Component Count Method 1

LeaksCalculatedWithCountsFactorsRowDetails:

Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Gas Service - Valves
Geographic Location (according to Table W-1D) [98.236(r)(1)(i)]	Western U.S.
Total number of emission source type, Counte (for gathering pipelines, this value is the number of miles of pipeline per material type) [98.236(r)(1)(ii)]	10422
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	8784
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	6.4092498
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	207.3645963
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Gas Service - Connectors
Geographic Location (according to Table W-1D) [98.236(r)(1)(i)]	Western U.S.
Total number of emission source type, Counte (for gathering pipelines, this value is the number of miles of pipeline per material type) [98.236(r)(1)(ii)]	34048
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	8784
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	2.9417874
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	95.1784656
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Gas Service - Open ended lines
Geographic Location (according to Table W-1D) [98.236(r)(1)(i)]	Western U.S.
Total number of emission source type, Counte (for gathering pipelines, this value is the number of miles of pipeline per material type) [98.236(r)(1)(ii)]	1060
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	8784
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	0.1670084
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	5.4033827
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Gas Service - Pressure relief valves
Geographic Location (according to Table W-1D) [98.236(r)(1)(i)]	Western U.S.
Total number of emission source type, Counte (for gathering pipelines, this value is the number of miles of pipeline per material type) [98.236(r)(1)(ii)]	672
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	8784
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	0.6591699
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	21.3267537
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Gathering pipelines - Protected steel gathering pipeline
Geographic Location (according to Table W-1D) [98.236(r)(1)(i)]	Western U.S.
Total number of emission source type, Counte (for gathering pipelines, this value is the number of miles of pipeline per material type) [98.236(r)(1)(ii)]	791.3
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	8784
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	1.8902088
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	61.1557357
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Gathering pipelines - Unprotected steel gathering pipeline
Geographic Location (according to Table W-1D) [98.236(r)(1)(i)]	Western U.S.
Total number of emission source type, Counte (for gathering pipelines, this value is the number of miles of pipeline per material type) [98.236(r)(1)(ii)]	0
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	8784
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	0
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	0
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Gathering pipelines - Plastic/composite gathering pipeline
Geographic Location (according to Table W-1D) [98.236(r)(1)(i)]	Western U.S.
Total number of emission source type, Counte (for gathering pipelines, this value is the number of miles of pipeline per material type) [98.236(r)(1)(ii)]	211.8
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	8784
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	2.6911427
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	87.0691162
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Gathering pipelines - Cast iron gathering pipeline
Geographic Location (according to Table W-1D) [98.236(r)(1)(i)]	Western U.S.
Total number of emission source type, Counte (for gathering pipelines, this value is the number of miles of pipeline per material type) [98.236(r)(1)(ii)]	0
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	8784
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	0
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	0

MajorGasEquipmentTypeRowDetails:

Major Equipment Type [98.236(r)(3)(ii)]	Wellhead
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	No
Major Equipment Type [98.236(r)(3)(ii)]	Separators
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	Yes
Count of Major Equipment Type in Western US [98.236(r)(3)(ii)(B)]	103
Major Equipment Type [98.236(r)(3)(ii)]	Meters/piping
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	Yes
Count of Major Equipment Type in Western US [98.236(r)(3)(ii)(B)]	364
Major Equipment Type [98.236(r)(3)(ii)]	Compressors
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	Yes
Count of Major Equipment Type in Western US [98.236(r)(3)(ii)(B)]	24
Major Equipment Type [98.236(r)(3)(ii)]	In-line heaters
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	No
Major Equipment Type [98.236(r)(3)(ii)]	Dehydrators
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	Yes
Count of Major Equipment Type in Western US [98.236(r)(3)(ii)(B)]	4

CombustionEmissionsDetails:

mt CO2	37126.7
mt CH4	0.70
mt N2O	0.070
Did the Facility have combustion units subject to reporting under 98.232?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No
Are there external fuel combustion units with a rated heat capacity less than or equal to 5 mmBtu/hr? [98.236(z)(1)(i)]	No
Are there internal fuel combustion units that are not compressor-drivers, with a rated heat capacity less than or equal to 1 mmBtu/hr? [98.236(z)(1)(i)]	No
Are there external fuel combustion units with a rated heat capacity greater than 5 mmBtu/hr? [98.236(z)(2)(i)]	Yes
Are there internal fuel combustion units that are not compressor-drivers, with a rated heat capacity greater than 1 mmBtu/hr? [98.236(z)(2)(i)]	No
Are there Internal fuel combustion units of any heat capacity that are compressor-drivers? [98.236(z)(2)(i)]	No

LargeCombustionUnitEmissionsRowDetails:

Type of combustion unit [98.236(z)(2)(i)]	External fuel combustion units with a rated heat capacity greater than 5 mmBtu/hr
Type of fuel combusted [98.236(z)(2)(ii)]	Natural gas (pipeline quality)
Quantity of fuel combusted in calendar year [98.236(z)(2)(iii)]	681981
Unit of measure [98.236(z)(2)(iii)	thousand standard cubic feet
CO2 Emissions (mt CO2) [98.236(z)(2)(iv)]	37126.7455684
CH4 Emissions (mt CH4) [98.236(z)(2)(v)]	0.6997125
N2O Emissions (mt N2O) [98.236(z)(2)(vi)]	0.0699713