GHG Summary Report

CO2 equivalent emissions from facility subparts C-II, SS, and TT (metric tons):495,514
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:486210
Second Primary NAICS Code:

Parent Company Details:

Parent Company Name:ENTERPRISE PRODUCTS PARTNERS LP
Address:1100 Louisiana Street, Houston, TX 77002
Percent Ownership Interest:100

Subpart W: Petroleum and Natural Gas Systems

Gas Information Details

Gas Name	Carbon Dioxide
Gas Quantity	375,166.8 (Metric Tons)
Own Result?

Gas Name	Methane
Gas Quantity	4,805.64 (Metric Tons)
Own Result?

Gas Name	Nitrous Oxide
Gas Quantity	0.692 (Metric Tons)
Own Result?

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)	375166.8
Total CO2e Emissions (mt CO2e)	495513.8
Total Reported CH4 Emissions (mt CH4)	4805.64
Total Reported N2O Emissions (mt N2O)	0.692

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)	34.5
Total Reported CH4 Emissions (mt CH4)	1073.25
Source Reporting Form	Natural Gas Driven Pneumatic Pumps [98.236(c)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	1.8
Total Reported CH4 Emissions (mt CH4)	55.15
Source Reporting Form	Acid Gas Removal Units [98.236(d)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	2266.6
Source Reporting Form	Dehydrators [98.236(e)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	8874.8
Total Reported CH4 Emissions (mt CH4)	187.28
Total Reported N2O Emissions (mt N2O)	0.001
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)	2.9
Total Reported CH4 Emissions (mt CH4)	128.96
Source Reporting Form	Atmospheric Storage Tanks [98.236(j)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	1835.1
Total Reported CH4 Emissions (mt CH4)	6.43
Total Reported N2O Emissions (mt N2O)	0.002
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)	23290.4
Total Reported CH4 Emissions (mt CH4)	72.46
Total Reported N2O Emissions (mt N2O)	0.050
Source Reporting Form	Centrifugal Compressors [98.236(o)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	250.9
Total Reported CH4 Emissions (mt CH4)	2073.60
Source Reporting Form	Reciprocating Compressors [98.236(p)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	1.7
Total Reported CH4 Emissions (mt CH4)	11.10
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)	38.3
Total Reported CH4 Emissions (mt CH4)	1191.02
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)	338569.9
Total Reported CH4 Emissions (mt CH4)	6.38
Total Reported N2O Emissions (mt N2O)	0.638

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)]	620717160
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)]	639067871
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)]	0

PneumaticDeviceVentingDetails:

mt CO2	34.5
mt CH4	1073.25
Did the Facility have any continuous high-bleed pneumatic devices subject to reporting under 98.232 [98.236(b)]?	Yes
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)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

PneumaticDeviceTypesRowDetails:

Type of Pneumatic Device	High-bleed Pneumatic Devices
Total Number, Countt [98.236(b)(1)(i)]	93
Is the Total Number estimated? (Yes / No) [98.236(b)(1)(ii)]	No
Total CO2 Emissions (mt CO2) [98.236(b)(3)]	15.9564188
Total CH4 Emissions (mt CH4) [98.236(b)(4)]	496.0006262
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	Intermittent Bleed Pneumatic Devices
Total Number, Countt [98.236(b)(1)(i)]	287
Is the Total Number estimated? (Yes / No) [98.236(b)(1)(ii)]	No
Total CO2 Emissions (mt CO2) [98.236(b)(3)]	17.8221178
Total CH4 Emissions (mt CH4) [98.236(b)(4)]	553.9953375
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
Total Number, Countt [98.236(b)(1)(i)]	117
Is the Total Number estimated? (Yes / No) [98.236(b)(1)(ii)]	No
Total CO2 Emissions (mt CO2) [98.236(b)(3)]	0.7480736
Total CH4 Emissions (mt CH4) [98.236(b)(4)]	23.2536487
Estimated average number of hours in the calendar year that the pneumatic devices were operating, Tt (hours) [98.236(b)(2)]	8784

NaturalGasDrivenPneumaticPumpsDetails:

mt CO2	1.8
mt CH4	55.15
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)]	29
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)]	1.774162
Total CH4 Emissions (mt CH4) [98.236(c)(4)]	55.14931

AcidGasRemovalUnitsDetails:

mt CO2	2266.6
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)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

AcidGasInfoRowDetails:

Unit ID or Name [98.236(d)(1)(i)]	CGP 31
County and State [98.236(d)(1)(vi)]	Live Oak, TX
Total feed rate entering the acid gas removal unit for the year (million cubic feet) [98.236(d)(1)(ii)]	0.101273
Calculation Method Used (Select from list) [98.236(d)(1)(iii)]	Calculation Methodology 3 [98.233(d)(3)]
Are any CO2 emissions from the acid gas removal unit recovered and transferred outside the facility? (Yes / No) [98.236(d)(1)(iv)]	No
Total CO2 Emissions (mt CO2) [98.236(d)(1)(v)]	20.0874788
Unit ID or Name [98.236(d)(1)(i)]	CGP 41
County and State [98.236(d)(1)(vi)]	Live Oak, TX
Total feed rate entering the acid gas removal unit for the year (million cubic feet) [98.236(d)(1)(ii)]	0.1447242
Calculation Method Used (Select from list) [98.236(d)(1)(iii)]	Calculation Methodology 3 [98.233(d)(3)]
Are any CO2 emissions from the acid gas removal unit recovered and transferred outside the facility? (Yes / No) [98.236(d)(1)(iv)]	No
Total CO2 Emissions (mt CO2) [98.236(d)(1)(v)]	8.686227
Unit ID or Name [98.236(d)(1)(i)]	CGP 52
County and State [98.236(d)(1)(vi)]	Bee, TX
Total feed rate entering the acid gas removal unit for the year (million cubic feet) [98.236(d)(1)(ii)]	15.1247209
Calculation Method Used (Select from list) [98.236(d)(1)(iii)]	Calculation Methodology 3 [98.233(d)(3)]
Are any CO2 emissions from the acid gas removal unit recovered and transferred outside the facility? (Yes / No) [98.236(d)(1)(iv)]	No
Total CO2 Emissions (mt CO2) [98.236(d)(1)(v)]	1359.25764
Unit ID or Name [98.236(d)(1)(i)]	CGP 61
County and State [98.236(d)(1)(vi)]	Karnes, TX
Total feed rate entering the acid gas removal unit for the year (million cubic feet) [98.236(d)(1)(ii)]	101.6286495
Calculation Method Used (Select from list) [98.236(d)(1)(iii)]	Calculation Methodology 3 [98.233(d)(3)]
Are any CO2 emissions from the acid gas removal unit recovered and transferred outside the facility? (Yes / No) [98.236(d)(1)(iv)]	No
Total CO2 Emissions (mt CO2) [98.236(d)(1)(v)]	878.5282941

AcidGasCalcMethod3EmissionsRowDetails:

Unit ID or Name [98.236(d)(1)(i)]	CGP 31
Equation Used (W-4A/W-4B) [98.236(d)(2)(ii)(A)]	W-4A
Annual average fraction of CO2 content of natural gas into the acid gas removal unit, Voli (volumetric fraction) [98.236(d)(2)(ii)(C)]	0.06
Annual average fraction of CO2 content of natural gas out of the acid gas removal unit, Volo (volumetric fraction) [98.236(d)(2)(ii)(B)]	0.001
Natural gas flow rate into the acid gas removal unit, Vin (actual or standard cubic feet) (Eq. W-4A) [98.236(d)(2)(ii)(D)]	101273.0393533
Natural gas flow rate reported on an Actual or Standard basis? [98.236]	Actual
Temperature used to calculate natural gas flow rate (°F) [98.236]	94
Pressure used to calculate natural gas flow rate (psi) [98.236]	1000
Unit ID or Name [98.236(d)(1)(i)]	CGP 41
Equation Used (W-4A/W-4B) [98.236(d)(2)(ii)(A)]	W-4A
Annual average fraction of CO2 content of natural gas into the acid gas removal unit, Voli (volumetric fraction) [98.236(d)(2)(ii)(C)]	0.02
Annual average fraction of CO2 content of natural gas out of the acid gas removal unit, Volo (volumetric fraction) [98.236(d)(2)(ii)(B)]	0
Natural gas flow rate into the acid gas removal unit, Vin (actual or standard cubic feet) (Eq. W-4A) [98.236(d)(2)(ii)(D)]	144724.1938379
Natural gas flow rate reported on an Actual or Standard basis? [98.236]	Actual
Temperature used to calculate natural gas flow rate (°F) [98.236]	168.64
Pressure used to calculate natural gas flow rate (psi) [98.236]	1014
Unit ID or Name [98.236(d)(1)(i)]	CGP 52
Equation Used (W-4A/W-4B) [98.236(d)(2)(ii)(A)]	W-4A
Annual average fraction of CO2 content of natural gas into the acid gas removal unit, Voli (volumetric fraction) [98.236(d)(2)(ii)(C)]	0.025
Annual average fraction of CO2 content of natural gas out of the acid gas removal unit, Volo (volumetric fraction) [98.236(d)(2)(ii)(B)]	0
Natural gas flow rate into the acid gas removal unit, Vin (actual or standard cubic feet) (Eq. W-4A) [98.236(d)(2)(ii)(D)]	15124720.9352543
Natural gas flow rate reported on an Actual or Standard basis? [98.236]	Actual
Temperature used to calculate natural gas flow rate (°F) [98.236]	84.0336702
Pressure used to calculate natural gas flow rate (psi) [98.236]	1051.0917149
Unit ID or Name [98.236(d)(1)(i)]	CGP 61
Equation Used (W-4A/W-4B) [98.236(d)(2)(ii)(A)]	W-4A
Annual average fraction of CO2 content of natural gas into the acid gas removal unit, Voli (volumetric fraction) [98.236(d)(2)(ii)(C)]	0.04
Annual average fraction of CO2 content of natural gas out of the acid gas removal unit, Volo (volumetric fraction) [98.236(d)(2)(ii)(B)]	0.0055
Natural gas flow rate into the acid gas removal unit, Vin (actual or standard cubic feet) (Eq. W-4A) [98.236(d)(2)(ii)(D)]	101628649.5094964
Natural gas flow rate reported on an Actual or Standard basis? [98.236]	Actual
Temperature used to calculate natural gas flow rate (°F) [98.236]	100
Pressure used to calculate natural gas flow rate (psi) [98.236]	75

DehydratorsDetails:

mt CO2	8874.8
mt CH4	187.28
mt N2O	0.001
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)]?	Yes
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:

Total Number of Small Glycol Dehydrators [98.236(e)(2)(i)]	2
Vapor Recovery	No
Dehydrator vents to flares or regenerator firebox/fire tubes	Yes
Number of Small Glycol Dehydrators By Vent Control Type, Count [98.236(e)(2)(ii)] [98.236(e)(2)(iv)(A)]	2
Control devices other than vapor recovery, flare or regenerator firebox/fire tubes	No
Emissions vented to flare or regenerator firebox/fire tubes
Total CO2 Emissions (mt CO2) [98.236(e)(2)(iv)(B)] [98.236(e)(2)(v)(A)]	1097.1108598
Total CH4 Emissions (mt CH4) [98.236(e)(2)(iv)(C)] [98.236(e)(2)(v)(B)]	2.0059173
Total N2O Emissions (mt N2O) [98.236(e)(2)(iv)(D)]	0
Emissions that were not vented to a flare or regenerator firebox/fire tubes
Total CO2 Emissions (mt CO2) [98.236(e)(2)(iv)(B)] [98.236(e)(2)(v)(A)]	0
Total CH4 Emissions (mt CH4) [98.236(e)(2)(iv)(C)] [98.236(e)(2)(v)(B)]	0

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)]	Alderman Dehy
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)]	10
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	99.32
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7
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)]	90
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	355
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0199187
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.838962
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	720.7667331
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	7.379668
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0001285
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	Area 41 Facility (CGP)
County and State [98.236(e)(1)(xviii)]	LIVE OAK, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	10.9
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	52.92
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	2
Glycol dehydrator absorbent circulation pump type [98.236(e)(1)(v)]	Air pneumatic
Dehydrator absorbent circulation rate (gallons per minute) [98.236(e)(1)(vi)]	14
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)]	97
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	1025
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0009934
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.752712
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	166.1790052
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.1217842
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0000157
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	Big Wells Compressor Station
County and State [98.236(e)(1)(xviii)]	Dimmit, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	0.5
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	184.23
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7
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)]	0.3
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)]	No
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)]	475
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0096069
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.7602685
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)]	0.4821066
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	105.1868962
Unit ID or Name [98.236(e)(1)(i)]	CGP 31 Dehy
County and State [98.236(e)(1)(xviii)]	LIVE OAK, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	10
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	97.08
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	2
Glycol dehydrator absorbent circulation pump type [98.236(e)(1)(v)]	Electric/Pneumatic
Dehydrator absorbent circulation rate (gallons per minute) [98.236(e)(1)(vi)]	18
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)]	8770
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	89
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	350
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9686137
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	207.7671583
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	2.7206923
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0000411
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	CGP 52 Dehy
County and State [98.236(e)(1)(xviii)]	BEE, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.5
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	82.5
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7
Glycol dehydrator absorbent circulation pump type [98.236(e)(1)(v)]	Electric/Pneumatic
Dehydrator absorbent circulation rate (gallons per minute) [98.236(e)(1)(vi)]	10
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)]	8632.32
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	80
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	305
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.00498
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.86418
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	149.4331821
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.1039392
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0000143
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	CGP 61 Dehy
County and State [98.236(e)(1)(xviii)]	KARNES, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.5
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	32.13
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	1.8
Glycol dehydrator absorbent circulation pump type [98.236(e)(1)(v)]	Air pneumatic
Dehydrator absorbent circulation rate (gallons per minute) [98.236(e)(1)(vi)]	10
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)]	8739
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	76
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	840
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.00341
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.85778
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	64.6252653
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.0759244
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0000067
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	CGP 81 Dehy
County and State [98.236(e)(1)(xviii)]	DE WITT, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	2
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	55.29
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	1.8
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)]	3.3
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)]	8763.5
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	98
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	1010
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0232516
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.8204838
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	39.0303355
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.0303442
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0000042
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	Delmita Station
County and State [98.236(e)(1)(xviii)]	Starr, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	28.94
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	40
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	2.74
Glycol dehydrator absorbent circulation pump type [98.236(e)(1)(v)]	Electric/Pneumatic
Dehydrator absorbent circulation rate (gallons per minute) [98.236(e)(1)(vi)]	6.84
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)]	8736
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	100
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	942.7
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.00162
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.86807
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	629.5763105
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	1.9881917
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0000932
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	J Lease Compressor Station
County and State [98.236(e)(1)(xviii)]	Kenedy, 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)]	320.59
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	4.8
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)]	0.701
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)]	89
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	88
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.00649
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.90375
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	2.6240638
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.0034403
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0000003
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	East Yard Dehy 1
County and State [98.236(e)(1)(xviii)]	WEBB, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	30
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	63.33
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7
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)]	100
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	900
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0100502
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.8365438
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	1687.2054175
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	18.3166883
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0003046
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	East Yard Dehy 2
County and State [98.236(e)(1)(xviii)]	WEBB, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	30
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	63.33
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7
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)]	100
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	900
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0100502
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.8365438
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	1687.2054175
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	18.3166883
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0003046
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	North Chesterville
County and State [98.236(e)(1)(xviii)]	COLORADO, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	5
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	53.1
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7
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)]	0.48
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)]	86
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	660
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.050989
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.854675
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	6.3565697
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.0017144
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000001
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	Webb County Dehy
County and State [98.236(e)(1)(xviii)]	WEBB, 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)]	58.9
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	3
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)]	8761
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	98
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	914
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0144419
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9000622
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	1555.8791965
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	20.7146138
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0003164
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	Silsbee Compressor Station
County and State [98.236(e)(1)(xviii)]	Hardin, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	2
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	265.88
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7
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)]	3
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)]	No
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)]	72
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	56
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0092
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.8502
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	56.8127517
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.0303494
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000053
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No
Unit ID or Name [98.236(e)(1)(i)]	West Mesa Dehy
County and State [98.236(e)(1)(xviii)]	WEBB, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	15
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	105.52
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7
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)]	100
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	470
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0067641
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.901495
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)]	Yes
CO2 Emissions from Flares or Regenerators (mt CO2) [98.236(e)(1)(xvi)(A)]	803.7465376
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	10.2851358
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.0001576
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	No

BlowdownVentStacksDetails:

mt CO2	2.9
mt CH4	128.96
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)]	Calculated by equipment or event type

BlowdownEquipmentOrEventEmissionsRowDetails:

Equipment or event type [98.236(i)(1)] [98.236(i)(2)]	Facility piping
Total number of blowdowns for equipment or event type, N [98.236(i)(1)(i)]	0
Annual total CO2 emissions for each equipment or event type (mt CO2) [98.236(i)(1)(ii)]	0
Annual total CH4 emissions for each equipment or event type (mt CH4) [98.236(i)(1)(iii)]	0
Equipment or event type [98.236(i)(1)] [98.236(i)(2)]	Pipeline venting
Total number of blowdowns for equipment or event type, N [98.236(i)(1)(i)]	0
Annual total CO2 emissions for each equipment or event type (mt CO2) [98.236(i)(1)(ii)]	0
Annual total CH4 emissions for each equipment or event type (mt CH4) [98.236(i)(1)(iii)]	0
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)]	863
Annual total CO2 emissions for each equipment or event type (mt CO2) [98.236(i)(1)(ii)]	2.249537
Annual total CH4 emissions for each equipment or event type (mt CH4) [98.236(i)(1)(iii)]	74.4947504
Equipment or event type [98.236(i)(1)] [98.236(i)(2)]	Scrubbers/strainers
Total number of blowdowns for equipment or event type, N [98.236(i)(1)(i)]	0
Annual total CO2 emissions for each equipment or event type (mt CO2) [98.236(i)(1)(ii)]	0
Annual total CH4 emissions for each equipment or event type (mt CH4) [98.236(i)(1)(iii)]	0
Equipment or event type [98.236(i)(1)] [98.236(i)(2)]	Pig launchers and receivers
Total number of blowdowns for equipment or event type, N [98.236(i)(1)(i)]	868
Annual total CO2 emissions for each equipment or event type (mt CO2) [98.236(i)(1)(ii)]	0.3445042
Annual total CH4 emissions for each equipment or event type (mt CH4) [98.236(i)(1)(iii)]	37.2320694
Equipment or event type [98.236(i)(1)] [98.236(i)(2)]	Emergency shutdowns
Total number of blowdowns for equipment or event type, N [98.236(i)(1)(i)]	4
Annual total CO2 emissions for each equipment or event type (mt CO2) [98.236(i)(1)(ii)]	0.1535726
Annual total CH4 emissions for each equipment or event type (mt CH4) [98.236(i)(1)(iii)]	14.2017368
Equipment or event type [98.236(i)(1)] [98.236(i)(2)]	All other equipment with a physical volume greater than or equal 50 cubic feet
Total number of blowdowns for equipment or event type, N [98.236(i)(1)(i)]	3
Annual total CO2 emissions for each equipment or event type (mt CO2) [98.236(i)(1)(ii)]	0.1570178
Annual total CH4 emissions for each equipment or event type (mt CH4) [98.236(i)(1)(iii)]	3.0302716

AtmosphericTanksDetails:

mt CO2	1835.1
mt CH4	6.43
mt N2O	0.002
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)]?	Yes
Was Calculation Method 2 used to calculate emissions [(98.233(j)(2)]?	No
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)]	LA SALLE, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	E & P Tank
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	68
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	493
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	73.16
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)]	0.372754
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.372754
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.009356
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.009356
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	304.0698421
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.2542974
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.0002879
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)]	2236.26
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)]	BEE, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	E & P Tank
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	56
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	60
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	67.25
Count of tanks that control emissions with vapor recovery systems [98.236(j)(1)(xii)(A)]	8
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.367593
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.367593
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.008672
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.008672
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)]	5892.6
Total CO2 mass that was recovered (mt CO2) [98.236(j)(1)(xii)(B)]	0.2085193
Total CH4 mass that was recovered (mt CH4) [98.236(j)(1)(xii)(C)]	3.2260176
Annual CO2 emissions from tanks with vapor recovery systems (mt CO2) [98.236(j)(1)(xii)(D)]	0.0109747
Annual CH4 emissions from tanks with vapor recovery systems (mt CH4) [98.236(j)(1)(xii)(E)]	0.1697904
Were any emissions from atmospheric tanks controlled with vapor recovery systems? [98.236(j)(1)(xii)]	Yes
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)]	No
Count of atmospheric tanks [98.236(j)(1)(x)]	8
County and State [98.236(j)(1)(i)]	KARNES, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	E & P Tank
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	56
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	60
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	61.95
Count of tanks that control emissions with vapor recovery systems [98.236(j)(1)(xii)(A)]	8
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.430437
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.430437
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.009224
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.009224
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)]	11064.18
Total CO2 mass that was recovered (mt CO2) [98.236(j)(1)(xii)(B)]	0.4023906
Total CH4 mass that was recovered (mt CH4) [98.236(j)(1)(xii)(C)]	6.2193897
Annual CO2 emissions from tanks with vapor recovery systems (mt CO2) [98.236(j)(1)(xii)(D)]	0.0211785
Annual CH4 emissions from tanks with vapor recovery systems (mt CH4) [98.236(j)(1)(xii)(E)]	0.3273363
Were any emissions from atmospheric tanks controlled with vapor recovery systems? [98.236(j)(1)(xii)]	Yes
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)]	No
Count of atmospheric tanks [98.236(j)(1)(x)]	8
County and State [98.236(j)(1)(i)]	DE WITT, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	E & P Tank
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	56
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	60
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	63.95
Count of tanks that control emissions with vapor recovery systems [98.236(j)(1)(xii)(A)]	16
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.430437
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.430437
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.009224
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.009224
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)]	17604.6
Total CO2 mass that was recovered (mt CO2) [98.236(j)(1)(xii)(B)]	0.6341744
Total CH4 mass that was recovered (mt CH4) [98.236(j)(1)(xii)(C)]	9.7960992
Annual CO2 emissions from tanks with vapor recovery systems (mt CO2) [98.236(j)(1)(xii)(D)]	0.0333776
Annual CH4 emissions from tanks with vapor recovery systems (mt CH4) [98.236(j)(1)(xii)(E)]	0.5155842
Were any emissions from atmospheric tanks controlled with vapor recovery systems? [98.236(j)(1)(xii)]	Yes
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)]	No
Count of atmospheric tanks [98.236(j)(1)(x)]	16
County and State [98.236(j)(1)(i)]	DIMMIT, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	E & P Tank
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	66
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	540
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	74.28
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	2
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.377163
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.377163
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.006791
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.006791
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	788.2690956
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.5758741
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.0007106
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)]	3982.08
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)]	2
County and State [98.236(j)(1)(i)]	WEBB, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	E & P Tank
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	77.2857143
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	449.8571429
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	59.5714286
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	14
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	3
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.379449
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.609923
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.005387
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.016164
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.000907
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	0.035373
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	569.8619447
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	1.1561951
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.0007015
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)]	48853.68
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)]	Yes
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)]	17
County and State [98.236(j)(1)(i)]	KENEDY, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	E & P Tank
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	78
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	870
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	60.9
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	2
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.487366
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.487366
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.009529
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.009529
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	81.5329978
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.1453909
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.0000967
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)]	1379.82
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)]	2
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 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	E & P Tank
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	70
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	780
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	64.95
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	2
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.609923
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.609923
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.007944
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.007944
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	53.0574389
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.1335217
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.0000714
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)]	1372.5
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)]	2
County and State [98.236(j)(1)(i)]	ZAPATA, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	E & P Tank
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	60
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	60
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	44
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	2
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.443004
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.443004
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.00818
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.00818
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	36.862463
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.050784
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.0000402
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)]	9461.1
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)]	2

AtmosphericTanksCalculationMethodThreeRowDetails:

Estimate of fraction of oil/condensate throughput sent to tanks in basin with flaring [98.236(j)(2)(i)(B)]	0
Estimate of fraction of oil/condensate throughput sent to tanks with vapor recovery system control measures [98.236(j)(2)(i)(C)]	0.3125
Count of atmospheric tanks in basin [98.236(j)(2)(i)(D)]	16
Total annual oil/condensate throughput that is sent to all atmospheric tanks (barrels per year) [98.236(j)(2)(i)(A)]	9970.761914

AtmosphericTanksCalcMethodThreeNoFlaringRowDetails:

County and State [98.236(j)(2)(ii)(A)]	MC MULLEN, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	3
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0.0088368
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.0202752
County and State [98.236(j)(2)(ii)(A)]	DE WITT, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	2
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0.0029456
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.0067584
County and State [98.236(j)(2)(ii)(A)]	LA SALLE, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	3
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0.44184
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	1.01376
County and State [98.236(j)(2)(ii)(A)]	STARR, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	5
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0.29456
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.67584
County and State [98.236(j)(2)(ii)(A)]	LIVE OAK, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	1
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0.14728
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.33792
County and State [98.236(j)(2)(ii)(A)]	KENEDY, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	1
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0.14728
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.33792
County and State [98.236(j)(2)(ii)(A)]	WEBB, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	1
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0.29456
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.67584

FlareStacksDetails:

mt CO2	23290.4
mt CH4	72.46
mt N2O	0.050
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)]	402C Compressor Station
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)]	1317600
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.901041
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0033153
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	78.0621604
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.4558893
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0001627
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Alderman Compressor Station
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)]	2612508
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.3437521
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0086746
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	17.7656716
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.0905557
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000347
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Area 31 Facility (CGP)
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	285396925.4823244
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.3748207
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.607348
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	15004.414975
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	41.0775089
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0352465
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Area 32 Facility (CGP)
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	725290
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.797003
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.020594
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	48.19367
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.2219744
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000896
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Area 41 Facility (CGP)
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	29744029.1494876
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.307274
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.588742
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	1771.6160007
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	3.5095937
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0036734
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Area 52 Facility (CGP)
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	24867189.7295821
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.8236862
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.006556
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	1752.5380454
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	7.8653802
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0030711
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Area 61 Facility (CGP)
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	4466594.3101341
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.251337
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.704417
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	250.3567053
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.4310862
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0005516
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Area 81 Facility (CGP)
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	1575656.0859339
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.728737
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.027895
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	124.4483301
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.4409237
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0001946
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Area 82 Facility (CGP)
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	1345585.4357785
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.568832
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.033022
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	115.221839
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.2939182
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0001662
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Big Wells Compressor Station
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)]	6034608
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.2839248
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.005042
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	231.3506965
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.0820617
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000347
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	East Yard Compressor Station
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	14280513.2865005
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.4979704
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0088078
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	1137.2540564
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	2.1752388
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0013591
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Freer 44 Compressor Station
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)]	2027640
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.8383523
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0109961
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	69.9742091
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.4886441
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0001627
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	J Lease Compressor Station
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)]	1494744
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.6834909
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0081055
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	40.9902339
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.2469203
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000879
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Pearsall Compressor Station
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)]	562176
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.98
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.01
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	28.9849625
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.2115581
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000694
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Silsbee Compressor Station
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	1317600
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.8502
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.00922
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	84.0246262
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.4301658
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0001627
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Station (SAS) 536
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	1317600
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.98
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.01
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	67.933506
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.4958392
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0001627
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Swift Dehy Station
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)]	1895880
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.8546023
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0112131
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	69.9742091
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.4886441
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0001627
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Webb County Dehy & Compressor Station
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	2620230.6
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.7837747
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0146432
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	102.7196629
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.607192
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.000217
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	West Mesa Compressor Station
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)]	1050420
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.6647704
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0076174
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	12.9230608
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.0760198
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000271
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Zapata Compressor Station
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)]	826801.32
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.6813616
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0136648
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	31.8106454
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.1655426
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0000619
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	Delmita Station
Does the flare stack have a continuous flow monitor on gas to the flare? [98.236(n)(2)]	Yes
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)]	37231440
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.8816962
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0030752
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	2249.809552
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	12.6054986
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.0045981

CentrifugalCompressorsDetails:

mt CO2	250.9
mt CH4	2073.60
Did the facility have any centrifugal compressors subject to reporting under 98.232 [98.236(o)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No
Total annual Centrifugal Compressor emissions CO2 Emissions (mt CO2) [98.236(o)(5)(ii)]	250.902
Total annual Centrifugal Compressor emissions CH4 Emissions (mt CH4) [98.236(o)(5)(iii)]	2073.6
Number of Centrifugal Compressors with wet seal oil degassing vents, Count [98.236(o)(5)(i)]	9

ReciprocatingCompressorsDetails:

mt CO2	1.7
mt CH4	11.10
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)]	1.6909322
Total annual Reciprocating Compressor emissions CH4 Emissions (mt CH4) [98.236(p)(5)(iii)]	11.102976
Count of Reciprocating Compressors [98.236(p)(5)(i)]	61

OtherEmissionsFromEquipmentLeaksDetails:

mt CO2	38.3
mt CH4	1191.02
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)]	31299
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)]	17.4204543
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	541.5097453
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)]	104319
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)]	8.1574793
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	253.5728671
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)]	2652
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)]	0.3781628
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	11.7550819
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)]	2072
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)]	1.8394615
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	57.1791249
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)]	4865.9170578
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)]	10.519769
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	327.0039542
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)]	0
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)]	0
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	0
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 - 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)]	0
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)]	160
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)]	1357
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)]	83
Major Equipment Type [98.236(r)(3)(ii)]	In-line heaters
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)]	23
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)]	20

CombustionEmissionsDetails:

mt CO2	338569.9
mt CH4	6.38
mt N2O	0.638
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)]	Yes
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
Total number of combustion units meeting 98.236(z)(1) descriptions	26
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)]	Yes
Are there Internal fuel combustion units of any heat capacity that are compressor-drivers? [98.236(z)(2)(i)]	Yes

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)]	406721.8560633
Unit of measure [98.236(z)(2)(iii)	thousand standard cubic feet
CO2 Emissions (mt CO2) [98.236(z)(2)(iv)]	23794.7416975
CH4 Emissions (mt CH4) [98.236(z)(2)(v)]	0.4484497
N2O Emissions (mt N2O) [98.236(z)(2)(vi)]	0.044845
Type of combustion unit [98.236(z)(2)(i)]	Internal fuel combustion units that are not compressor-drivers, with a rated heat capacity greater than 1 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)]	492505.4159186
Unit of measure [98.236(z)(2)(iii)	thousand standard cubic feet
CO2 Emissions (mt CO2) [98.236(z)(2)(iv)]	29131.3025808
CH4 Emissions (mt CH4) [98.236(z)(2)(v)]	0.5490257
N2O Emissions (mt N2O) [98.236(z)(2)(vi)]	0.0549026
Type of combustion unit [98.236(z)(2)(i)]	Internal fuel combustion units of any heat capacity that are compressor-drivers
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)]	4966097.3969336
Unit of measure [98.236(z)(2)(iii)	thousand standard cubic feet
CO2 Emissions (mt CO2) [98.236(z)(2)(iv)]	285643.8272905
CH4 Emissions (mt CH4) [98.236(z)(2)(v)]	5.3834117
N2O Emissions (mt N2O) [98.236(z)(2)(vi)]	0.5383412