Address: 6141 Paluxy drive
City: Tyler
State: TX
Postal Code:

CO2 equivalent emissions from facility subparts C-II, SS, and TT (metric tons):773,327.8
CO2 equivalent emissions from supplier subparts LL-QQ (metric tons):
Biogenic CO2 emissions from facility subparts C-II, SS, and TT (metric tons):0
Cogeneration Unit Emissions Indicator:N
GHG Report Start Date:2020-01-01
GHG Report End Date:2020-12-31
Description of Changes to Calculation Methodology:
Plant Code Indicator:N
Primary NAICS Code:211130
Second Primary NAICS Code:

Parent Company Details:

Subpart W: Petroleum and Natural Gas Systems

SubpartWSummaryDetails:

Industry Segment Number	9
Industry Segment Name	Onshore petroleum and natural gas gathering and boosting [98.230(a)(9)]
Total Reported CO2 Emissions (mt CO2)	589887.0
Total CO2e Emissions (mt CO2e)	773327.8
Total Reported CH4 Emissions (mt CH4)	7324.52
Total Reported N2O Emissions (mt N2O)	1.100

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)	220.6
Total Reported CH4 Emissions (mt CH4)	2948.67
Total Reported N2O Emissions (mt N2O)	0
Source Reporting Form	Natural Gas Driven Pneumatic Pumps [98.236(c)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	38.4
Total Reported CH4 Emissions (mt CH4)	555.10
Total Reported N2O Emissions (mt N2O)	0
Source Reporting Form	Acid Gas Removal Units [98.236(d)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	0
Total Reported CH4 Emissions (mt CH4)	0
Total Reported N2O Emissions (mt N2O)	0
Source Reporting Form	Dehydrators [98.236(e)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	6838.7
Total Reported CH4 Emissions (mt CH4)	229.85
Total Reported N2O Emissions (mt N2O)	0.012
Source Reporting Form	Well Venting for Liquids Unloading [98.236(f)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0
Total Reported CH4 Emissions (mt CH4)	0
Total Reported N2O Emissions (mt N2O)	0
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
Total Reported CH4 Emissions (mt CH4)	0
Total Reported N2O Emissions (mt N2O)	0
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
Total Reported CH4 Emissions (mt CH4)	0
Total Reported N2O Emissions (mt N2O)	0
Source Reporting Form	Blowdown Vent Stacks [98.236(i)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	3.9
Total Reported CH4 Emissions (mt CH4)	66.13
Source Reporting Form	Atmospheric Storage Tanks [98.236(j)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	795.2
Total Reported CH4 Emissions (mt CH4)	47.42
Total Reported N2O Emissions (mt N2O)	0.001
Source Reporting Form	Transmission Storage Tanks [98.236(k)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0
Total Reported CH4 Emissions (mt CH4)	0
Total Reported N2O Emissions (mt N2O)	0
Source Reporting Form	Well Testing [98.236(l)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0
Total Reported CH4 Emissions (mt CH4)	0
Total Reported N2O Emissions (mt N2O)	0
Source Reporting Form	Associated Gas Venting and Flaring [98.236(m)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0
Total Reported CH4 Emissions (mt CH4)	0
Total Reported N2O Emissions (mt N2O)	0
Source Reporting Form	Flare Stacks [98.236(n)]
Required for Selected Industry Segment	Yes
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	Centrifugal Compressors [98.236(o)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	0
Total Reported CH4 Emissions (mt CH4)	0
Total Reported N2O Emissions (mt N2O)	0
Source Reporting Form	Reciprocating Compressors [98.236(p)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	3.8
Total Reported CH4 Emissions (mt CH4)	25.12
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)	168.1
Total Reported CH4 Emissions (mt CH4)	2227.08
Total Reported N2O Emissions (mt N2O)	0.000
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
Total Reported CH4 Emissions (mt CH4)	0
Total Reported N2O Emissions (mt N2O)	0
Source Reporting Form	Enhanced Oil Recovery Injection Pumps [98.236(w)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	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
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)	581818.3
Total Reported CH4 Emissions (mt CH4)	1225.15
Total Reported N2O Emissions (mt N2O)	1.087

FacilityOverviewDetails:


FacilityOverviewOnshorePetroleumAndNaturalGasGatheringAndBoostingRowDetails:

Select the basin associated with this facility [98.236(a)(9)]	260 - East Texas Basin
Quantity of gas received by the gathering and boosting facility in the calendar year (thousand standard cubic feet) [98.236(aa)(10)(i)]	242297978.193598
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)]	241699401.711698
Quantity of all hydrocarbon liquids received by the gathering and boosting facility in the calendar year (barrels) [98.236(aa)(10)(iii)]	2291393.94199999
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)]	2291393.94199999

PneumaticDeviceVentingDetails:

mt CO2	220.6
mt CH4	2948.67
Did the Facility have any continuous high-bleed pneumatic devices subject to reporting under 98.232 [98.236(b)]?	No
Did the Facility have any intermittent bleed pneumatic devices subject to reporting under 98.232 [98.236(b)]?	Yes
Did the Facility have any continuous low-bleed pneumatic devices subject to reporting under 98.232 [98.236(b)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

PneumaticDeviceTypesRowDetails:

Type of Pneumatic Device	Intermittent Bleed Pneumatic Devices
Total Number, Countt [98.236(b)(1)(i)]	1520
Is the Total Number estimated? (Yes / No) [98.236(b)(1)(ii)]	No
Total CO2 Emissions (mt CO2) [98.236(b)(3)]	220.6
Total CH4 Emissions (mt CH4) [98.236(b)(4)]	2948.02
Estimated average number of hours in the calendar year that the pneumatic devices were operating, Tt (hours) [98.236(b)(2)]	8784.000000
Type of Pneumatic Device	Low-Bleed Pneumatic Devices
Total Number, Countt [98.236(b)(1)(i)]	3
Is the Total Number estimated? (Yes / No) [98.236(b)(1)(ii)]	No
Total CO2 Emissions (mt CO2) [98.236(b)(3)]	0.0
Total CH4 Emissions (mt CH4) [98.236(b)(4)]	0.65
Estimated average number of hours in the calendar year that the pneumatic devices were operating, Tt (hours) [98.236(b)(2)]	8784.000000

NaturalGasDrivenPneumaticPumpsDetails:

mt CO2	38.4
mt CH4	555.10
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)]	299
Average estimated number of hours in the calendar year that the natural gas driven pneumatic pumps were operated, T (hours) [98.236(c)(2)]	8784.000000
Total CO2 Emissions (mt CO2) [98.236(c)(3)]	38.4
Total CH4 Emissions (mt CH4) [98.236(c)(4)]	555.10

AcidGasRemovalUnitsDetails:

mt CO2	0
Did the Facility have any acid gas removal units that vent directly to the atmosphere, to a flare or engine, or to a sulfur recovery plant subject to reporting under 98.232 [98.236(d)]?	No

DehydratorsDetails:

mt CO2	6838.7
mt CH4	229.85
mt N2O	0.012
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)]	49
Vapor Recovery	No
Number of Small Glycol Dehydrators By Vent Control Type, Count [98.236(e)(2)(ii)] [98.236(e)(2)(iv)(A)]	0
Dehydrator vents to flares or regenerator firebox/fire tubes	No
Number of Small Glycol Dehydrators By Vent Control Type, Count [98.236(e)(2)(ii)] [98.236(e)(2)(iv)(A)]	0
Control devices other than vapor recovery, flare or regenerator firebox/fire tubes	No
Emissions vented to flare or regenerator firebox/fire tubes
Total N2O Emissions (mt N2O) [98.236(e)(2)(iv)(D)]	0.000
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)]	8.3
Total CH4 Emissions (mt CH4) [98.236(e)(2)(iv)(C)] [98.236(e)(2)(v)(B)]	69.24

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)]	29623
County and State [98.236(e)(1)(xviii)]	CHEROKEE, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	0.7700000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	38.7800000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	3.5000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	81.6600000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	821.4400000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0170000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9730000
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)]	545.8
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	3.64
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
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)]	30793
County and State [98.236(e)(1)(xviii)]	CHEROKEE, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	7.3500000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	44.0800000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	3.5000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	88.7600000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	927.0200000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0160000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9770000
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)]	19.2
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	92.50
Unit ID or Name [98.236(e)(1)(i)]	30044
County and State [98.236(e)(1)(xviii)]	GREGG, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	2.5000000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	43.9700000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	3.5000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	68.7300000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	415.9000000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0260000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9090000
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)]	164.5
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.80
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
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)]	30046
County and State [98.236(e)(1)(xviii)]	GREGG, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	2.1500000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	57.1900000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	71.8500000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	344.4400000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0200000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9190000
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)]	61.6
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.35
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
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)]	30053
County and State [98.236(e)(1)(xviii)]	GREGG, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	4.2600000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	24.1600000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	3.5000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	70.0000000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	960.0000000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0240000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9240000
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)]	364.7
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	1.90
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
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)]	8.8
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	1.89
Unit ID or Name [98.236(e)(1)(i)]	30056
County and State [98.236(e)(1)(xviii)]	GREGG, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	4.6500000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	34.2400000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	4.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	75.9300000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	766.7100000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0170000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9190000
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)]	326.0
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	1.64
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
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)]	4.9
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	1.42
Unit ID or Name [98.236(e)(1)(i)]	30063
County and State [98.236(e)(1)(xviii)]	GREGG, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	0.5900000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	89.7700000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	68.1700000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	303.7300000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0150000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.8830000
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)]	152.6
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.70
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	Yes
CO2 Emissions from Venting (mt CO2) [98.236(e)(1)(xvii)(A)]	1.5
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	0.70
Unit ID or Name [98.236(e)(1)(i)]	30066
County and State [98.236(e)(1)(xviii)]	GREGG, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	0.5900000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	56.1100000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	68.1700000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	303.7300000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0150000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.8830000
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)]	147.0
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.70
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	Yes
CO2 Emissions from Venting (mt CO2) [98.236(e)(1)(xvii)(A)]	1.8
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	0.92
Unit ID or Name [98.236(e)(1)(i)]	30085
County and State [98.236(e)(1)(xviii)]	HARRISON, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.5500000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	17.0900000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	52.5700000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	677.6800000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0160000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9220000
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)]	304.6
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	1.75
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
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)]	30093
County and State [98.236(e)(1)(xviii)]	HARRISON, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	2.2000000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	39.8700000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	4.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	80.9900000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	777.4100000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0170000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.8970000
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)]	369.0
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	1.25
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
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)]	30095
County and State [98.236(e)(1)(xviii)]	HARRISON, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	6.0500000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	23.8300000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	1.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	64.9900000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	775.7400000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0160000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9020000
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)]	90.6
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.42
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	Yes
CO2 Emissions from Venting (mt CO2) [98.236(e)(1)(xvii)(A)]	1.4
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	0.34
Unit ID or Name [98.236(e)(1)(i)]	30792
County and State [98.236(e)(1)(xviii)]	HARRISON, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.7500000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	36.3600000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	80.3100000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	858.5200000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0170000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.8730000
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)]	448.8
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	2.09
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
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)]	30177
County and State [98.236(e)(1)(xviii)]	HENDERSON, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	3.1800000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	32.6000000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	3.5000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	70.6400000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	650.2700000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0150000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9430000
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)]	242.2
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	1.34
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
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)]	4.1
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	1.30
Unit ID or Name [98.236(e)(1)(i)]	30177
County and State [98.236(e)(1)(xviii)]	HENDERSON, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	0.4400000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	19.0100000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	3.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	54.7500000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	651.1600000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0150000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9390000
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)]	447.6
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	2.56
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
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)]	30107
County and State [98.236(e)(1)(xviii)]	HOUSTON, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.2700000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	36.6300000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.8000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	78.4500000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	774.9900000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0200000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9720000
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)]	414.4
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	2.75
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
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)]	2.6
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	1.11
Unit ID or Name [98.236(e)(1)(i)]	30108
County and State [98.236(e)(1)(xviii)]	HOUSTON, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.7700000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	32.9200000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	76.3800000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	819.6600000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0200000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9710000
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)]	162.3
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	1.02
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
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)]	30443
County and State [98.236(e)(1)(xviii)]	MARION, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.0500000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	35.1000000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	59.6300000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	374.0700000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0120000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9140000
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)]	180.0
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.91
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
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)]	30554
County and State [98.236(e)(1)(xviii)]	NACOGDOCHES, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	5.0300000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	22.5300000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	1.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	61.4300000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	704.7200000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0320000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9660000
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)]	10.2
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	20.83
Unit ID or Name [98.236(e)(1)(i)]	30555
County and State [98.236(e)(1)(xviii)]	NACOGDOCHES, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.0200000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	30.9700000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	1.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	77.1100000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	931.8500000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0150000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9250000
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)]	103.5
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.55
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
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)]	30559
County and State [98.236(e)(1)(xviii)]	NACOGDOCHES, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	3.6100000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	33.2200000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.8000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	79.4300000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	933.4500000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0140000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9310000
Were any dehydrator emissions vented to a vapor recovery device? [98.236(e)(1)(xv)]	Yes
Were any dehydrator emissions vented to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvi)]	No
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	Yes
CO2 Emissions from Venting (mt CO2) [98.236(e)(1)(xvii)(A)]	2.8
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	1.02
Unit ID or Name [98.236(e)(1)(i)]	30628
County and State [98.236(e)(1)(xviii)]	PANOLA, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	6.0700000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	20.0100000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.8000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	62.6800000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	885.9100000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0200000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9260000
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)]	308.9
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	1.52
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
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)]	30802
County and State [98.236(e)(1)(xviii)]	RUSK, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.5100000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	40.2700000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.8000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	80.3100000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	746.7600000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0180000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.8830000
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)]	558.5
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	2.52
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
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)]	30810
County and State [98.236(e)(1)(xviii)]	RUSK, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.2300000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	44.6000000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	88.7400000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	921.9400000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0160000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.8980000
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)]	430.6
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	2.23
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	Yes
CO2 Emissions from Venting (mt CO2) [98.236(e)(1)(xvii)(A)]	1.6
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	0.94
Unit ID or Name [98.236(e)(1)(i)]	35053
County and State [98.236(e)(1)(xviii)]	RUSK, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.5100000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	40.2700000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	1.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	80.3100000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	746.7600000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0180000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.8830000
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)]	182.7
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.89
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	Yes
CO2 Emissions from Venting (mt CO2) [98.236(e)(1)(xvii)(A)]	1.0
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	0.46
Unit ID or Name [98.236(e)(1)(i)]	30852
County and State [98.236(e)(1)(xviii)]	SHELBY, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	1.2100000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	113.9300000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	75.7900000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	179.4900000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0120000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9770000
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)]	64.1
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.44
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
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)]	30860
County and State [98.236(e)(1)(xviii)]	SHELBY, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	14.8000000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	19.3400000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	4.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	62.3300000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	913.1600000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0240000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9540000
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)]	392.6
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	2.11
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.001
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)]	30868
County and State [98.236(e)(1)(xviii)]	SHELBY, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	3.5700000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	79.4800000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	1.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	109.1600000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	932.4300000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0330000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9620000
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)]	84.5
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.50
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
Were any dehydrator emissions vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes? [98.236(e)(1)(xvii)]	Yes
CO2 Emissions from Venting (mt CO2) [98.236(e)(1)(xvii)(A)]	1.6
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	0.35
Unit ID or Name [98.236(e)(1)(i)]	30868
County and State [98.236(e)(1)(xviii)]	SHELBY, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	3.5700000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	79.4800000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	109.1600000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	932.4300000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0330000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9620000
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)]	166.7
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	1.00
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
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)]	4.0
CH4 Emissions from Venting (mt CH4) [98.236(e)(1)(xvii)(B)]	0.95
Unit ID or Name [98.236(e)(1)(i)]	30870
County and State [98.236(e)(1)(xviii)]	SHELBY, TX
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	2.4600000
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	121.3500000
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	7.0000000
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)]	2.0000000
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)]	8760.00
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	126.2800000
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	978.9600000
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.0130000
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.9480000
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)]	51.1
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.30
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0.000
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	3.9
mt CH4	66.13
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)]	Compressors
Total number of blowdowns for equipment or event type, N [98.236(i)(1)(i)]	1319
Annual total CO2 emissions for each equipment or event type (mt CO2) [98.236(i)(1)(ii)]	3.9
Annual total CH4 emissions for each equipment or event type (mt CH4) [98.236(i)(1)(iii)]	65.89
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)]	6
Annual total CO2 emissions for each equipment or event type (mt CO2) [98.236(i)(1)(ii)]	0.0
Annual total CH4 emissions for each equipment or event type (mt CH4) [98.236(i)(1)(iii)]	0.24

AtmosphericTanksDetails:

mt CO2	795.2
mt CH4	47.42
mt N2O	0.001
Did the facility send hydrocarbon liquids to atmospheric storage tanks that are subject to reporting under 98.232 [98.236(j)]?	Yes
Was Calculation Method 1 used to calculate emissions [(98.233(j)(1)]?	No
Was Calculation Method 2 used to calculate emissions [(98.233(j)(2)]?	Yes
Was Calculation Method 3 used to calculate emissions [(98.233(j)(3)]?	Yes
If Calculation Method 1 or 2 were used, were any atmospheric tanks observed to have malfunctioning dump valves during the calendar year?	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

AtmosphericTanksCalculationMethodOneOrTwoSubBasinRowDetails:

County and State [98.236(j)(1)(i)]	FRANKLIN, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	77.6000000
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	81.0100000
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	42.0900000
Count of tanks that control emissions with vapor recovery systems [98.236(j)(1)(xii)(A)]	0
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	32
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	17
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.2636000
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.2636000
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.0322000
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.0322000
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	2.1
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	6.33
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	378.3
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.28
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.001
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)]	122649.00
Total CO2 mass that was recovered (mt CO2) [98.236(j)(1)(xii)(B)]	0.0
Total CH4 mass that was recovered (mt CH4) [98.236(j)(1)(xii)(C)]	0.00
Annual CO2 emissions from tanks with vapor recovery systems (mt CO2) [98.236(j)(1)(xii)(D)]	0.0
Annual CH4 emissions from tanks with vapor recovery systems (mt CH4) [98.236(j)(1)(xii)(E)]	0.00
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)]	49
County and State [98.236(j)(1)(i)]	GREGG, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	84.1800000
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	167.2600000
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	46.5600000
Count of tanks that control emissions with vapor recovery systems [98.236(j)(1)(xii)(A)]	0
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	0
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	204
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.3270000
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.3270000
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.0260000
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.0260000
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.9
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	4.01
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	0.0
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.00
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.000
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)]	14926.00
Total CO2 mass that was recovered (mt CO2) [98.236(j)(1)(xii)(B)]	0.0
Total CH4 mass that was recovered (mt CH4) [98.236(j)(1)(xii)(C)]	0.00
Annual CO2 emissions from tanks with vapor recovery systems (mt CO2) [98.236(j)(1)(xii)(D)]	0.0
Annual CH4 emissions from tanks with vapor recovery systems (mt CH4) [98.236(j)(1)(xii)(E)]	0.00
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)]	No
Count of atmospheric tanks [98.236(j)(1)(x)]	204
County and State [98.236(j)(1)(i)]	HENDERSON, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	74.6800000
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	49.7600000
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	44.9200000
Count of tanks that control emissions with vapor recovery systems [98.236(j)(1)(xii)(A)]	0
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	167
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	27
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.2991000
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.2991000
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.0302000
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.0302000
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.3
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	1.23
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	93.1
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.12
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.000
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)]	29591.00
Total CO2 mass that was recovered (mt CO2) [98.236(j)(1)(xii)(B)]	0.0
Total CH4 mass that was recovered (mt CH4) [98.236(j)(1)(xii)(C)]	0.00
Annual CO2 emissions from tanks with vapor recovery systems (mt CO2) [98.236(j)(1)(xii)(D)]	0.0
Annual CH4 emissions from tanks with vapor recovery systems (mt CH4) [98.236(j)(1)(xii)(E)]	0.00
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)]	194
County and State [98.236(j)(1)(i)]	LEON, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	66.4300000
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	54.5100000
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	40.4900000
Count of tanks that control emissions with vapor recovery systems [98.236(j)(1)(xii)(A)]	0
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	0
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	4
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.5828000
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.5828000
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.0362000
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.0362000
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.3
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	1.72
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	0.0
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.00
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.000
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)]	4929.00
Total CO2 mass that was recovered (mt CO2) [98.236(j)(1)(xii)(B)]	0.0
Total CH4 mass that was recovered (mt CH4) [98.236(j)(1)(xii)(C)]	0.00
Annual CO2 emissions from tanks with vapor recovery systems (mt CO2) [98.236(j)(1)(xii)(D)]	0.0
Annual CH4 emissions from tanks with vapor recovery systems (mt CH4) [98.236(j)(1)(xii)(E)]	0.00
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)]	No
Count of atmospheric tanks [98.236(j)(1)(x)]	4
County and State [98.236(j)(1)(i)]	PANOLA, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	79.9300000
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	189.2600000
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	52.3200000
Count of tanks that control emissions with vapor recovery systems [98.236(j)(1)(xii)(A)]	0
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	0
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	178
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.3962000
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.3962000
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.0320000
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.0320000
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	3.0
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	13.64
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	0.0
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.00
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.000
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)]	56648.00
Total CO2 mass that was recovered (mt CO2) [98.236(j)(1)(xii)(B)]	0.0
Total CH4 mass that was recovered (mt CH4) [98.236(j)(1)(xii)(C)]	0.00
Annual CO2 emissions from tanks with vapor recovery systems (mt CO2) [98.236(j)(1)(xii)(D)]	0.0
Annual CH4 emissions from tanks with vapor recovery systems (mt CH4) [98.236(j)(1)(xii)(E)]	0.00
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)]	No
Count of atmospheric tanks [98.236(j)(1)(x)]	178
County and State [98.236(j)(1)(i)]	TITUS, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	101.9300000
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	56.0100000
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	33.2900000
Count of tanks that control emissions with vapor recovery systems [98.236(j)(1)(xii)(A)]	0
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	0
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	29
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.3684000
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.3684000
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.0675000
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.0675000
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	4.6
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	9.07
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	0.0
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.00
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.000
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)]	55661.00
Total CO2 mass that was recovered (mt CO2) [98.236(j)(1)(xii)(B)]	0.0
Total CH4 mass that was recovered (mt CH4) [98.236(j)(1)(xii)(C)]	0.00
Annual CO2 emissions from tanks with vapor recovery systems (mt CO2) [98.236(j)(1)(xii)(D)]	0.0
Annual CH4 emissions from tanks with vapor recovery systems (mt CH4) [98.236(j)(1)(xii)(E)]	0.00
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)]	No
Count of atmospheric tanks [98.236(j)(1)(x)]	29
County and State [98.236(j)(1)(i)]	UPSHUR, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	80.4300000
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	162.5100000
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	52.0700000
Count of tanks that control emissions with vapor recovery systems [98.236(j)(1)(xii)(A)]	0
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	24
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	27
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.3712000
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.3712000
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.0297000
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.0297000
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.5
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	2.44
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	54.7
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.07
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.000
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)]	12213.00
Total CO2 mass that was recovered (mt CO2) [98.236(j)(1)(xii)(B)]	0.0
Total CH4 mass that was recovered (mt CH4) [98.236(j)(1)(xii)(C)]	0.00
Annual CO2 emissions from tanks with vapor recovery systems (mt CO2) [98.236(j)(1)(xii)(D)]	0.0
Annual CH4 emissions from tanks with vapor recovery systems (mt CH4) [98.236(j)(1)(xii)(E)]	0.00
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)]	51
County and State [98.236(j)(1)(i)]	WOOD, TX
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	80.4300000
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	49.5100000
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	33.8900000
Count of tanks that control emissions with vapor recovery systems [98.236(j)(1)(xii)(A)]	252
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	252
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	0
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.3266000
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.3266000
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.0676000
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.0676000
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.0
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	0.00
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	251.4
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.36
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.000
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)]	1901971.00
Total CO2 mass that was recovered (mt CO2) [98.236(j)(1)(xii)(B)]	195.4
Total CH4 mass that was recovered (mt CH4) [98.236(j)(1)(xii)(C)]	344.68
Annual CO2 emissions from tanks with vapor recovery systems (mt CO2) [98.236(j)(1)(xii)(D)]	0.0
Annual CH4 emissions from tanks with vapor recovery systems (mt CH4) [98.236(j)(1)(xii)(E)]	0.00
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)]	Yes
Count of atmospheric tanks [98.236(j)(1)(x)]	252

AtmosphericTanksCalculationMethodThreeRowDetails:

Estimate of fraction of oil/condensate throughput sent to tanks in basin with flaring [98.236(j)(2)(i)(B)]	0.1237897
Estimate of fraction of oil/condensate throughput sent to tanks with vapor recovery system control measures [98.236(j)(2)(i)(C)]	0.0000000
Count of atmospheric tanks in basin [98.236(j)(2)(i)(D)]	239
Total annual oil/condensate throughput that is sent to all atmospheric tanks (barrels per year) [98.236(j)(2)(i)(A)]	24994

AtmosphericTanksCalcMethodThreeNoFlaringRowDetails:

County and State [98.236(j)(2)(ii)(A)]	CHEROKEE, 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)]	0.1
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.34
County and State [98.236(j)(2)(ii)(A)]	HARRISON, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	36
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0.4
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	1.02
County and State [98.236(j)(2)(ii)(A)]	HENDERSON, 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)]	0.1
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.08
County and State [98.236(j)(2)(ii)(A)]	LEON, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	12
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0.3
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.42
County and State [98.236(j)(2)(ii)(A)]	PANOLA, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	101
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	2.4
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	4.91
County and State [98.236(j)(2)(ii)(A)]	RUSK, TX
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	19
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0.4
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	1.02
County and State [98.236(j)(2)(ii)(A)]	UPSHUR, 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)]	0.1
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.34

AtmosphericTanksCalcMethodThreeWithFlaringRowDetails:

County and State [98.236(j)(2)(iii)(A)]	GREGG, TX
Count of tanks with flaring emission control measures [98.236(j)(2)(iii)(B)]	50
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(2)(iii)(C)]	1.1
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(2)(iii)(D)]	0.01
Annual N2O emissions from flaring (mt N2O) [98.236(j)(2)(iii)(E)]	0.000
County and State [98.236(j)(2)(iii)(A)]	UPSHUR, TX
Count of tanks with flaring emission control measures [98.236(j)(2)(iii)(B)]	16
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(2)(iii)(C)]	1.1
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(2)(iii)(D)]	0.01
Annual N2O emissions from flaring (mt N2O) [98.236(j)(2)(iii)(E)]	0.000

FlareStacksDetails:

mt CO2	0.0
mt CH4	0.00
mt N2O	0.000
Did the facility have flare stacks subject to reporting under 98.232 [98.236(n)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

UniqueFlareStacksRowDetails:

Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	29724
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)]	754726
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.264000
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.033000
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0.00000000
CO2 emissions (mt CO2) [98.236(n)(9)]	0.0
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.00
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.000
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	29733
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)]	1993743
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.264000
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.033000
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0.00000000
CO2 emissions (mt CO2) [98.236(n)(9)]	0.0
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.00
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.000
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	30047
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)]	20448
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.863067
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.136933
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0.00000000
CO2 emissions (mt CO2) [98.236(n)(9)]	0.0
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.00
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.000
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	30175
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)]	1035235
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.300000
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.031000
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0.00000000
CO2 emissions (mt CO2) [98.236(n)(9)]	0.0
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.00
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.000
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	31279
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)]	20448
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.863067
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.136933
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0.00000000
CO2 emissions (mt CO2) [98.236(n)(9)]	0.0
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.00
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.000
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	31281
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)]	490203
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.372000
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.030000
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0.00000000
CO2 emissions (mt CO2) [98.236(n)(9)]	0.0
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.00
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.000
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	31470
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)]	2891581
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.327000
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.068000
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0.00000000
CO2 emissions (mt CO2) [98.236(n)(9)]	0.0
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.00
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0.000

CentrifugalCompressorsDetails:

mt CO2	0
mt CH4	0
Did the facility have any centrifugal compressors subject to reporting under 98.232 [98.236(o)]?	No

ReciprocatingCompressorsDetails:

mt CO2	3.8
mt CH4	25.12
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)]	3.8
Total annual Reciprocating Compressor emissions CH4 Emissions (mt CH4) [98.236(p)(5)(iii)]	25.12
Count of Reciprocating Compressors [98.236(p)(5)(i)]	138

OtherEmissionsFromEquipmentLeaksDetails:

mt CO2	168.1
mt CH4	2227.08
Did this facility use leak surveys to calculate emissions from equipment leaks in accordance with 98.232 [per 98.236(q)]?	Yes
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)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No
Number of complete equipment leak surveys performed during the calendar year [98.236(q)(1)(i)]	2
Optical gas imaging instrument as specified in §60.18 [98.234(a)(1)]	No
Method 21 [98.234(a)(2)]	No
Infrared laser beam illuminated instrument [98.234(a)(3)]	No
Acoustic leak detection device [98.234(a)(5)]	No
Optical gas imaging instrument as specified in §60.5397a [98.234(a)(6)]	Yes
Method 21 as specified in §60.5397a [98.234(a)(7)]	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

OnshorePetroleumAndNaturalGasProductionAndGatheringAndBoostingRowDetails:

Component Type [98.236(q)(2)(i)]	Onshore Production or GB Components, Gas Service - Flange
Total number of surveyed component type identified as leaking, xp [98.236(q)(2)(ii)]	2
Average time the surveyed components are assumed to be leaking and operational, Tp,z (hours) [98.236(q)(2)(iii)]	8784.000000
CO2 Emissions (surveyed components identified as leaking only) (mt CO2) [98.236(q)(2)(iv)]	0.1
CH4 Emissions (surveyed components identified as leaking only) (mt CH4) [98.236(q)(2)(v)]	1.24
Component Type [98.236(q)(2)(i)]	Onshore Production or GB Components, Gas Service - Open-Ended Line
Total number of surveyed component type identified as leaking, xp [98.236(q)(2)(ii)]	4
Average time the surveyed components are assumed to be leaking and operational, Tp,z (hours) [98.236(q)(2)(iii)]	8784.000000
CO2 Emissions (surveyed components identified as leaking only) (mt CO2) [98.236(q)(2)(iv)]	0.1
CH4 Emissions (surveyed components identified as leaking only) (mt CH4) [98.236(q)(2)(v)]	1.64
Component Type [98.236(q)(2)(i)]	Onshore Production or GB Components, Gas Service - Other
Total number of surveyed component type identified as leaking, xp [98.236(q)(2)(ii)]	11
Average time the surveyed components are assumed to be leaking and operational, Tp,z (hours) [98.236(q)(2)(iii)]	4363.090909
CO2 Emissions (surveyed components identified as leaking only) (mt CO2) [98.236(q)(2)(iv)]	0.3
CH4 Emissions (surveyed components identified as leaking only) (mt CH4) [98.236(q)(2)(v)]	6.07
Component Type [98.236(q)(2)(i)]	Onshore Production or GB Components, Gas Service - Valve
Total number of surveyed component type identified as leaking, xp [98.236(q)(2)(ii)]	4
Average time the surveyed components are assumed to be leaking and operational, Tp,z (hours) [98.236(q)(2)(iii)]	8784.000000
CO2 Emissions (surveyed components identified as leaking only) (mt CO2) [98.236(q)(2)(iv)]	0.2
CH4 Emissions (surveyed components identified as leaking only) (mt CH4) [98.236(q)(2)(v)]	2.85

LeaksCalculatedWithCountsFactorsRowDetails:

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)]	231653
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	7027.200000
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	42.5
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	552.40
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)]	7903
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	7027.200000
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	2.6
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	34.12
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)]	4547
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	7027.200000
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	9.5
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	123.23
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)]	70884
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	7027.200000
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	92.7
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	1203.98
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)]	176.37
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	8784.000000
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	4.2
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	67.58
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)]	3270.16
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	8784.000000
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	15.8
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	232.98
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Light crude 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)]	186
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	5856.000000
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	0.0
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	0.12
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Light crude service - Flanges
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)]	296
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	5856.000000
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	0.0
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	0.09
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Light crude 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)]	0
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	5856.000000
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	0.0
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	0.00
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Light crude service - Other equipment leak sources (such as instruments, loading arms, stuffing boxes, compressor seals, dump lever arms, breather caps)
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)]	5856.000000
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	0.0
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	0.00
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Light crude 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)]	148
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	5856.000000
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	0.1
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	0.78
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Light crude service - Pumps
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 - 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 - 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)]	871
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)]	2205
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)]	128
Major Equipment Type [98.236(r)(3)(ii)]	In-line heaters
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	No
Count of Major Equipment Type in Western US [98.236(r)(3)(ii)(B)]	0
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)]	44

MajorOilEquipmentTypeRowDetails:

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)]	13
Major Equipment Type [98.236(r)(3)(ii)]	Heater-treater
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	No
Count of Major Equipment Type in Western US [98.236(r)(3)(ii)(B)]	0
Major Equipment Type [98.236(r)(3)(ii)]	Header
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)]	14

CombustionEmissionsDetails:

mt CO2	581818.3
mt CH4	1225.15
mt N2O	1.087
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	132
Are there external fuel combustion units with a rated heat capacity greater than 5 mmBtu/hr? [98.236(z)(2)(i)]	No
Are there internal fuel combustion units that are not compressor-drivers, with a rated heat capacity greater than 1 mmBtu/hr? [98.236(z)(2)(i)]	No
Are there Internal fuel combustion units of any heat capacity that are compressor-drivers? [98.236(z)(2)(i)]	Yes

LargeCombustionUnitEmissionsRowDetails:

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)]	Field gas, process gas, and/or natural gas that is not of pipeline quality
Quantity of fuel combusted in calendar year [98.236(z)(2)(iii)]	10517332.79
Unit of measure [98.236(z)(2)(iii)	thousand standard cubic feet
CO2 Emissions (mt CO2) [98.236(z)(2)(iv)]	581818.3
CH4 Emissions (mt CH4) [98.236(z)(2)(v)]	1225.15
N2O Emissions (mt N2O) [98.236(z)(2)(vi)]	1.087