GHG Summary Report

CO2 equivalent emissions from facility subparts C-II, SS, and TT (metric tons):153,356.4
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:2015-01-01
GHG Report End Date:2015-12-31
Description of Changes to Calculation Methodology:
Plant Code Indicator:N
Primary NAICS Code:211111
Second Primary NAICS Code:

Parent Company Details:

Parent Company Name:DEVON ENERGY CORP
Address:333 West Sheridan Avenue, Oklahoma City, OK 73102
Percent Ownership Interest:100

Subpart W: Petroleum and Natural Gas Systems

Gas Information Details

Gas Name	Methane
Gas Quantity	4,813.2 (Metric Tons)
Own Result?

Gas Name	Nitrous Oxide
Gas Quantity	0.1 (Metric Tons)
Own Result?

Gas Name	Carbon Dioxide
Gas Quantity	32,996.6 (Metric Tons)
Own Result?

SubpartWSummaryDetails:

Industry Segment Number	2
Industry Segment Name	Onshore petroleum and natural gas production [98.230(a)(2)]
Total Reported CO2 Emissions (mt CO2)	32996.6
Total CO2e Emissions (mt CO2e)	153356.5
Total Reported CH4 Emissions (mt CH4)	4813.20
Total Reported N2O Emissions (mt N2O)	0.100

SubpartWSourceReportingFormRowDetails:

Source Reporting Form	Facility Overview [98.236(aa)]
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)	180.4
Total Reported CH4 Emissions (mt CH4)	3046.16
Source Reporting Form	Natural Gas Driven Pneumatic Pumps [98.236(c)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	11.8
Total Reported CH4 Emissions (mt CH4)	199.90
Source Reporting Form	Acid Gas Removal Units [98.236(d)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	0.0
Source Reporting Form	Dehydrators [98.236(e)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	470.5
Total Reported CH4 Emissions (mt CH4)	0.70
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Well Venting for Liquids Unloading [98.236(f)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	0.1
Total Reported CH4 Emissions (mt CH4)	4.20
Source Reporting Form	Gas Well Completions and Workovers [98.236(g,h)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	231.7
Total Reported CH4 Emissions (mt CH4)	1.40
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Blowdown Vent Stacks [98.236(i)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Source Reporting Form	Production Storage Tanks [98.236(j)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	447.9
Total Reported CH4 Emissions (mt CH4)	288.54
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Transmission Storage Tanks [98.236(k)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Well Testing [98.236(l)]
Required for Selected Industry Segment	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	Associated Gas Venting and Flaring [98.236(m)]
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	Flare Stacks [98.236(n)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	2568.4
Total Reported CH4 Emissions (mt CH4)	15.40
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Centrifugal Compressors [98.236(o)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Source Reporting Form	Reciprocating Compressors [98.236(p)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	2.6
Total Reported CH4 Emissions (mt CH4)	17.10
Source Reporting Form	Equipment Leaks Surveys and Population Counts [98.236(q,r)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	71.0
Total Reported CH4 Emissions (mt CH4)	1197.70
Source Reporting Form	Offshore Petroleum and Natural Gas Production [98.236(s)]
Required for Selected Industry Segment	No
Total Reported CO2 Emissions (mt CO2)	0.0
Total Reported CH4 Emissions (mt CH4)	0.00
Total Reported N2O Emissions (mt N2O)	0.000
Source Reporting Form	Enhanced Oil Recovery Injection Pumps Blowdown [98.236(w)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	0.0
Source Reporting Form	Enhanced Oil Recovery Hydrocarbon Liquids [98.236(x)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	0.0
Source Reporting Form	Combustion Equipment at Onshore Petroleum and Natural Gas Production and Natural Gas Distribution Facilities [98.236(z)]
Required for Selected Industry Segment	Yes
Total Reported CO2 Emissions (mt CO2)	29012.2
Total Reported CH4 Emissions (mt CH4)	42.10
Total Reported N2O Emissions (mt N2O)	0.100

OnshoreRequirementsDetails:

Select the basin associated with this facility [98.236(aa)(1)(i)]	260 - East Texas Basin
Quantity of gas produced in the calendar year from wells (thousand standard cubic feet) [98.236(aa)(1)(i)(A)]	49365713
Quantity of gas produced in the calendar year for sales (thousand standard cubic feet) [98.236(aa)(1)(i)(B)]	39482448
Quantity of crude oil and condensate produced in the calendar year for sales (barrels) [98.236(aa)(1)(i)(C)]	554149.7

OnshoreProductionRequirementsSubBasinRowDetails:

Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	HARRISON, TX (203)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	High permeability gas
Sub-Basin ID	260 - HARRISON, TX (203) - High permeability gas
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	42
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	1
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.89296
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.01626
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	HARRISON, TX (203)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	Other tight reservoir rock
Sub-Basin ID	260 - HARRISON, TX (203) - Other tight reservoir rock
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	97
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	1
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.8931
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.01602
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	HARRISON, TX (203)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	Shale gas
Sub-Basin ID	260 - HARRISON, TX (203) - Shale gas
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	24
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	0
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.8492
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.01684
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	LEON, TX (289)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	High permeability gas
Sub-Basin ID	260 - LEON, TX (289) - High permeability gas
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	8
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	0
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.82084
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.04045
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	NACOGDOCHES, TX (347)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	High permeability gas
Sub-Basin ID	260 - NACOGDOCHES, TX (347) - High permeability gas
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	4
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	0
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.93404
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.01305
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	PANOLA, TX (365)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	High permeability gas
Sub-Basin ID	260 - PANOLA, TX (365) - High permeability gas
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	69
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	1
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.88302
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.0091
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	PANOLA, TX (365)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	Other tight reservoir rock
Sub-Basin ID	260 - PANOLA, TX (365) - Other tight reservoir rock
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	592
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	1
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	11
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.86381
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.01529
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	PANOLA, TX (365)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	Shale gas
Sub-Basin ID	260 - PANOLA, TX (365) - Shale gas
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	348
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	0
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.85617
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.01538
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	RUSK, TX (401)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	Other tight reservoir rock
Sub-Basin ID	260 - RUSK, TX (401) - Other tight reservoir rock
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	5
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	0
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.93504
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.01271
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	SAN AUGUSTINE, TX (405)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	Other tight reservoir rock
Sub-Basin ID	260 - SAN AUGUSTINE, TX (405) - Other tight reservoir rock
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	10
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	0
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.81046
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.01997
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	SAN AUGUSTINE, TX (405)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	Shale gas
Sub-Basin ID	260 - SAN AUGUSTINE, TX (405) - Shale gas
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	7
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	0
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.93851
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.05782
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	SHELBY, TX (419)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	High permeability gas
Sub-Basin ID	260 - SHELBY, TX (419) - High permeability gas
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	41
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	2
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.94634
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.0106
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	SHELBY, TX (419)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	Other tight reservoir rock
Sub-Basin ID	260 - SHELBY, TX (419) - Other tight reservoir rock
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	27
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	0
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.91976
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.01979
Select the County and State in which the Sub-Basin is located [98.236(aa)(1)(ii)(A-B)]	SHELBY, TX (419)
Select the Formation Type of the Sub-Basin [98.236(aa)(1)(ii)(C)]	Shale gas
Sub-Basin ID	260 - SHELBY, TX (419) - Shale gas
Number of producing wells at the end of the calendar year [98.236(aa)(1)(ii)(D)]	9
Number of producing wells acquired during the calendar year [98.236(aa)(1)(ii)(E)]	0
Number of producing wells divested during the calendar year [98.236(aa)(1)(ii)(F)]	0
Number of wells completed during the calendar year [98.236(aa)(1)(ii)(G)]	0
Number of wells permanently taken out of production [98.236(aa)(1)(ii)(H)]	0
Average mole fraction of CH4 in produced gas [98.236(aa)(1)(ii)(I)]	0.85617
Average mole fraction of CO2 in produced gas [98.236(aa)(1)(ii)(J)]	0.01538

PneumaticDeviceVentingDetails:

mt CO2	180.4
mt CH4	3046.16
Does the Facility have any continuous high-bleed pneumatic devices subject to reporting under 98.232 [98.236(b)]?	Yes
Does the Facility have any intermittent bleed pneumatic devices subject to reporting under 98.232 [98.236(b)]?	Yes
Does the Facility have any continuous low-bleed pneumatic devices subject to reporting under 98.232 [98.236(b)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

PneumaticDeviceTypesRowDetails:

Type of Pneumatic Device	High-bleed Pneumatic Devices
Total Number, Countt [98.236(b)(1)(i)]	366
Is the Total Number estimated? (Yes / No) [98.236(b)(1)(ii)]	No
Total CO2 Emissions (mt CO2) [98.236(b)(3)]	108.8
Total CH4 Emissions (mt CH4) [98.236(b)(4)]	1837.7
Actual Count [98.236(b)(1)(ii)(A)]	366
Estimated average number of hours in the calendar year that the pneumatic devices were operating, Tt (hours) [98.236(b)(2)]	7854.0
Type of Pneumatic Device	Intermittent Bleed Pneumatic Devices
Total Number, Countt [98.236(b)(1)(i)]	598
Is the Total Number estimated? (Yes / No) [98.236(b)(1)(ii)]	No
Total CO2 Emissions (mt CO2) [98.236(b)(3)]	62.6
Total CH4 Emissions (mt CH4) [98.236(b)(4)]	1056.2
Actual Count [98.236(b)(1)(ii)(A)]	598
Estimated average number of hours in the calendar year that the pneumatic devices were operating, Tt (hours) [98.236(b)(2)]	7634.0
Type of Pneumatic Device	Low-Bleed Pneumatic Devices
Total Number, Countt [98.236(b)(1)(i)]	803
Is the Total Number estimated? (Yes / No) [98.236(b)(1)(ii)]	No
Total CO2 Emissions (mt CO2) [98.236(b)(3)]	9.0
Total CH4 Emissions (mt CH4) [98.236(b)(4)]	152.2
Actual Count [98.236(b)(1)(ii)(A)]	803
Estimated average number of hours in the calendar year that the pneumatic devices were operating, Tt (hours) [98.236(b)(2)]	7959.0

NaturalGasDrivenPneumaticPumpsDetails:

mt CO2	11.8
mt CH4	199.90
Does 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)]	142
Average estimated number of hours in the calendar year that the natural gas driven pneumatic pumps were operated, T (hours) [98.236(c)(2)]	6175
Total CO2 Emissions (mt CO2) [98.236(c)(3)]	11.8
Total CH4 Emissions (mt CH4) [98.236(c)(4)]	199.9

AcidGasRemovalUnitsDetails:

mt CO2	0.0
Does 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
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

DehydratorsDetails:

mt CO2	470.5
mt CH4	0.70
mt N2O	0.000
Does 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
Does 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
Does the facility have any desiccant dehydrators subject to reporting under 98.232 [98.236(e)]?	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

SmallGlycolDehydrators:

Total Number of Small Glycol Dehydrators [98.236(e)(2)(i)]	2
Vapor Recovery	No
Dehydrator vents to flares or regenerator firebox/fire tubes	Yes
Number of Small Glycol Dehydrators By Vent Control Type, Count [98.236(e)(2)(ii)] [98.236(e)(2)(iv)(A)]	1
Control devices other than vapor recovery, flare or regenerator firebox/fire tubes	No
Emissions vented to flare or regenerator firebox/fire tubes
Total CO2 Emissions (mt CO2) [98.236(e)(2)(iv)(B)] [98.236(e)(2)(v)(A)]	4
Total CH4 Emissions (mt CH4) [98.236(e)(2)(iv)(C)] [98.236(e)(2)(v)(B)]	0
Total N2O Emissions (mt N2O) [98.236(e)(2)(iv)(D)]	0
Emissions that were not vented to a flare or regenerator firebox/fire tubes
Total CO2 Emissions (mt CO2) [98.236(e)(2)(iv)(B)] [98.236(e)(2)(v)(A)]	1.4
Total CH4 Emissions (mt CH4) [98.236(e)(2)(iv)(C)] [98.236(e)(2)(v)(B)]	0.2

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)]	1.0052584E7
Sub-Basin ID [98.236(e)(1)(xviii]	260 - HARRISON, TX (203) - Other tight reservoir rock
Glycol dehydrator feed natural gas flow rate determined by engineering estimate based on best available data (MMscfd) [98.236(e)(1)(ii)]	0.4958
Dehydrator feed natural gas water content (pounds per MMscf) [98.236(e)(1)(iii)]	83.35
Dehydrator outlet natural gas water content (pounds per MMscf) [98.236(e)(1)(iv)]	16.64
Glycol dehydrator absorbent circulation pump type [98.236(e)(1)(v)]	Electric
Dehydrator absorbent circulation rate (gallons per minute) [98.236(e)(1)(vi)]	0.0911337
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
Temperature of the wet natural gas (°F) [98.236(e)(1)(xi)]	100
Pressure of the wet natural gas (psig) [98.236(e)(1)(xii)]	600
Concentration of CO2 in wet natural gas (mole fraction) [98.236(e)(1)(xiv)]	0.03055
Concentration of CH4 in wet natural gas (mole fraction) [98.236(e)(1)(xiii)]	0.68042
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)]	465.1
CH4 Emissions from Flares or Regenerators (mt CH4) [98.236(e)(1)(xvi)(B)]	0.5
N2O Emissions from Flares or Regenerators (mt N2O) [98.236(e)(1)(xvi)(C)]	0
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

WellVentingDetails:

mt CO2	0.1
mt CH4	4.20
Did the facility have any well venting for liquids unloading subject to reporting under 98.232 [98.236(f)]?	Yes
Were BAMM used for any parameters to calculate GHG emissions? [98.3(c)(7)]	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	Yes
Was Calculation Method 1 used to calculate emissions [98.233(f)(1)]?	No
Was Calculation Method 2 used to calculate emissions [98.233(f)(2)]?	Yes
Was Calculation Method 3 used to calculate emissions [98.233(f)(3)]?	Yes

WellVentingCalculationMethodTwoAndThreeRowDetails:

Sub-Basin ID [98.236(f)(2)(i)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Calculation Method [98.236(f)(2)(ii)]	Calculation Methodology 2 [98.233(f)(2)]
Were Plunger Lifts used? [98.236(f)(2)(iii)]	No
Number of wells vented for liquids unloading, W [98.236(f)(2)(iv)]	10
Cumulative number of unloadings vented to the atmosphere, Vp [98.236(f)(2)(v)]	32
Annual natural gas emissions from well venting for liquids unloading (standard cubic feet) [98.236(f)(2)(vi)]	183913
Total CO2 Emissions (mt CO2) [98.236(f)(2)(vii)]	0.1
Total CH4 Emissions (mt CH4) [98.236(f)(2)(viii)]	3.1
Average internal casing diameter, CDp (inches) (Calc. Method 2) [98.236(f)(2)(ix)]	4.48
Sub-Basin ID [98.236(f)(2)(i)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Calculation Method [98.236(f)(2)(ii)]	Calculation Methodology 3 [98.233(f)(3)]
Were Plunger Lifts used? [98.236(f)(2)(iii)]	Yes
Number of wells vented for liquids unloading, W [98.236(f)(2)(iv)]	4
Cumulative number of unloadings vented to the atmosphere, Vp [98.236(f)(2)(v)]	17
Annual natural gas emissions from well venting for liquids unloading (standard cubic feet) [98.236(f)(2)(vi)]	13997.3
Total CO2 Emissions (mt CO2) [98.236(f)(2)(vii)]	0
Total CH4 Emissions (mt CH4) [98.236(f)(2)(viii)]	0.2
Average internal tubing diameter, TDp (inches) (Calc. Method 3) [98.236(f)(2)(x)]	1.79
Sub-Basin ID [98.236(f)(2)(i)]	260 - PANOLA, TX (365) - Shale gas
Calculation Method [98.236(f)(2)(ii)]	Calculation Methodology 3 [98.233(f)(3)]
Were Plunger Lifts used? [98.236(f)(2)(iii)]	Yes
Number of wells vented for liquids unloading, W [98.236(f)(2)(iv)]	3
Cumulative number of unloadings vented to the atmosphere, Vp [98.236(f)(2)(v)]	4
Annual natural gas emissions from well venting for liquids unloading (standard cubic feet) [98.236(f)(2)(vi)]	10934.5
Total CO2 Emissions (mt CO2) [98.236(f)(2)(vii)]	0
Total CH4 Emissions (mt CH4) [98.236(f)(2)(viii)]	0.2
Average internal tubing diameter, TDp (inches) (Calc. Method 3) [98.236(f)(2)(x)]	1.79
Sub-Basin ID [98.236(f)(2)(i)]	260 - SAN AUGUSTINE, TX (405) - Other tight reservoir rock
Calculation Method [98.236(f)(2)(ii)]	Calculation Methodology 2 [98.233(f)(2)]
Were Plunger Lifts used? [98.236(f)(2)(iii)]	No
Number of wells vented for liquids unloading, W [98.236(f)(2)(iv)]	2
Cumulative number of unloadings vented to the atmosphere, Vp [98.236(f)(2)(v)]	2
Annual natural gas emissions from well venting for liquids unloading (standard cubic feet) [98.236(f)(2)(vi)]	46730.2
Total CO2 Emissions (mt CO2) [98.236(f)(2)(vii)]	0
Total CH4 Emissions (mt CH4) [98.236(f)(2)(viii)]	0.7
Average internal casing diameter, CDp (inches) (Calc. Method 2) [98.236(f)(2)(ix)]	4

WellVentingMissingDataProcUsedRowDetails:

Sub-Basin ID [98.236(f)(1)(i)]	260 - SAN AUGUSTINE, TX (405) - Other tight reservoir rock
Calculation Method 2 and 3 (With and without plunger lifts) [Table F.2]	Shut-in/surface/casing pressure (SPp) (Calculation Methodology 2)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where surface pressure was missing, applied the basin average.
Sub-Basin ID [98.236(f)(1)(i)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Calculation Method 2 and 3 (With and without plunger lifts) [Table F.2]	Hours that each well was left open to the atmosphere during each unloading event (HRp,q) (Calculation Methodology 2 or 3)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average basin duration was applied.
Sub-Basin ID [98.236(f)(1)(i)]	260 - PANOLA, TX (365) - Shale gas
Calculation Method 2 and 3 (With and without plunger lifts) [Table F.2]	Hours that each well was left open to the atmosphere during each unloading event (HRp,q) (Calculation Methodology 2 or 3)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average basin duration was applied.
Sub-Basin ID [98.236(f)(1)(i)]	260 - SAN AUGUSTINE, TX (405) - Other tight reservoir rock
Calculation Method 2 and 3 (With and without plunger lifts) [Table F.2]	Hours that each well was left open to the atmosphere during each unloading event (HRp,q) (Calculation Methodology 2 or 3)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average basin duration was applied.

WellCompletionsWorkoversDetails:

mt CO2	231.7
mt CH4	1.40
mt N2O	0.000
Did the facility have any gas well completions or workovers with hydraulic fracturing subject to reporting under 98.232 [98.236(g)]?	Yes
Did the facility have any gas well completions or workovers without hydraulic fracturing subject to reporting under 98.232 [98.236(h)]?	No
Were BAMM used for any parameters to calculate GHG emissions? [98.234(f)(2)(ii)]	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	Yes

WellCompletionsWithHydraulicFracturingRowDetails:

Sub-Basin ID [98.236(g)(1)]	260 - HARRISON, TX (203) - High permeability gas
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions? [98.236(g)(2)(iii)]	Yes
Total count of completions in the calendar year, W [98.236(g)(3)]	1
Equation Used (Select) [98.236(g)(4)]	Equation W-10B
Flow volume vented or sent to a flare, FVs,p (standard cubic feet) [98.236(g)(6)(i)]	786493.0556
Flow rate, FRp,i (standard cubic feet per hour) [98.236(g)(6)(ii)]	8
Annual gas emissions, Es,n (standard cubic feet) [98.236(g)(7)]	786973.0556
Annual total CO2 emissions (mt CO2) [98.236(g)(8)]	45.6
Annual total CH4 emissions (mt CH4) [98.236(g)(9)]	0.3
Annual total N2O emissions (mt N2O) [98.236(g)(10)]	0
Sub-Basin ID [98.236(g)(1)]	260 - SHELBY, TX (419) - High permeability gas
Well Type [98.236(g)(2)(i)]	Vertical
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions? [98.236(g)(2)(iii)]	Yes
Total count of completions in the calendar year, W [98.236(g)(3)]	1
Equation Used (Select) [98.236(g)(4)]	Equation W-10B
Flow volume vented or sent to a flare, FVs,p (standard cubic feet) [98.236(g)(6)(i)]	786493.0556
Flow rate, FRp,i (standard cubic feet per hour) [98.236(g)(6)(ii)]	8
Annual gas emissions, Es,n (standard cubic feet) [98.236(g)(7)]	786973.0556
Annual total CO2 emissions (mt CO2) [98.236(g)(8)]	42.4
Annual total CH4 emissions (mt CH4) [98.236(g)(9)]	0.3
Annual total N2O emissions (mt N2O) [98.236(g)(10)]	0
Sub-Basin ID [98.236(g)(1)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Well Type [98.236(g)(2)(i)]	Vertical
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions? [98.236(g)(2)(iii)]	Yes
Total count of completions in the calendar year, W [98.236(g)(3)]	2
Equation Used (Select) [98.236(g)(4)]	Equation W-10B
Flow volume vented or sent to a flare, FVs,p (standard cubic feet) [98.236(g)(6)(i)]	1572986.1112
Flow rate, FRp,i (standard cubic feet per hour) [98.236(g)(6)(ii)]	8
Annual gas emissions, Es,n (standard cubic feet) [98.236(g)(7)]	1573946.1112
Annual total CO2 emissions (mt CO2) [98.236(g)(8)]	95.8
Annual total CH4 emissions (mt CH4) [98.236(g)(9)]	0.5
Annual total N2O emissions (mt N2O) [98.236(g)(10)]	0
Sub-Basin ID [98.236(g)(1)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions? [98.236(g)(2)(iii)]	Yes
Total count of completions in the calendar year, W [98.236(g)(3)]	1
Equation Used (Select) [98.236(g)(4)]	Equation W-10B
Flow volume vented or sent to a flare, FVs,p (standard cubic feet) [98.236(g)(6)(i)]	0
Flow rate, FRp,i (standard cubic feet per hour) [98.236(g)(6)(ii)]	30
Annual gas emissions, Es,n (standard cubic feet) [98.236(g)(7)]	0
Annual total CO2 emissions (mt CO2) [98.236(g)(8)]	0
Annual total CH4 emissions (mt CH4) [98.236(g)(9)]	0
Annual total N2O emissions (mt N2O) [98.236(g)(10)]	0
Sub-Basin ID [98.236(g)(1)]	260 - PANOLA, TX (365) - Shale gas
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions? [98.236(g)(2)(iii)]	Yes
Total count of completions in the calendar year, W [98.236(g)(3)]	1
Equation Used (Select) [98.236(g)(4)]	Equation W-10B
Flow volume vented or sent to a flare, FVs,p (standard cubic feet) [98.236(g)(6)(i)]	0
Flow rate, FRp,i (standard cubic feet per hour) [98.236(g)(6)(ii)]	9
Annual gas emissions, Es,n (standard cubic feet) [98.236(g)(7)]	81
Annual total CO2 emissions (mt CO2) [98.236(g)(8)]	0
Annual total CH4 emissions (mt CH4) [98.236(g)(9)]	0
Annual total N2O emissions (mt N2O) [98.236(g)(10)]	0

WellWorkoversWithHydraulicFracturingRowDetails:

Sub-Basin ID [98.236(g)(1)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Well Type [98.236(g)(2)(i)]	Vertical
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Workovers? [98.236(g)(2)(iii)]	Yes
Total count of workovers [98.236(g)(3)]	1
Equation Used (Select) [98.236(g)(4)]	Equation W-10B
Flow volume vented or sent to a flare, FVs,p (standard cubic feet) [98.236(g)(6)(i)]	786493.0556
Flow rate, FRp,i (standard cubic feet per hour) [98.236(g)(6)(ii)]	8
Annual gas emissions (standard cubic feet) [98.236(g)(7)]	786973.0556
Annual Total CO2 emissions (mt CO2) [98.236(g)(8)]	47.9
Annual Total CH4 emissions (mt CH4) [98.236(g)(9)]	0.3
Annual Total N2O emissions (mt N2O) [98.236(g)(10)]	0

WellMissingDataProceduresUsedRowDetails:

Sub-Basin ID [98.236(g)(1)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Vented natural gas volume (scf)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average flare volume from all completions was applied.
Sub-Basin ID [98.236(g)(1)]	260 - SHELBY, TX (419) - High permeability gas
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Vented natural gas volume (scf)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average flare volume from all completions was applied.
Sub-Basin ID [98.236(g)(1)]	260 - HARRISON, TX (203) - High permeability gas
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Vented natural gas volume (scf)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average flare volume from all completions was applied.
Sub-Basin ID [98.236(g)(1)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Cumulative completion gas flow back time, Sum of Tp,i values (hours)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average duration of all completions events was calculated and applied.
Sub-Basin ID [98.236(g)(1)]	260 - SHELBY, TX (419) - High permeability gas
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Cumulative completion gas flow back time, Sum of Tp,i values (hours)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average duration of all completions events was calculated and applied.
Sub-Basin ID [98.236(g)(1)]	260 - HARRISON, TX (203) - High permeability gas
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Cumulative completion gas flow back time, Sum of Tp,i values (hours)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average duration of all completions events was calculated and applied.
Sub-Basin ID [98.236(g)(1)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Cumulative completion gas flow back time, Sum of Tp,s values (hours)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average duration of all completions events was calculated and applied.
Sub-Basin ID [98.236(g)(1)]	260 - SHELBY, TX (419) - High permeability gas
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Cumulative completion gas flow back time, Sum of Tp,s values (hours)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average duration of all completions events was calculated and applied.
Sub-Basin ID [98.236(g)(1)]	260 - HARRISON, TX (203) - High permeability gas
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Cumulative completion gas flow back time, Sum of Tp,s values (hours)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average duration of all completions events was calculated and applied.
Sub-Basin ID [98.236(g)(1)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Measured flowback rate during well completions (standard cubic feet per hour)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average flowback rate from all completions was applied.
Sub-Basin ID [98.236(g)(1)]	260 - SHELBY, TX (419) - High permeability gas
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Measured flowback rate during well completions (standard cubic feet per hour)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average flowback rate from all completions was applied.
Sub-Basin ID [98.236(g)(1)]	260 - HARRISON, TX (203) - High permeability gas
Well Type [98.236(g)(2)(i)]	Horizontal
Is gas flared? [98.236(g)(2)(ii)]	Yes
Reduced Emission Completions or Workovers [98.236(g)(2)(iii)]	Yes
Completion or Workover?	Completion
Hydraulic Fracturing	With Hydraulic Fracturing
Flaring	With Flaring
Gas Well Completions with Hydraulic Fracturing [Table G.1]	Measured flowback rate during well completions (standard cubic feet per hour)
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where missing, an average flowback rate from all completions was applied.

AtmosphericTanksDetails:

mt CO2	447.9
mt CH4	288.54
mt N2O	0.000
Did the facility send hydrocarbon liquids to atmospheric storage tanks that are subject to reporting under 98.232 [98.236(j)]?	Yes
Was Calculation Method 1 used to calculate emissions [(98.233(j)(1)]?	Yes
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]	Yes

AtmosphericTanksCalculationMethodOneOrTwoSubBasinRowDetails:

Sub-Basin ID [98.236(j)(1)(i)]	260 - HARRISON, TX (203) - High permeability gas
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Number of wells sending oil to gas-liquid separators or directly to atmospheric tanks [98.236(j)(1)(ix)]	1
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	130
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	45
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	30.77
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)]	0.30813
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.30813
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.02265
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.02265
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.11821
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	0.58708
For Onshore petroleum and natural gas production facilities, are the only wells used to calculate "total volume of oil" in the sub-basin wildcat or delineation wells subject to a 2-year delay in reporting? [98.236(j)(1)(iii)]	No
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)]	4302.59
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)]	0
Estimated number of atmospheric tanks not on well pads [98.236(j)(1)(xi)]	0
Sub-Basin ID [98.236(j)(1)(i)]	260 - HARRISON, TX (203) - Other tight reservoir rock
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	ProMax
Number of wells sending oil to gas-liquid separators or directly to atmospheric tanks [98.236(j)(1)(ix)]	2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	91
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	82.5
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	53.81
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	4
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.7023
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.7023
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.03548
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.03548
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	9.68633
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.05729
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.00002
For Onshore petroleum and natural gas production facilities, are the only wells used to calculate "total volume of oil" in the sub-basin wildcat or delineation wells subject to a 2-year delay in reporting? [98.236(j)(1)(iii)]	No
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)]	7393.74
Were any emissions from atmospheric tanks controlled with vapor recovery systems? [98.236(j)(1)(xii)]	No
Were any emissions from atmospheric tanks vented directly to the atmosphere? [98.236(j)(1)(xiii)(A)]	No
Were any emissions from atmospheric tanks vented to flare(s)? [98.236(j)(1)(xiv)]	Yes
Count of atmospheric tanks [98.236(j)(1)(x)]	4
Estimated number of atmospheric tanks not on well pads [98.236(j)(1)(xi)]	0
Sub-Basin ID [98.236(j)(1)(i)]	260 - LEON, TX (289) - High permeability gas
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	ProMax
Number of wells sending oil to gas-liquid separators or directly to atmospheric tanks [98.236(j)(1)(ix)]	3
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	130
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	45
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	30.77
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	9
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.3091
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.30914
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.02267
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.02267
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.52986
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	2.63753
For Onshore petroleum and natural gas production facilities, are the only wells used to calculate "total volume of oil" in the sub-basin wildcat or delineation wells subject to a 2-year delay in reporting? [98.236(j)(1)(iii)]	No
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)]	19311.96
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)]	9
Estimated number of atmospheric tanks not on well pads [98.236(j)(1)(xi)]	0
Sub-Basin ID [98.236(j)(1)(i)]	260 - LEON, TX (289) - High permeability gas
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Number of wells sending oil to gas-liquid separators or directly to atmospheric tanks [98.236(j)(1)(ix)]	1
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	130
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	45
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	30.77
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	6
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.30913
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.30913
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.02267
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.02267
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.27104
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	1.34924
For Onshore petroleum and natural gas production facilities, are the only wells used to calculate "total volume of oil" in the sub-basin wildcat or delineation wells subject to a 2-year delay in reporting? [98.236(j)(1)(iii)]	No
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)]	9879.07
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)]	6
Estimated number of atmospheric tanks not on well pads [98.236(j)(1)(xi)]	6
Sub-Basin ID [98.236(j)(1)(i)]	260 - PANOLA, TX (365) - High permeability gas
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Number of wells sending oil to gas-liquid separators or directly to atmospheric tanks [98.236(j)(1)(ix)]	1
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	130
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	45
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	30.77
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)]	0.30813
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.30813
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.02265
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.02265
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.10776
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	0.53522
For Onshore petroleum and natural gas production facilities, are the only wells used to calculate "total volume of oil" in the sub-basin wildcat or delineation wells subject to a 2-year delay in reporting? [98.236(j)(1)(iii)]	No
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)]	3922.56
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)]	0
Estimated number of atmospheric tanks not on well pads [98.236(j)(1)(xi)]	0
Sub-Basin ID [98.236(j)(1)(i)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Number of wells sending oil to gas-liquid separators or directly to atmospheric tanks [98.236(j)(1)(ix)]	5
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	91.89
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	62.89
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	53.81
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)]	11
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.7023
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.7023
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.03548
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.03548
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.96566
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	6.97725
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	8.2642
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.04503
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.00002
For Onshore petroleum and natural gas production facilities, are the only wells used to calculate "total volume of oil" in the sub-basin wildcat or delineation wells subject to a 2-year delay in reporting? [98.236(j)(1)(iii)]	No
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)]	28910.11
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)]	11
Estimated number of atmospheric tanks not on well pads [98.236(j)(1)(xi)]	6
Sub-Basin ID [98.236(j)(1)(i)]	260 - PANOLA, TX (365) - Shale gas
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 2
Number of wells sending oil to gas-liquid separators or directly to atmospheric tanks [98.236(j)(1)(ix)]	2
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	63
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	46
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	30.77
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)]	3
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.23871
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.23871
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.0224
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.0224
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.28317
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	1.10129
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	12.34534
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.06582
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.00002
For Onshore petroleum and natural gas production facilities, are the only wells used to calculate "total volume of oil" in the sub-basin wildcat or delineation wells subject to a 2-year delay in reporting? [98.236(j)(1)(iii)]	No
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)]	8062.98
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)]	3
Estimated number of atmospheric tanks not on well pads [98.236(j)(1)(xi)]	3
Sub-Basin ID [98.236(j)(1)(i)]	260 - SAN AUGUSTINE, TX (405) - Other tight reservoir rock
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	ProMax
Number of wells sending oil to gas-liquid separators or directly to atmospheric tanks [98.236(j)(1)(ix)]	6
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	62.33
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	70.17
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	53.81
Count of tanks with flaring emission control measures [98.236(j)(1)(xiv)(A)]	21
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.69128
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.7023
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.03548
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.03879
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(1)(xiv)(B)]	37.3789
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(1)(xiv)(C)]	0.17504
Annual N2O emissions from flaring (mt N2O) [98.236(j)(1)(xiv)(D)]	0.00006
For Onshore petroleum and natural gas production facilities, are the only wells used to calculate "total volume of oil" in the sub-basin wildcat or delineation wells subject to a 2-year delay in reporting? [98.236(j)(1)(iii)]	No
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)]	26480.64
Were any emissions from atmospheric tanks controlled with vapor recovery systems? [98.236(j)(1)(xii)]	No
Were any emissions from atmospheric tanks vented directly to the atmosphere? [98.236(j)(1)(xiii)(A)]	No
Were any emissions from atmospheric tanks vented to flare(s)? [98.236(j)(1)(xiv)]	Yes
Count of atmospheric tanks [98.236(j)(1)(x)]	21
Estimated number of atmospheric tanks not on well pads [98.236(j)(1)(xi)]	0
Sub-Basin ID [98.236(j)(1)(i)]	260 - SAN AUGUSTINE, TX (405) - Shale gas
Select Calculation Method Used (Select from list) [98.236(j)(1)(ii)]	Calculation Methodology 1
Name of software package used for Calculation Method 1 [98.236(j)(1)(ii)]	ProMax
Number of wells sending oil to gas-liquid separators or directly to atmospheric tanks [98.236(j)(1)(ix)]	1
Average gas-liquid separator or non-separator equipment temperature (°F) [98.236(j)(1)(iv)]	63
Average gas-liquid separator or non-separator equipment pressure (psig) [98.236(j)(1)(v)]	46
Average sales oil or stabilized oil API gravity (degrees) [98.236(j)(1)(vi)]	68.72
Count of tanks that vented directly to the atmosphere [98.236(j)(1)(xiii)(A)]	3
Minimum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.12219
Maximum concentration of CH4 in flash gas (mole fraction) [98.236(j)(1)(viii)]	0.12219
Minimum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]]	0.01013
Maximum concentration of CO2 in flash gas (mole fraction) [98.236(j)(1)(vii)]	0.01013
Annual CO2 emissions from venting (mt CO2) [98.236(j)(1)(xiii)(B)]	0.43479
Annual CH4 emissions from venting (mt CH4) [98.236(j)(1)(xiii)(C)]	1.91386
For Onshore petroleum and natural gas production facilities, are the only wells used to calculate "total volume of oil" in the sub-basin wildcat or delineation wells subject to a 2-year delay in reporting? [98.236(j)(1)(iii)]	No
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)]	7588.8
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)]	3
Estimated number of atmospheric tanks not on well pads [98.236(j)(1)(xi)]	0

AtmosphericTanksCalculationMethodThreeRowDetails:

Estimate of fraction of oil/condensate throughput sent to tanks in basin with flaring [98.236(j)(2)(i)(B)]	0.24512
Estimate of fraction of oil/condensate throughput sent to tanks with vapor recovery system control measures [98.236(j)(2)(i)(C)]	0
Count of atmospheric tanks in basin [98.236(j)(2)(i)(D)]	375
Count of wells with gas-liquid separators, Count [98.236(j)(2)(i)(E)]	206
Count of wells without gas-liquid separators, Count [98.236(j)(2)(i)(F)]	860
For Onshore petroleum and natural gas production facilities, are the only wells in the sub-basin that were used to calculate the total annual oil/condensate throughput wildcat or delineation wells subject to a 2 year delay in reporting? [98.236(j)(2)(i)(A)]	No
Total annual oil/condensate throughput that is sent to all atmospheric tanks (barrels per year) [98.236(j)(2)(i)(A)]	438297.22

AtmosphericTanksCalcMethodThreeNoFlaringRowDetails:

Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - HARRISON, TX (203) - High permeability gas
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	28
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	5
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	11.5
Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - HARRISON, TX (203) - Other tight reservoir rock
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	69
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	12.5
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	28.7
Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - HARRISON, TX (203) - Shale gas
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	13
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	2.9
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	6.8
Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - LEON, TX (289) - High permeability gas
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)]	0.6
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	1.4
Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - NACOGDOCHES, TX (347) - High permeability gas
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)]	0.3
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.7
Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - PANOLA, TX (365) - High permeability gas
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	35
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	6.3
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	14.5
Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	130
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	52.1
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	119.6
Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - PANOLA, TX (365) - Shale gas
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	63
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	31.7
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	72.7
Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - RUSK, TX (401) - Other tight reservoir rock
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	3
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	0.4
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	1
Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - SAN AUGUSTINE, TX (405) - Other tight reservoir rock
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)]	0.3
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	0.7
Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - SHELBY, TX (419) - High permeability gas
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	4
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	3.8
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	8.8
Sub-Basin ID [98.236(j)(2)(ii)(A)]	260 - SHELBY, TX (419) - Other tight reservoir rock
Count of tanks that did not control emissions with flares [98.236(j)(2)(ii)(B)]	3
Annual CO2 emissions from tanks without flares (mt CO2) [98.236(j)(2)(ii)(C)]	2.2
Annual CH4 emissions from tanks without flares (mt CH4) [98.236(j)(2)(ii)(D)]	5.1

AtmosphericTanksCalcMethodThreeWithFlaringRowDetails:

Sub-Basin ID [98.236(j)(2)(iii)(A)]	260 - HARRISON, TX (203) - Other tight reservoir rock
Count of tanks with flaring emission control measures [98.236(j)(2)(iii)(B)]	2
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(2)(iii)(C)]	2.1
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(2)(iii)(D)]	0
Annual N2O emissions from flaring (mt N2O) [98.236(j)(2)(iii)(E)]	0
Sub-Basin ID [98.236(j)(2)(iii)(A)]	260 - PANOLA, TX (365) - High permeability gas
Count of tanks with flaring emission control measures [98.236(j)(2)(iii)(B)]	0
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(2)(iii)(C)]	5.3
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(2)(iii)(D)]	0
Annual N2O emissions from flaring (mt N2O) [98.236(j)(2)(iii)(E)]	0
Sub-Basin ID [98.236(j)(2)(iii)(A)]	260 - PANOLA, TX (365) - Other tight reservoir rock
Count of tanks with flaring emission control measures [98.236(j)(2)(iii)(B)]	0
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(2)(iii)(C)]	136
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(2)(iii)(D)]	0.9
Annual N2O emissions from flaring (mt N2O) [98.236(j)(2)(iii)(E)]	0
Sub-Basin ID [98.236(j)(2)(iii)(A)]	260 - PANOLA, TX (365) - Shale gas
Count of tanks with flaring emission control measures [98.236(j)(2)(iii)(B)]	0
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(2)(iii)(C)]	112.8
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(2)(iii)(D)]	0.7
Annual N2O emissions from flaring (mt N2O) [98.236(j)(2)(iii)(E)]	0
Sub-Basin ID [98.236(j)(2)(iii)(A)]	260 - RUSK, TX (401) - Other tight reservoir rock
Count of tanks with flaring emission control measures [98.236(j)(2)(iii)(B)]	2
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
Annual N2O emissions from flaring (mt N2O) [98.236(j)(2)(iii)(E)]	0
Sub-Basin ID [98.236(j)(2)(iii)(A)]	260 - SAN AUGUSTINE, TX (405) - Other tight reservoir rock
Count of tanks with flaring emission control measures [98.236(j)(2)(iii)(B)]	7
Annual CO2 emissions from flaring (mt CO2) [98.236(j)(2)(iii)(C)]	2.1
Annual CH4 emissions from flaring (mt CH4) [98.236(j)(2)(iii)(D)]	0
Annual N2O emissions from flaring (mt N2O) [98.236(j)(2)(iii)(E)]	0

AtmosphericTanksMissingDataProcUsedRowDetails:

Sub-Basin ID	260 - HARRISON, TX (203) - High permeability gas
For gas-liquid separator, non-separator equipment, or well with oil throughput ≥10 barrels/day using Calculation Method 1 or 2 [Table J.1]	Well production oil and gas composition
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where subbasin composition representation was missing, a composition from an equivalent formation in an adjacent county was used. Where subbasin composition representation was missing, and a composition from an equivalent formation in an adjacent county was not available, a composition from a like-kind formation (oil versus gas formations) was used.
Sub-Basin ID	260 - PANOLA, TX (365) - High permeability gas
For gas-liquid separator, non-separator equipment, or well with oil throughput ≥10 barrels/day using Calculation Method 1 or 2 [Table J.1]	Well production oil and gas composition
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where subbasin composition representation was missing, a composition from an equivalent formation in an adjacent county was used. Where subbasin composition representation was missing, and a composition from an equivalent formation in an adjacent county was not available, a composition from a like-kind formation (oil versus gas formations) was used.
Sub-Basin ID	260 - PANOLA, TX (365) - Shale gas
For gas-liquid separator, non-separator equipment, or well with oil throughput ≥10 barrels/day using Calculation Method 1 or 2 [Table J.1]	Well production oil and gas composition
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where subbasin composition representation was missing, a composition from an equivalent formation in an adjacent county was used. Where subbasin composition representation was missing, and a composition from an equivalent formation in an adjacent county was not available, a composition from a like-kind formation (oil versus gas formations) was used.

WellTestingDetails:

mt CO2	0.0
Did the facility perform well testing that resulted in venting or flaring subject to reporting under 98.232 [98.236(l)]?	No
mt CH4	0.00
mt N2O	0.000
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

AssociatedGasVentingFlaringDetails:

mt CO2	0.0
mt CH4	0.00
mt N2O	0.000
Did the facility have any associated gas venting or flaring subject to reporting under 98.232 [98.236(m)]?	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

FlareStacksDetails:

mt CO2	2568.4
mt CH4	15.40
mt N2O	0.000
Does 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)]	465810
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)]	3679200
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	214.2
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	1.3
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465815
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)]	987840
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	57.5
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.3
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465816
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)]	3679200
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	214.2
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	1.3
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465817
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)]	3659040
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	213
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	1.3
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465818
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)]	3578400
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	208.3
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	1.2
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465819
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)]	3648960
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	212.4
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	1.3
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465820
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)]	3679200
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	214.2
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	1.3
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465821
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)]	3618720
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	210.6
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	1.2
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465823
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)]	3669120
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	213.6
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	1.3
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465824
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)]	3679200
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	214.2
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	1.3
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465825
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)]	3679200
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	214.2
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	1.3
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465826
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)]	181440
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	10.6
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.1
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465832
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)]	3659040
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	213
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	1.3
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0
Unique Name or ID Number for the Flare Stack [98.236(n)(1)]	465853
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)]	2721600
Flare combustion efficiency (decimal value) [98.236(n)(6)]	0.98
Mole fraction of CH4 in flare feed gas, XCH4 [98.236(n)(7)]	0.89263
Mole fraction of CO2 in flare feed gas, XCO2 [98.236(n)(8)]	0.0193
Fraction of feed gas sent to un-lit flare, Zu [98.236(n)(5)]	0
CO2 emissions (mt CO2) [98.236(n)(9)]	158.4
CH4 Emissions (mt CH4) (Eq. W-19) [98.236(n)(10)]	0.9
N2O Emissions (mt N2O) (Eq. W-40) [98.236(n)(11)]	0

CentrifugalCompressorsDetails:

mt CO2	0.0
mt CH4	0.00
Does the facility have any centrifugal compressors subject to reporting under 98.232 [98.236(o)]?	No
Were BAMM used for any parameters to calculate GHG emissions? [98.234(g)(6)(i)]	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

CentrifugalCompressorsEmissionFactorsSampleDataRowDetails:

Compressor Mode [98.236(o)(3)(ii)(A)]	Operating
Compressor Source [98.236(o)(3)(ii)(A)]	Wet seal
Compressor Mode [98.236(o)(3)(ii)(A)]	Operating
Compressor Source [98.236(o)(3)(ii)(A)]	Blowdown valve
Compressor Mode [98.236(o)(3)(ii)(A)]	Not-operating
Compressor Source [98.236(o)(3)(ii)(A)]	Isolation valve

ReciprocatingCompressorsDetails:

mt CO2	2.6
mt CH4	17.10
Does the facility have any reciprocating compressors subject to reporting under 98.232?	Yes
Were BAMM used for any parameters to calculate GHG emissions? [98.234(g)(6)(i)]	No
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)]	2.6
Total annual Reciprocating Compressor emissions CH4 Emissions (mt CH4) [98.236(p)(5)(iii)]	17.10
Count of Reciprocating Compressors [98.236(p)(5)(i)]	94

ReciprocatingCompressorsEmissionFactorsSampleDataRowDetails:

Compressor Mode [98.236(p)(3)(ii)(A)]	Operating
Compressor Source [98.236(p)(3)(ii)(A)]	Blowdown valve
Compressor Mode [98.236(p)(3)(ii)(A)]	Operating
Compressor Source [98.236(p)(3)(ii)(A)]	Rod packing
Compressor Mode [98.236(p)(3)(ii)(A)]	Standby-pressurized
Compressor Source [98.236(p)(3)(ii)(A)]	Blowdown valve
Compressor Mode [98.236(p)(3)(ii)(A)]	Not-operating-depressurized
Compressor Source [98.236(p)(3)(ii)(A)]	Isolation valve

OtherEmissionsFromEquipmentLeaksDetails:

mt CO2	71.0
mt CH4	1197.70
Is this facility required to report equipment leaks via surveys under 98.236(a) [98.236(q)]?	No
Is this facility required to report equipment leaks via population counts under 98.236(a) [98.236(r)]?	Yes
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	Yes
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

MajorEquipmentMissingDataProcUsedRowDetails:

Emission Source Type/ Major Equipment Type	Header
Geographic Location	Western U.S.
Parameters	Count of Major Equipment Type
Measurement Frequency	N/A (i.e., activity data parameters that are determined but not measured)
Procedures used [98.235(h)]	Where header data was unavailable, a count of headers (1) was applied to each facility.

GasProcessingEmissionsFactorsRowDetails:

Component Type [98.236(q)(2)(i)]	Compressor Components, Gas Service - Valve
Component Type [98.236(q)(2)(i)]	Compressor Components, Gas Service - Connector
Component Type [98.236(q)(2)(i)]	Compressor Components, Gas Service - Open-ended Line
Component Type [98.236(q)(2)(i)]	Compressor Components, Gas Service - Pressure Relief Valve
Component Type [98.236(q)(2)(i)]	Compressor Components, Gas Service - Meter
Component Type [98.236(q)(2)(i)]	Non-Compressor Components, Gas Service - Valve
Component Type [98.236(q)(2)(i)]	Non-Compressor Components, Gas Service - Connector
Component Type [98.236(q)(2)(i)]	Non-Compressor Components, Gas Service - Open-ended Line
Component Type [98.236(q)(2)(i)]	Non-Compressor components, Gas Service - Pressure Relief Valve
Component Type [98.236(q)(2)(i)]	Non-Compressor components, Gas Service - Meter

GasTransmissionCompressionEmissionFactorsRowDetails:

Component Type [98.236(q)(2)(i)]	Compressor Components, Gas Service - Valve
Component Type [98.236(q)(2)(i)]	Compressor Components, Gas Service - Connector
Component Type [98.236(q)(2)(i)]	Compressor Components, Gas Service - Open-ended Line
Component Type [98.236(q)(2)(i)]	Compressor Components, Gas Service - Pressure Relief Valve
Component Type [98.236(q)(2)(i)]	Compressor Components, Gas Service - Meter
Component Type [98.236(q)(2)(i)]	Non-Compressor Components, Gas Service - Valve
Component Type [98.236(q)(2)(i)]	Non-Compressor Components, Gas Service - Connector
Component Type [98.236(q)(2)(i)]	Non-Compressor Components, Gas Service - Open-ended Line
Component Type [98.236(q)(2)(i)]	Non-Compressor components, Gas Service - Pressure Relief Valve
Component Type [98.236(q)(2)(i)]	Non-Compressor components, Gas Service - Meter

UndergroundStorageEmissionsFactorsRowDetails:

Component Type [98.236(q)(2)(i)]	Storage Station, Gas Service - Valve
Component Type [98.236(q)(2)(i)]	Storage Station, Gas Service - Connector
Component Type [98.236(q)(2)(i)]	Storage Station, Gas Service - Open-ended Line
Component Type [98.236(q)(2)(i)]	Storage Station, Gas Service - Pressure Relief Valve
Component Type [98.236(q)(2)(i)]	Storage Station, Gas Service - Meter

LngStorageEmissionsFactorsRowDetails:

Component Type [98.236(q)(2)(i)]	LNG Storage, LNG Service - Valve
Component Type [98.236(q)(2)(i)]	LNG Storage, LNG Service - Connector
Component Type [98.236(q)(2)(i)]	LNG Storage, LNG Service - Pump Seal
Component Type [98.236(q)(2)(i)]	LNG Storage, LNG Service - Other

ImportExportEmissionsFactorsRowDetails:

Component Type [98.236(q)(2)(i)]	LNG Terminal, LNG Service - Valve
Component Type [98.236(q)(2)(i)]	LNG Terminal, LNG Service - Connector
Component Type [98.236(q)(2)(i)]	LNG Terminal, LNG Service - Pump Seal
Component Type [98.236(q)(2)(i)]	LNG Terminal, LNG Service - Other

GasDistributionEmissionsFactorsRowDetails:

Component Type [98.236(q)(2)(i)]	Transmission-Distribution Transfer Station Components, Gas Service - Connector
Component Type [98.236(q)(2)(i)]	Transmission-Distribution Transfer Station Components, Gas Service - Block Valve
Component Type [98.236(q)(2)(i)]	Transmission-Distribution Transfer Station Components, Gas Service - Control Valve
Component Type [98.236(q)(2)(i)]	Transmission-Distribution Transfer Station Components, Gas Service - Pressure Relief Valve
Component Type [98.236(q)(2)(i)]	Transmission-Distribution Transfer Station Components, Gas Service - Orifice Meter
Component Type [98.236(q)(2)(i)]	Transmission-Distribution Transfer Station Components, Gas Service - Regulator
Component Type [98.236(q)(2)(i)]	Transmission-Distribution Transfer Station Components, Gas Service - Open-ended line

LeaksCalculatedWithCountsFactorsRowDetails:

Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Connectors
Service Type [98.236(r)(1)(i)]	Gas Service
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)]	164051
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	7411.27
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	21
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	354.2
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Open ended lines
Service Type [98.236(r)(1)(i)]	Gas Service
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)]	5038
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	7310.71
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	1.2
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	19.6
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Pressure relief valves
Service Type [98.236(r)(1)(i)]	Gas Service
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)]	2335
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	7211.88
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	3.3
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	55.7
Emission Source Type (Eq. W-32A) [98.232(c)(21)] [98.233(r)]	Valves
Service Type [98.236(r)(1)(i)]	Gas Service
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)]	50565
Average estimated time that the emission source type was operational in the calendar year, Te (hours) [98.236(r)(1)(iii)]	7325.89
CO2 Emissions (mt CO2) [98.236(r)(1)(iv)]	45.5
CH4 Emissions (mt CH4) [98.236(r)(1)(v)]	768.2

GasEstimatingEmissionsRowDetails:

Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Storage wellheads, Gas Service - Valves
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Storage wellheads, Gas Service - Connector
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Storage wellheads, Gas Service - Open-ended line
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Storage wellheads, Gas Service - Pressure Relief Valve

LngStorageEstimatingEmissionsRowDetails:

Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]

LNG Storage Compressor, Gas Service - Vapor Recovery Compressor

LngImportExportEstimatingEmissionsRowDetails:

Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]

LNG Terminals Compressor, Gas Service - Vapor Recovery Compressor

GasDistributionTDEstimatingEmissionsRowDetails:

Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Below Grade T-D Station, Gas Service, Inlet Pressure > 300 psig
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Below Grade T-D Station, Gas Service, Inlet Pressure 100 to 300 psig
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Below Grade T-D Station, Gas Service, Inlet Pressure < 100 psig

GasDistributionMREstimatingEmissionsRowDetails:

Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Below Grade M-R Station, Gas Service, Inlet Pressure > 300 psig
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Below Grade M-R Station, Gas Service, Inlet Pressure 100 to 300 psig
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Below Grade M-R Station, Gas Service, Inlet Pressure < 100 psig

MainGasDistributionEstimatingEmissionsRowDetails:

Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Distribution Mains, Gas Service - Unprotected Steel
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Distribution Mains, Gas Service - Protected Steel
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Distribution Mains, Gas Service - Plastic
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Distribution Mains, Gas Service - Cast Iron

ServicesGasDistributionEstimatingEmissionsRowDetails:

Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Distribution Services, Gas Service - Unprotected Steel
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Distribution Services, Gas Service - Protected Steel
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Distribution Services, Gas Service - Plastic
Emission Source Type (Eq. W-32A) [98.232] [98.233(r)(1)]	Distribution Services, Gas Service - Copper

MajorGasEquipmentTypeRowDetails:

Major Equipment Type [98.236(r)(3)(ii)]	Wellhead
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	Yes
Geographic Loction (according to Table W-1D) [98.236(r)(3)(ii)(A)]	Western U.S.
Count of Major Equipment Type [98.236(r)(3)(ii)(B)]	1273
Major Equipment Type [98.236(r)(3)(ii)]	Separators
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	Yes
Geographic Loction (according to Table W-1D) [98.236(r)(3)(ii)(A)]	Western U.S.
Count of Major Equipment Type [98.236(r)(3)(ii)(B)]	381
Major Equipment Type [98.236(r)(3)(ii)]	Meters/piping
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	Yes
Geographic Loction (according to Table W-1D) [98.236(r)(3)(ii)(A)]	Western U.S.
Count of Major Equipment Type [98.236(r)(3)(ii)(B)]	1191
Major Equipment Type [98.236(r)(3)(ii)]	Compressors
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	Yes
Geographic Loction (according to Table W-1D) [98.236(r)(3)(ii)(A)]	Western U.S.
Count of Major Equipment Type [98.236(r)(3)(ii)(B)]	94
Major Equipment Type [98.236(r)(3)(ii)]	In-line heaters
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	No
Major Equipment Type [98.236(r)(3)(ii)]	Dehydrators
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	Yes
Geographic Loction (according to Table W-1D) [98.236(r)(3)(ii)(A)]	Western U.S.
Count of Major Equipment Type [98.236(r)(3)(ii)(B)]	3

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)]	No
Major Equipment Type [98.236(r)(3)(ii)]	Heater-treater
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	No
Major Equipment Type [98.236(r)(3)(ii)]	Header
Equipment type present at facility? [98.236(r)(3)(ii)(A)]	No

OffshoreEmissionsDetails:

mt CO2	0.0
mt CH4	0.00
mt N2O	0.000

OffshoreEmissionsSourcesRowDetails:

Emission Source [98.236(s)]	Amine Unit
Emission Source [98.236(s)]	Combustion Flares - Light Smoke - No Pilot Fuel-flaring
Emission Source [98.236(s)]	Combustion Flares - Light Smoke - Pilot Fuel - pilot
Emission Source [98.236(s)]	Combustion Flares - Light Smoke - Pilot Fuel-flaring
Emission Source [98.236(s)]	Combustion Flares - Medium Smoke - No Pilot Fuel - flaring
Emission Source [98.236(s)]	Combustion Flares - Medium Smoke - Pilot Fuel - flaring
Emission Source [98.236(s)]	Combustion Flares - Medium Smoke - Pilot Fuel - pilot
Emission Source [98.236(s)]	Combustion Flares - No Smoke - No Pilot Fuel - flaring
Emission Source [98.236(s)]	Combustion Flares - No Smoke - Pilot Fuel - flaring
Emission Source [98.236(s)]	Combustion Flares - No Smoke - Pilot Fuel - pilot
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal dry - gas
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal dry - NG liq
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal dry - heavy oil
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal dry - light oil
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal dry - oil/water
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal dry - oil/water/gas
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal wet - gas
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal wet - NG liq
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal wet - heavy oil
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal wet - light oil
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal wet - oil/water
Emission Source [98.236(s)]	Fugitives - Compressor centrifugal wet - oil/water/gas
Emission Source [98.236(s)]	Fugitives - Compressor reciprocating - gas
Emission Source [98.236(s)]	Fugitives - Compressor reciprocating - NG liq
Emission Source [98.236(s)]	Fugitives - Compressor reciprocating - heavy oil
Emission Source [98.236(s)]	Fugitives - Compressor reciprocating - light oil
Emission Source [98.236(s)]	Fugitives - Compressor reciprocating - oil/water
Emission Source [98.236(s)]	Fugitives - Compressor reciprocating - oil/water/gas
Emission Source [98.236(s)]	Fugitives - Connectors - gas
Emission Source [98.236(s)]	Fugitives - Connectors - NG liq
Emission Source [98.236(s)]	Fugitives - Connectors - heavy oil
Emission Source [98.236(s)]	Fugitives - Connectors - light oil
Emission Source [98.236(s)]	Fugitives - Connectors - oil/water
Emission Source [98.236(s)]	Fugitives - Connectors - oil/water/gas
Emission Source [98.236(s)]	Fugitives - Flanges - gas
Emission Source [98.236(s)]	Fugitives - Flanges - NG liq
Emission Source [98.236(s)]	Fugitives - Flanges - heavy oil
Emission Source [98.236(s)]	Fugitives - Flanges - light oil
Emission Source [98.236(s)]	Fugitives - Flanges - oil/water
Emission Source [98.236(s)]	Fugitives - Flanges - oil/water/gas
Emission Source [98.236(s)]	Fugitives - Open-Ended Lines - gas
Emission Source [98.236(s)]	Fugitives - Open-Ended Lines - NG liq
Emission Source [98.236(s)]	Fugitives - Open-Ended Lines - heavy oil
Emission Source [98.236(s)]	Fugitives - Open-Ended Lines - light oil
Emission Source [98.236(s)]	Fugitives - Open-Ended Lines - oil/water
Emission Source [98.236(s)]	Fugitives - Open-Ended Lines - oil/water/gas
Emission Source [98.236(s)]	Fugitives - Other Equipment - gas
Emission Source [98.236(s)]	Fugitives - Other Equipment - NG liq
Emission Source [98.236(s)]	Fugitives - Other Equipment - heavy oil
Emission Source [98.236(s)]	Fugitives - Other Equipment - light oil
Emission Source [98.236(s)]	Fugitives - Other Equipment - oil/water
Emission Source [98.236(s)]	Fugitives - Other Equipment - oil/water/gas
Emission Source [98.236(s)]	Fugitives - Pumps - gas
Emission Source [98.236(s)]	Fugitives - Pumps - NG liq
Emission Source [98.236(s)]	Fugitives - Pumps - heavy oil
Emission Source [98.236(s)]	Fugitives - Pumps - light oil
Emission Source [98.236(s)]	Fugitives - Pumps - oil/water
Emission Source [98.236(s)]	Fugitives - Pumps - oil/water/gas
Emission Source [98.236(s)]	Fugitives - Valves - gas
Emission Source [98.236(s)]	Fugitives - Valves - NG liq
Emission Source [98.236(s)]	Fugitives - Valves - heavy oil
Emission Source [98.236(s)]	Fugitives - Valves - light oil
Emission Source [98.236(s)]	Fugitives - Valves - oil/water
Emission Source [98.236(s)]	Fugitives - Valves - oil/water/gas
Emission Source [98.236(s)]	Glycol Dehydrator Unit
Emission Source [98.236(s)]	Losses from Flashing
Emission Source [98.236(s)]	Mud Degassing - oil-based muds
Emission Source [98.236(s)]	Mud Degassing - water-based muds
Emission Source [98.236(s)]	Mud Degassing - synthetic-based muds
Emission Source [98.236(s)]	Pneumatic Pump
Emission Source [98.236(s)]	Pressure/Level Controllers
Emission Source [98.236(s)]	Storage Tank Operations - crude oil
Emission Source [98.236(s)]	Storage Tank Operations - condensate
Emission Source [98.236(s)]	Cold Vent

EnhancedOilRecoveryInjectionPumpBlowdownDetails:

mt CO2	0.0
Did the facility use CO2 EOR injection during the calendar year [98.236(w)]?	No
Did any EOR injection pump blowdowns occur at the facility during the calendar year [98.236(w)]?	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

EnhancedOilRecoveryHydrocarbonLiquidsDissolvedDetails:

mt CO2	0.0
Does the facility have hydrocarbon liquids that were produced from enhanced oil recovery operations subject to reporting under 98.232 [98.236(x)]?	No
Were missing data procedures used for any parameters to calculate GHG emissions? [98.235]	No

CombustionEmissionsDetails:

mt CO2	29012.2
mt CH4	42.10
mt N2O	0.100
Does 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)]	Yes
Total Number of combustion units meeting the above criteria [98.236(z)(1)(ii)]	52
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)]	Yes
Are there Internal fuel combustion units of any heat capacity that are compressor-drivers? [98.236(z)(2)(i)]	Yes

LargeCombustionUnitEmissionsRowDetails:

Type of combustion unit [98.236(z)(2)(i)]	Internal fuel combustion units of any heat capacity that are compressor-drivers
Type of fuel combusted [98.236(z)(2)(ii)]	Field gas and/or process gas
Quantity of fuel combusted in calendar year [98.236(z)(2)(iii)]	490944.70406
Unit of measure [98.236(z)(2)(iii)	thousand standard cubic feet
CO2 Emissions (mt CO2) [98.236(z)(2)(iv)]	29006.9
CH4 Emissions (mt CH4) [98.236(z)(2)(v)]	42.1
N2O Emissions (mt N2O) [98.236(z)(2)(vi)]	0.1
Type of combustion unit [98.236(z)(2)(i)]	Internal fuel combustion units that are not compressor-drivers, with a rated heat capacity greater than 1 mmBtu/hr
Type of fuel combusted [98.236(z)(2)(ii)]	Petroleum products: distillate fuel oil No. 2
Quantity of fuel combusted in calendar year [98.236(z)(2)(iii)]	515
Unit of measure [98.236(z)(2)(iii)	gallons
CO2 Emissions (mt CO2) [98.236(z)(2)(iv)]	5.3
CH4 Emissions (mt CH4) [98.236(z)(2)(v)]	0
N2O Emissions (mt N2O) [98.236(z)(2)(vi)]	0