Facility Name:WRB Refining LP Wood River Refinery
Facility Identifier:
Facility Reporting Year:2023
Facility Location:
Address: 900 SOUTH CENTRAL AVENUE
City: ROXANA
State: IL
Postal Code: 62084

Facility Site Details:
CO2 equivalent emissions from facility subparts C-II, SS, and TT (metric tons):4,197,007.5
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:2023-01-01
GHG Report End Date:2023-12-31
Description of Changes to Calculation Methodology:
Plant Code Indicator:N
Primary NAICS Code:324110
Second Primary NAICS Code:

Parent Company Details:
Parent Company Name:PHILLIPS 66
Address:2331 Citywest Blvd, Houston,  TX 77042
Percent Ownership Interest:100

Subpart C: General Stationary Fuel Combustion

Gas Information Details

Gas NameCarbon Dioxide
Gas Quantity2,099,357.1 (Metric Tons)
Own Result?

Gas NameBiogenic Carbon dioxide
Gas Quantity0 (Metric Tons)
Own Result?

Gas NameMethane
Gas Quantity117.41 (Metric Tons)
Own Result?

Gas NameNitrous Oxide
Gas Quantity23.322 (Metric Tons)
Own Result?

Unit Details:
Unit Name : GP-Purchased Diesel Combustion
Unit Description :
Small Unit Aggregation Details:
Use Ivt Indicator: Y
Highest Maximum Rated Heat Input Capacity: 10
Cumulative Maximum Rated Heat Input Capacity: 10

Emission Details:
Annual CO2 mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)
Annual Fossil fuel based CO2 Emissions: 4334.8 (metric tons)

Tier Fuel Details:
Fuel : Distillate Fuel Oil No. 2
Tier Name : Tier 1 (Equation C-1)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
4334.8 (Metric Tons) 0.18 (Metric Tons) 0.035 (Metric Tons) 4.4 (Metric Tons) 10.5 (Metric Tons)


Unit Name : CP-Main Plant RFG Combustion
Unit Description :
Common Pipe Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 1275
Cumulative Maximum Rated Heat Input Capacity: 8422.1

Emission Details:
Annual Biogenic CO2 Emissions: 0 (metric tons)
Annual Fossil fuel based CO2 Emissions: 1855235.4 (metric tons)

Tier Fuel Details:
Fuel : Fuel Gas
Tier Name : Tier 3 (Equation C-5, gaseous fuel)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
1855235.4 (Metric Tons) 106.93 (Metric Tons) 21.385 (Metric Tons) 2673.1 (Metric Tons) 6372.8 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 8447
Total number of carbon content substitute data values : 313
Frequency of carbon content determinations : Hourly
Total number of operating hours in the reporting year for which missing data substitution was used for fuel usage : 40

Molecular Weight Information :
Total number of valid molecular weight determinations : 8448
Total number of molecular weight substitute data values : 312
Frequency of molecular weight determinations : Hourly
Molar Volume Constant (MVC) used : 836.6 (scf/kg-mole)

Unit Name : DU-4 Charge Heater, H-24
Unit Type : PRH (Process Heater)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 314 (mmBtu/hr)

Emission Details:
Annual CO2 mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)

Tier Fuel Details:
Fuel : Fuel Gas
Tier Name : Tier 3 (Equation C-5, gaseous fuel)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
81174.1 (Metric Tons) 4.45 (Metric Tons) 0.890 (Metric Tons) 111.2 (Metric Tons) 265.2 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 8667
Total number of carbon content substitute data values : 93
Frequency of carbon content determinations : Hourly
Total number of operating hours in the reporting year for which missing data substitution was used for fuel usage : 2

Molecular Weight Information :
Total number of valid molecular weight determinations : 365
Total number of molecular weight substitute data values : 0
Frequency of molecular weight determinations : Daily
Molar Volume Constant (MVC) used : 836.6 (scf/kg-mole)

Unit Name : HCNHT
Unit Type : PRH (Process Heater)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 39 (mmBtu/hr)

Emission Details:
Annual CO2 mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)

Tier Fuel Details:
Fuel : Natural Gas (Weighted U.S. Average)
Tier Name : Tier 2 (Equation C-2a)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31
Frequency of HHV determinations : Daily

Tier 2 Monthly HHV Details :
JanuaryFebruaryMarchAprilMayJuneJulyAugustSeptemberOctoberNovemberDecember
N N N N N N N N N N N N

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
8316.9 (Metric Tons) 0.16 (Metric Tons) 0.016 (Metric Tons) 3.9 (Metric Tons) 4.7 (Metric Tons)


Unit Name : CEU Thermal Oxidizer
Unit Type : RTO (Regenerative thermal oxidizer)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 5 (mmBtu/hr)

Emission Details:
Annual CO2 mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)

Tier Fuel Details:
Fuel : Natural Gas (Weighted U.S. Average)
Tier Name : Tier 2 (Equation C-2a)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31
Frequency of HHV determinations : Daily

Tier 2 Monthly HHV Details :
JanuaryFebruaryMarchAprilMayJuneJulyAugustSeptemberOctoberNovemberDecember
N N N N N N N N N N N N

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
1268.0 (Metric Tons) 0.02 (Metric Tons) 0.002 (Metric Tons) 0.6 (Metric Tons) 0.7 (Metric Tons)


Unit Name : Boiler 19
Unit Type : OB (Boiler, other)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 405 (mmBtu/hr)

Emission Details:
Annual CO2 mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)

Tier Fuel Details:
Fuel : Natural Gas (Weighted U.S. Average)
Tier Name : Tier 3 (Equation C-5, gaseous fuel)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
2040.3 (Metric Tons) 0.04 (Metric Tons) 0.004 (Metric Tons) 1.0 (Metric Tons) 1.1 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 13
Total number of carbon content substitute data values : 0
Frequency of carbon content determinations : Daily
Total number of operating hours in the reporting year for which missing data substitution was used for fuel usage : 0

Molecular Weight Information :
Total number of valid molecular weight determinations : 13
Total number of molecular weight substitute data values : 0
Frequency of molecular weight determinations : Daily
Molar Volume Constant (MVC) used : 836.6 (scf/kg-mole)

Fuel : Fuel Gas
Tier Name : Tier 3 (Equation C-5, gaseous fuel)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
58169.1 (Metric Tons) 3.37 (Metric Tons) 0.673 (Metric Tons) 84.2 (Metric Tons) 200.7 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 7137
Total number of carbon content substitute data values : 240
Frequency of carbon content determinations : Hourly
Total number of operating hours in the reporting year for which missing data substitution was used for fuel usage : 0

Molecular Weight Information :
Total number of valid molecular weight determinations : 7138
Total number of molecular weight substitute data values : 239
Frequency of molecular weight determinations : Hourly
Molar Volume Constant (MVC) used : 836.6 (scf/kg-mole)

Unit Name : VF-4 Charge Heater, H-28
Unit Type : PRH (Process Heater)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 66 (mmBtu/hr)

Emission Details:
Annual CO2 mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)

Tier Fuel Details:
Fuel : Fuel Gas
Tier Name : Tier 3 (Equation C-5, gaseous fuel)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
14508.9 (Metric Tons) 0.80 (Metric Tons) 0.159 (Metric Tons) 19.9 (Metric Tons) 47.5 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 8667
Total number of carbon content substitute data values : 93
Frequency of carbon content determinations : Hourly
Total number of operating hours in the reporting year for which missing data substitution was used for fuel usage : 2

Molecular Weight Information :
Total number of valid molecular weight determinations : 365
Total number of molecular weight substitute data values : 0
Frequency of molecular weight determinations : Daily
Molar Volume Constant (MVC) used : 836.6 (scf/kg-mole)

Unit Name : Benzene Barge Loading MVC
Unit Type : OCS (Other combustion source)
Unit Description :
Other Unit Name : Enclosed Vapor Combustor
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 10.9 (mmBtu/hr)

Emission Details:
Annual CO2 mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)

Tier Fuel Details:
Fuel : Natural Gas (Weighted U.S. Average)
Tier Name : Tier 2 (Equation C-2a)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31
Frequency of HHV determinations : Daily

Tier 2 Monthly HHV Details :
JanuaryFebruaryMarchAprilMayJuneJulyAugustSeptemberOctoberNovemberDecember
N N N N N N N N N N N N

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
1204.4 (Metric Tons) 0.02 (Metric Tons) 0.002 (Metric Tons) 0.6 (Metric Tons) 0.7 (Metric Tons)


Unit Name : CP-West Property NG (SRU/SCOT/WWTP)
Unit Description :
Common Pipe Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 40
Cumulative Maximum Rated Heat Input Capacity: 120

Emission Details:
Annual Biogenic CO2 Emissions: 0 (metric tons)
Annual Fossil fuel based CO2 Emissions: 27637.6 (metric tons)

Tier Fuel Details:
Fuel : Natural Gas (Weighted U.S. Average)
Tier Name : Tier 2 (Equation C-2a)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31
Frequency of HHV determinations : Daily

Tier 2 Monthly HHV Details :
JanuaryFebruaryMarchAprilMayJuneJulyAugustSeptemberOctoberNovemberDecember
N N N N N N N N N N N N

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
27637.6 (Metric Tons) 0.52 (Metric Tons) 0.052 (Metric Tons) 13.0 (Metric Tons) 15.5 (Metric Tons)


Unit Name : GP-Purchased Gasoline Combustion
Unit Description :
Small Unit Aggregation Details:
Use Ivt Indicator: Y
Highest Maximum Rated Heat Input Capacity: 10
Cumulative Maximum Rated Heat Input Capacity: 10

Emission Details:
Annual CO2 mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)
Annual Fossil fuel based CO2 Emissions: 2761.6 (metric tons)

Tier Fuel Details:
Fuel : Motor Gasoline
Tier Name : Tier 1 (Equation C-1)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
2761.6 (Metric Tons) 0.12 (Metric Tons) 0.024 (Metric Tons) 2.9 (Metric Tons) 7.0 (Metric Tons)


Unit Name : GP-Purchased Propane Combustion
Unit Description :
Small Unit Aggregation Details:
Use Ivt Indicator: Y
Highest Maximum Rated Heat Input Capacity: 10
Cumulative Maximum Rated Heat Input Capacity: 10

Emission Details:
Annual CO2 mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)
Annual Fossil fuel based CO2 Emissions: 5.7 (metric tons)

Tier Fuel Details:
Fuel : Propane
Tier Name : Tier 1 (Equation C-1)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
5.7 (Metric Tons) 0.00 (Metric Tons) 0.000 (Metric Tons) 0.0 (Metric Tons) 0.0 (Metric Tons)


Unit Name : Boiler 18-1
Unit Type : OB (Boiler, other)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 213.4 (mmBtu/hr)

Emission Details:
Annual CO2 mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)

Tier Fuel Details:
Fuel : Natural Gas (Weighted U.S. Average)
Tier Name : Tier 3 (Equation C-5, gaseous fuel)
Tier Methodology Start Date : 2023-01-01
Tier Methodology End Date : 2023-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
42700.3 (Metric Tons) 0.80 (Metric Tons) 0.080 (Metric Tons) 19.9 (Metric Tons) 23.7 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 231
Total number of carbon content substitute data values : 0
Frequency of carbon content determinations : Daily
Total number of operating hours in the reporting year for which missing data substitution was used for fuel usage : 0

Molecular Weight Information :
Total number of valid molecular weight determinations : 231
Total number of molecular weight substitute data values : 0
Frequency of molecular weight determinations : Daily
Molar Volume Constant (MVC) used : 836.6 (scf/kg-mole)


Non-Operating Unit Details:
Unit Name : CP-DW - H20, H21, and H36
Configuration Type :
Unit Type :

Subpart P: Hydrogen Production


CEMS Monitoring Location (CML) Details

Gas Information Details

Gas NameCarbon Dioxide
Gas Quantity1,215,344.5 (Metric Tons)
Own Result?

Gas NameBiogenic Carbon dioxide
Gas Quantity0 (Metric Tons)
Own Result?

Gas NameMethane
Gas Quantity0 (Metric Tons)
Own Result?

Gas NameNitrous Oxide
Gas Quantity0 (Metric Tons)
Own Result?

Annual quantity of carbon, other than CO2, collected and transferred off site in either gas, liquid, or solid forms, excluding methanol: ()

No Cems Hydrogen Unit Details:
Unit Name: Hydrogen Plant No. 1 (HP-1)
Unit Type: Hydrogen production process unit
Unit Description:
CO2Emissions: 325939.7 (Metric Tons)
Annual Quantity of Hydrogen Produced: ()
Annual quantity of ammonia intentionally produced as a desired product, if applicable: ()
Annual quantity of methanol intentionally produced as a desired product, if applicable: ()
Fuel/FeedStock Details:
Feedstock name:
Fuel/FeedStock Type:
Annual Fuel/Feedstock Consumed: ()
Feedstock name:
Fuel/FeedStock Type:
Annual Fuel/Feedstock Consumed: ()

No Cems Hydrogen Unit Details:
Unit Name: Hydrogen Plant No. 2 (HP-2)
Unit Type: Hydrogen production process unit
Unit Description:
CO2Emissions: 548034.1 (Metric Tons)
Annual Quantity of Hydrogen Produced: ()
Annual quantity of ammonia intentionally produced as a desired product, if applicable: ()
Annual quantity of methanol intentionally produced as a desired product, if applicable: ()
Fuel/FeedStock Details:
Feedstock name:
Fuel/FeedStock Type:
Annual Fuel/Feedstock Consumed: ()
Feedstock name:
Fuel/FeedStock Type:
Annual Fuel/Feedstock Consumed: ()

No Cems Hydrogen Unit Details:
Unit Name: Steam Methane Reformer
Unit Type: Hydrogen production process unit
Unit Description:
CO2Emissions: 341370.7 (Metric Tons)
Annual Quantity of Hydrogen Produced: ()
Annual quantity of ammonia intentionally produced as a desired product, if applicable: ()
Annual quantity of methanol intentionally produced as a desired product, if applicable: ()
Fuel/FeedStock Details:
Feedstock name:
Fuel/FeedStock Type:
Annual Fuel/Feedstock Consumed: ()
Feedstock name:
Fuel/FeedStock Type:
Annual Fuel/Feedstock Consumed: ()

Subpart Y: Petroleum Refineries

Gas Information Details

Gas NameCarbon Dioxide
Gas Quantity857,862 (Metric Tons)
Own Result?

Gas NameBiogenic Carbon dioxide
Gas Quantity0 (Metric Tons)
Own Result?

Gas NameMethane
Gas Quantity336.89 (Metric Tons)
Own Result?

Gas NameNitrous Oxide
Gas Quantity4.76 (Metric Tons)
Own Result?

Flare Gas Details

Name or ID: Distilling Flare
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? Y
Type of flare: Steam assisted
Other Flare type:

Flare service type: General facility flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(ii)(A) - Equation Y-1a Gas Composition Monitored
NameValueOwn Result?
CO2Emissions1997.8 (Metric Tons)N

NameValueOwn Result?
CH4Emissions6.03 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.020 (Metric Tons)N

Y1a Equation Details

Were flare gas data used as inputs to Equation Y-1a collected on a mass or volumetric basis: Volumetric basis
Frequency of measurement data: Daily
Annual volume of flare gas combusted: 36974749.65 scf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: The flare flowmeter manufacturer recommends biennial calibration of the meter and suggests a diagnostic check of the system annually to verify if it is working correctly. WRR ensures these are performed as per manufacturer recommendations. Quarterly visual inspections are also performed to inspect all components for integrity, all electrical connections for continuity, oxidation, and galvanic corrosion, and all mechanical connections for leakage and meter installation is per design (tracing/insulation is place as required, no steam leaks on the meter, etc.).
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Annual average molecular weight: 17.03111723 kg/kg-mole
Method(s) used to determine the molecular weight of the flare gas:
Other (specify)
Specify other method: Mass spectrometry
Number of days missing data procedures were used for annual average molecular weight of the flare gas: 0
Annual average carbon content of the flare gas: 0.738603836 decimal fraction; kg carbon/kg flare gas
Method(s) used to determine the carbon content of the flare gas:
Other (specify)
Other annual average concentration: Mass spectrometry
Number of days missing data procedures were used for average carbon content of the flare gas: 0

Name or ID: Arom North Flare
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? Y
Type of flare: Steam assisted
Other Flare type:

Flare service type: General facility flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(ii)(A) - Equation Y-1a Gas Composition Monitored
NameValueOwn Result?
CO2Emissions2563.0 (Metric Tons)N

NameValueOwn Result?
CH4Emissions7.74 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.026 (Metric Tons)N

Y1a Equation Details

Were flare gas data used as inputs to Equation Y-1a collected on a mass or volumetric basis: Volumetric basis
Frequency of measurement data: Daily
Annual volume of flare gas combusted: 47755928.42 scf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: The flare flowmeter manufacturer recommends biennial calibration of the meter and suggests a diagnostic check of the system annually to verify if it is working correctly. WRR ensures these are performed as per manufacturer recommendations. Quarterly visual inspections are also performed to inspect all components for integrity, all electrical connections for continuity, oxidation, and galvanic corrosion, and all mechanical connections for leakage and meter installation is per design (tracing/insulation is place as required, no steam leaks on the meter, etc.).
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Annual average molecular weight: 16.94478222 kg/kg-mole
Method(s) used to determine the molecular weight of the flare gas:
Other (specify)
Specify other method: Mass spectrometry
Number of days missing data procedures were used for annual average molecular weight of the flare gas: 0
Annual average carbon content of the flare gas: 0.737406081 decimal fraction; kg carbon/kg flare gas
Method(s) used to determine the carbon content of the flare gas:
Other (specify)
Other annual average concentration: Mass spectrometry
Number of days missing data procedures were used for average carbon content of the flare gas: 0

Name or ID: LPG Triangle Manifold
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? N
Type of flare: Unassisted
Other Flare type:

Flare service type: Other (specify)
Other Flare service type: Meter Prover Maintenance Flare for LPG Pipeline

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(iii) - Equation Y-3 Start-up, Shutdown, Malfunction
NameValueOwn Result?
CO2Emissions0.3 (Metric Tons)N

NameValueOwn Result?
CH4Emissions0.00 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.000 (Metric Tons)N

Y3 Equation Details

Total number of start-up, shutdown, or malfunction (SSM) events exceeding 500,000 scf/day: 0

Name or ID: Distilling West Flare
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? Y
Type of flare: Air-assisted
Other Flare type:

Flare service type: General facility flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(ii)(A) - Equation Y-1a Gas Composition Monitored
NameValueOwn Result?
CO2Emissions6890.6 (Metric Tons)N

NameValueOwn Result?
CH4Emissions20.80 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.069 (Metric Tons)N

Y1a Equation Details

Were flare gas data used as inputs to Equation Y-1a collected on a mass or volumetric basis: Volumetric basis
Frequency of measurement data: Daily
Annual volume of flare gas combusted: 128137143 scf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: The flare flowmeter manufacturer recommends biennial calibration of the meter and suggests a diagnostic check of the system annually to verify if it is working correctly. WRR ensures these are performed as per manufacturer recommendations. Quarterly visual inspections are also performed to inspect all components for integrity, all electrical connections for continuity, oxidation, and galvanic corrosion, and all mechanical connections for leakage and meter installation is per design (tracing/insulation is place as required, no steam leaks on the meter, etc.).
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Annual average molecular weight: 16.931964 kg/kg-mole
Method(s) used to determine the molecular weight of the flare gas:
Other (specify)
Specify other method: Mass spectrometry
Number of days missing data procedures were used for annual average molecular weight of the flare gas: 0
Annual average carbon content of the flare gas: 0.739426029 decimal fraction; kg carbon/kg flare gas
Method(s) used to determine the carbon content of the flare gas:
Other (specify)
Other annual average concentration: Mass spectrometry
Number of days missing data procedures were used for average carbon content of the flare gas: 0

Name or ID: Hydrogen Plant No. 1 Flare
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? Y
Type of flare: Steam assisted
Other Flare type:

Flare service type: Unit flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(iii) - Equation Y-3 Start-up, Shutdown, Malfunction
NameValueOwn Result?
CO2Emissions11259.4 (Metric Tons)N

NameValueOwn Result?
CH4Emissions33.99 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.113 (Metric Tons)N

Y3 Equation Details

Total number of start-up, shutdown, or malfunction (SSM) events exceeding 500,000 scf/day: 2

Name or ID: VOC Flare #1
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? N
Type of flare: Unassisted
Other Flare type:

Flare service type: Unit flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(ii)(A) - Equation Y-1a Gas Composition Monitored
NameValueOwn Result?
CO2Emissions5726.9 (Metric Tons)N

NameValueOwn Result?
CH4Emissions17.29 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.057 (Metric Tons)N

Y1a Equation Details

Were flare gas data used as inputs to Equation Y-1a collected on a mass or volumetric basis: Volumetric basis
Frequency of measurement data: Daily
Annual volume of flare gas combusted: 97635518.91 scf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: The flare flowmeter manufacturer recommends biennial calibration of the meter and suggests a diagnostic check of the system annually to verify if it is working correctly. WRR ensures these are performed as per manufacturer recommendations. Quarterly visual inspections are also performed to inspect all components for integrity, all electrical connections for continuity, oxidation, and galvanic corrosion, and all mechanical connections for leakage and meter installation is per design (tracing/insulation is place as required, no steam leaks on the meter, etc.).
Number of days missing data procedures were used for annual volume of flare gas combusted: 2
Annual average molecular weight: 18.11328928 kg/kg-mole
Method(s) used to determine the molecular weight of the flare gas:
Chromatographic analysis: manufacturer's instructions

Number of days missing data procedures were used for annual average molecular weight of the flare gas: 0
Annual average carbon content of the flare gas: 0.753466394 decimal fraction; kg carbon/kg flare gas
Method(s) used to determine the carbon content of the flare gas:
Chromatographic analysis: manufacturer's instructions

Number of days missing data procedures were used for average carbon content of the flare gas: 0

Name or ID: VOC Flare #2
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? N
Type of flare: Unassisted
Other Flare type:

Flare service type: Unit flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(ii)(A) - Equation Y-1a Gas Composition Monitored
NameValueOwn Result?
CO2Emissions5727.8 (Metric Tons)N

NameValueOwn Result?
CH4Emissions17.29 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.057 (Metric Tons)N

Y1a Equation Details

Were flare gas data used as inputs to Equation Y-1a collected on a mass or volumetric basis: Volumetric basis
Frequency of measurement data: Daily
Annual volume of flare gas combusted: 97649519.14 scf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: The flare flowmeter manufacturer recommends biennial calibration of the meter and suggests a diagnostic check of the system annually to verify if it is working correctly. WRR ensures these are performed as per manufacturer recommendations. Quarterly visual inspections are also performed to inspect all components for integrity, all electrical connections for continuity, oxidation, and galvanic corrosion, and all mechanical connections for leakage and meter installation is per design (tracing/insulation is place as required, no steam leaks on the meter, etc.).
Number of days missing data procedures were used for annual volume of flare gas combusted: 2
Annual average molecular weight: 18.11531303 kg/kg-mole
Method(s) used to determine the molecular weight of the flare gas:
Chromatographic analysis: manufacturer's instructions

Number of days missing data procedures were used for annual average molecular weight of the flare gas: 0
Annual average carbon content of the flare gas: 0.753471451 decimal fraction; kg carbon/kg flare gas
Method(s) used to determine the carbon content of the flare gas:
Chromatographic analysis: manufacturer's instructions

Number of days missing data procedures were used for average carbon content of the flare gas: 0

Name or ID: Coker North Flare
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? Y
Type of flare: Steam assisted
Other Flare type:

Flare service type: Emergency only flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(ii)(A) - Equation Y-1a Gas Composition Monitored
NameValueOwn Result?
CO2Emissions1235.1 (Metric Tons)N

NameValueOwn Result?
CH4Emissions3.73 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.012 (Metric Tons)N

Y1a Equation Details

Were flare gas data used as inputs to Equation Y-1a collected on a mass or volumetric basis: Volumetric basis
Frequency of measurement data: Daily
Annual volume of flare gas combusted: 22970433.2 scf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: The flare flowmeter manufacturer recommends biennial calibration of the meter and suggests a diagnostic check of the system annually to verify if it is working correctly. WRR ensures these are performed as per manufacturer recommendations. Quarterly visual inspections are also performed to inspect all components for integrity, all electrical connections for continuity, oxidation, and galvanic corrosion, and all mechanical connections for leakage and meter installation is per design (tracing/insulation is place as required, no steam leaks on the meter, etc.).
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Annual average molecular weight: 16.95239617 kg/kg-mole
Method(s) used to determine the molecular weight of the flare gas:
Other (specify)
Specify other method: Mass spectrometry
Number of days missing data procedures were used for annual average molecular weight of the flare gas: 0
Annual average carbon content of the flare gas: 0.738590946 decimal fraction; kg carbon/kg flare gas
Method(s) used to determine the carbon content of the flare gas:
Other (specify)
Other annual average concentration: Mass spectrometry
Number of days missing data procedures were used for average carbon content of the flare gas: 0

Name or ID: Alky Flare
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? Y
Type of flare: Steam assisted
Other Flare type:

Flare service type: General facility flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(ii)(A) - Equation Y-1a Gas Composition Monitored
NameValueOwn Result?
CO2Emissions10904.4 (Metric Tons)N

NameValueOwn Result?
CH4Emissions32.91 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.109 (Metric Tons)N

Y1a Equation Details

Were flare gas data used as inputs to Equation Y-1a collected on a mass or volumetric basis: Volumetric basis
Frequency of measurement data: Daily
Annual volume of flare gas combusted: 189702442.1 scf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: The flare flowmeter manufacturer recommends biennial calibration of the meter and suggests a diagnostic check of the system annually to verify if it is working correctly. WRR ensures these are performed as per manufacturer recommendations. Quarterly visual inspections are also performed to inspect all components for integrity, all electrical connections for continuity, oxidation, and galvanic corrosion, and all mechanical connections for leakage and meter installation is per design (tracing/insulation is place as required, no steam leaks on the meter, etc.).
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Annual average molecular weight: 18.90187721 kg/kg-mole
Method(s) used to determine the molecular weight of the flare gas:
Other (specify)
Specify other method: Mass spectrometry
Number of days missing data procedures were used for annual average molecular weight of the flare gas: 0
Annual average carbon content of the flare gas: 0.716821699 decimal fraction; kg carbon/kg flare gas
Method(s) used to determine the carbon content of the flare gas:
Other (specify)
Other annual average concentration: Mass spectrometry
Number of days missing data procedures were used for average carbon content of the flare gas: 0

Name or ID: Hydrogen Plant No. 2 Flare
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? N
Type of flare: Steam assisted
Other Flare type:

Flare service type: General facility flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(ii)(A) - Equation Y-1a Gas Composition Monitored
NameValueOwn Result?
CO2Emissions2968.8 (Metric Tons)N

NameValueOwn Result?
CH4Emissions8.96 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.030 (Metric Tons)N

Y1a Equation Details

Were flare gas data used as inputs to Equation Y-1a collected on a mass or volumetric basis: Volumetric basis
Frequency of measurement data: Daily
Annual volume of flare gas combusted: 107944535.5 scf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: The flare flowmeter manufacturer recommends biennial calibration of the meter and suggests a diagnostic check of the system annually to verify if it is working correctly. WRR ensures these are performed as per manufacturer recommendations. Quarterly visual inspections are also performed to inspect all components for integrity, all electrical connections for continuity, oxidation, and galvanic corrosion, and all mechanical connections for leakage and meter installation is per design (tracing/insulation is place as required, no steam leaks on the meter, etc.).
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Annual average molecular weight: 18.34130417 kg/kg-mole
Method(s) used to determine the molecular weight of the flare gas:
Chromatographic analysis: manufacturer's instructions

Number of days missing data procedures were used for annual average molecular weight of the flare gas: 337
Annual average carbon content of the flare gas: 0.340413456 decimal fraction; kg carbon/kg flare gas
Method(s) used to determine the carbon content of the flare gas:
Chromatographic analysis: manufacturer's instructions

Number of days missing data procedures were used for average carbon content of the flare gas: 337

Name or ID: Lubes Flare
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? Y
Type of flare: Steam assisted
Other Flare type:

Flare service type: General facility flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(ii)(A) - Equation Y-1a Gas Composition Monitored
NameValueOwn Result?
CO2Emissions1675.7 (Metric Tons)N

NameValueOwn Result?
CH4Emissions5.06 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.017 (Metric Tons)N

Y1a Equation Details

Were flare gas data used as inputs to Equation Y-1a collected on a mass or volumetric basis: Volumetric basis
Frequency of measurement data: Daily
Annual volume of flare gas combusted: 31149265.34 scf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: The flare flowmeter manufacturer recommends biennial calibration of the meter and suggests a diagnostic check of the system annually to verify if it is working correctly. WRR ensures these are performed as per manufacturer recommendations. Quarterly visual inspections are also performed to inspect all components for integrity, all electrical connections for continuity, oxidation, and galvanic corrosion, and all mechanical connections for leakage and meter installation is per design (tracing/insulation is place as required, no steam leaks on the meter, etc.).
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Annual average molecular weight: 16.92414717 kg/kg-mole
Method(s) used to determine the molecular weight of the flare gas:
Chromatographic analysis: manufacturer's instructions

Number of days missing data procedures were used for annual average molecular weight of the flare gas: 0
Annual average carbon content of the flare gas: 0.740029402 decimal fraction; kg carbon/kg flare gas
Method(s) used to determine the carbon content of the flare gas:
Chromatographic analysis: manufacturer's instructions

Number of days missing data procedures were used for average carbon content of the flare gas: 0

Name or ID: North Property Flare
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? Y
Type of flare: Steam assisted
Other Flare type:

Flare service type: General facility flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(ii)(A) - Equation Y-1a Gas Composition Monitored
NameValueOwn Result?
CO2Emissions2247.5 (Metric Tons)N

NameValueOwn Result?
CH4Emissions6.78 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.022 (Metric Tons)N

Y1a Equation Details

Were flare gas data used as inputs to Equation Y-1a collected on a mass or volumetric basis: Volumetric basis
Frequency of measurement data: Daily
Annual volume of flare gas combusted: 41680332.58 scf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: The flare flowmeter manufacturer recommends biennial calibration of the meter and suggests a diagnostic check of the system annually to verify if it is working correctly. WRR ensures these are performed as per manufacturer recommendations. Quarterly visual inspections are also performed to inspect all components for integrity, all electrical connections for continuity, oxidation, and galvanic corrosion, and all mechanical connections for leakage and meter installation is per design (tracing/insulation is place as required, no steam leaks on the meter, etc.).
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Annual average molecular weight: 17.04741139 kg/kg-mole
Method(s) used to determine the molecular weight of the flare gas:
Other (specify)
Specify other method: Mass spectrometry
Number of days missing data procedures were used for annual average molecular weight of the flare gas: 0
Annual average carbon content of the flare gas: 0.736443608 decimal fraction; kg carbon/kg flare gas
Method(s) used to determine the carbon content of the flare gas:
Other (specify)
Other annual average concentration: Mass spectrometry
Number of days missing data procedures were used for average carbon content of the flare gas: 0

Name or ID: Arom South Flare
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? Y
Type of flare: Steam assisted
Other Flare type:

Flare service type: General facility flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Engineering calculations
Other Basis for the fraction of carbon in the flare gas contributed by methane value:

Emissions Details
CO2 Emissions Calculation Method: 98.253(b)(1)(ii)(A) - Equation Y-1a Gas Composition Monitored
NameValueOwn Result?
CO2Emissions3008.7 (Metric Tons)N

NameValueOwn Result?
CH4Emissions9.08 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.030 (Metric Tons)N

Y1a Equation Details

Were flare gas data used as inputs to Equation Y-1a collected on a mass or volumetric basis: Volumetric basis
Frequency of measurement data: Daily
Annual volume of flare gas combusted: 56014280.37 scf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: The flare flowmeter manufacturer recommends biennial calibration of the meter and suggests a diagnostic check of the system annually to verify if it is working correctly. WRR ensures these are performed as per manufacturer recommendations. Quarterly visual inspections are also performed to inspect all components for integrity, all electrical connections for continuity, oxidation, and galvanic corrosion, and all mechanical connections for leakage and meter installation is per design (tracing/insulation is place as required, no steam leaks on the meter, etc.).
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Annual average molecular weight: 16.95025037 kg/kg-mole
Method(s) used to determine the molecular weight of the flare gas:
Other (specify)
Specify other method: Mass spectrometry
Number of days missing data procedures were used for annual average molecular weight of the flare gas: 0
Annual average carbon content of the flare gas: 0.737774105 decimal fraction; kg carbon/kg flare gas
Method(s) used to determine the carbon content of the flare gas:
Other (specify)
Other annual average concentration: Mass spectrometry
Number of days missing data procedures were used for average carbon content of the flare gas: 0

Catalytic Cracking and Reforming Units

Catalytic Reformer No. 3 (Description: Type: Catalytic Reforming Unit)

NameValueOwn Result?
CO2Emissions421.8 (Metric Tons)
Method used to calculate CO2 emissions:Equation Y-11 - 98.253(e)(3)
NameValueOwn Result?
CH4Emissions0.01 (Metric Tons)
Method used to calculate CH4 emissions:Equation Y-9 with a default emission factor
NameValueOwn Result?
N2OEmissions0.002 (Metric Tons)
Method used to calculate N2O emissions:Equation Y-10 with a default emission factor
Total number of regeneration cycles or measurement periods:
Average coke burn-off quantity per cycle or measurement period: (kg coke/cycle or kg coke/measurement period)

Catalytic Cracking Unit No. 1 (Description: Type: Fluid Catalytic Cracking Unit)

NameValueOwn Result?
CO2Emissions341775.1 (Metric Tons)
Method used to calculate CO2 emissions:Equation Y-6 and Y-7a - 98.253(c)(2)
NameValueOwn Result?
CH4Emissions10.01 (Metric Tons)
Method used to calculate CH4 emissions:Equation Y-9 with a default emission factor
NameValueOwn Result?
N2OEmissions2.002 (Metric Tons)
Method used to calculate N2O emissions:Equation Y-10 with a default emission factor
NameValueSubstitute IndicatorTimes Substituted
AnnualAverageExhaustGasFlowRate ()
Manufacturer's method for annual average volumetric flow rate of exhaust gas:
NameValueSubstitute IndicatorTimes Substituted
PercentCO2 ()120
Manufacturer's method for annual average percent CO2 in exhaust gas stream:Continuous measurement with an infrared analyzer. Analyzer data is sent to the plant historian and compiled into an annual average.
NameValueSubstitute IndicatorTimes Substituted
PercentCO ()120
Manufacturer's method for annual average percent CO in exhaust gas stream:Continuous measurement with an infrared analyzer. Analyzer data is sent to the plant historian and compiled into an annual average.
NameValueSubstitute IndicatorTimes Substituted
PercentO2ExhaustGas ()120
Manufacturer's method for annual average percent O2 in exhaust gas stream:Continuous measurement with a paramagnetic analyzer. Analyzer data is sent to the plant historian and compiled into an annual average.
NameValueSubstitute IndicatorTimes Substituted
PercentO2Inlet ()

Catalytic Cracking Unit No. 2 (Description: Type: Fluid Catalytic Cracking Unit)

NameValueOwn Result?
CO2Emissions373766.4 (Metric Tons)
Method used to calculate CO2 emissions:Equation Y-6 and Y-7a - 98.253(c)(2)
NameValueOwn Result?
CH4Emissions10.95 (Metric Tons)
Method used to calculate CH4 emissions:Equation Y-9 with a default emission factor
NameValueOwn Result?
N2OEmissions2.190 (Metric Tons)
Method used to calculate N2O emissions:Equation Y-10 with a default emission factor
NameValueSubstitute IndicatorTimes Substituted
AnnualAverageExhaustGasFlowRate ()
Manufacturer's method for annual average volumetric flow rate of exhaust gas:
NameValueSubstitute IndicatorTimes Substituted
PercentCO2 ()105
Manufacturer's method for annual average percent CO2 in exhaust gas stream:Continuous measurement with an infrared analyzer. Analyzer data is sent to the plant historian and compiled into an annual average.
NameValueSubstitute IndicatorTimes Substituted
PercentCO ()46
Manufacturer's method for annual average percent CO in exhaust gas stream:Continuous measurement with an infrared analyzer. Analyzer data is sent to the plant historian and compiled into an annual average.
NameValueSubstitute IndicatorTimes Substituted
PercentO2ExhaustGas ()105
Manufacturer's method for annual average percent O2 in exhaust gas stream:Continuous measurement with a paramagnetic analyzer. Analyzer data is sent to the plant historian and compiled into an annual average.
NameValueSubstitute IndicatorTimes Substituted
PercentO2Inlet ()

Catalytic Reformer No. 1 (Description: Type: Catalytic Reforming Unit)

NameValueOwn Result?
CO2Emissions687.1 (Metric Tons)
Method used to calculate CO2 emissions:Equation Y-11 - 98.253(e)(3)
NameValueOwn Result?
CH4Emissions0.02 (Metric Tons)
Method used to calculate CH4 emissions:Equation Y-9 with a default emission factor
NameValueOwn Result?
N2OEmissions0.004 (Metric Tons)
Method used to calculate N2O emissions:Equation Y-10 with a default emission factor
Total number of regeneration cycles or measurement periods:
Average coke burn-off quantity per cycle or measurement period: (kg coke/cycle or kg coke/measurement period)


Sulfur Recovery Details

Sour Gas Details

is Sour Gas Stream Sent Off Site Indicator :N
Annual Volumetric Flow Method :
Average Mole Fraction of Carbon in Sour Gas Method :

Sulfur Recovery Unit Details

Unit Name :Sulfur Recovery Unit (N. & S. Oxidizers)
Unit Type :Sulfur Recovery Plant
Unit Description :

Sulfur Recovery Plant Description :Claus
Other Sulfur Recovery Plant Description :

NameValueOwn Result?
CalculatedCO2Emissions31339.7 (Metric Tons)

CO2 Emission Method :Equation Y-12

Process Vent Method Details
Cumulative Annual Volume Flow Discharged Method :
Other Annual Volume Metric Flow Method List :
Cumulative Venting Time :

is Recycled Tailgas Included Indicator :N
Annual Volumetric Flow Method :
Annual Average Mole Fraction of Carbon Method in the Sour Gas Method :
Number of hours missing data procedures were used for annual average mole fraction of carbon method in the sour gas :

Recycle Tail Gas Details

Tail Gas Recycled Flow Rate Carbon Content Included :N
Tail Gas Correction for CO2 Used :N

Recycled Tail Gas Method Details
Recycled Tail Gas Method :
Other Recycled Tail Gas Method :

Annual Average Mole Fraction of Carbon Method :
Other Annual Average Mole Fraction of Carbon Method :
Basis for Correction :
Value of Correction : ()
Approach Used for Correction :
Other Approach Used for Correction :
Sulfur Recovery Unit Details

Unit Name :Sulfur Recovery Unit (E Incinerator)
Unit Type :Sulfur Recovery Plant
Unit Description :

Sulfur Recovery Plant Description :Claus
Other Sulfur Recovery Plant Description :

NameValueOwn Result?
CalculatedCO2Emissions25762.4 (Metric Tons)

CO2 Emission Method :Equation Y-12

Process Vent Method Details
Cumulative Annual Volume Flow Discharged Method :
Other Annual Volume Metric Flow Method List :
Cumulative Venting Time :

is Recycled Tailgas Included Indicator :N
Annual Volumetric Flow Method :
Annual Average Mole Fraction of Carbon Method in the Sour Gas Method :
Number of hours missing data procedures were used for annual average mole fraction of carbon method in the sour gas :

Recycle Tail Gas Details

Tail Gas Recycled Flow Rate Carbon Content Included :N
Tail Gas Correction for CO2 Used :N

Recycled Tail Gas Method Details
Recycled Tail Gas Method :
Other Recycled Tail Gas Method :

Annual Average Mole Fraction of Carbon Method :
Other Annual Average Mole Fraction of Carbon Method :
Basis for Correction :
Value of Correction : ()
Approach Used for Correction :
Other Approach Used for Correction :
Sulfur Recovery Unit Details

Unit Name :Sulfur Recovery Unit (F Incinerator)
Unit Type :Sulfur Recovery Plant
Unit Description :

Sulfur Recovery Plant Description :Claus
Other Sulfur Recovery Plant Description :

NameValueOwn Result?
CalculatedCO2Emissions27903.5 (Metric Tons)

CO2 Emission Method :Equation Y-12

Process Vent Method Details
Cumulative Annual Volume Flow Discharged Method :
Other Annual Volume Metric Flow Method List :
Cumulative Venting Time :

is Recycled Tailgas Included Indicator :N
Annual Volumetric Flow Method :
Annual Average Mole Fraction of Carbon Method in the Sour Gas Method :
Number of hours missing data procedures were used for annual average mole fraction of carbon method in the sour gas :

Recycle Tail Gas Details

Tail Gas Recycled Flow Rate Carbon Content Included :N
Tail Gas Correction for CO2 Used :N

Recycled Tail Gas Method Details
Recycled Tail Gas Method :
Other Recycled Tail Gas Method :

Annual Average Mole Fraction of Carbon Method :
Other Annual Average Mole Fraction of Carbon Method :
Basis for Correction :
Value of Correction : ()
Approach Used for Correction :
Other Approach Used for Correction :


Delayed Coking Details


Unit Name: DCU-1
Unit Type: Delayed Coking Unit
Unit Description:

Total number of associated delayed coking vessels (or coke drums): 3
Basis for the typical dry mass of coke at the end of the coking cycle: calculated using Equation Y-18a
Method used to estimate the average temperature of the coke bed, Tinit: pressure correlation and Equation Y-18d
Type of emission factor was used in Equation Y-18f: default factor

NameValueOwn Result?
CH4Emissions0.00 (Metric Tons)N

Unit Name: DCU-2
Unit Type: Delayed Coking Unit
Unit Description:

Total number of associated delayed coking vessels (or coke drums): 4
Basis for the typical dry mass of coke at the end of the coking cycle: calculated using Equation Y-18a
Method used to estimate the average temperature of the coke bed, Tinit: pressure correlation and Equation Y-18d
Type of emission factor was used in Equation Y-18f: default factor

NameValueOwn Result?
CH4Emissions99.60 (Metric Tons)N

Uncontrolled Blowdown Systems

Methane emissions: ()
Methane emissions calculation method:No uncontrolled blowdown systems

Equipment Leak Details

NameValueOwn Result?
TotalCH4Emissions35.2 (Metric Tons)

Method to Calculate Equipment Leak Emission:98.253(l)(2) method

Storage Tank Details


NameValueOwn Result?
StabilizedCrudeTotalCH4Emissions11.44 (Metric Tons)

Stored Liquids Other Than Unstabilized Crude Oil Calculation Method:Equation Y-22
is Stored Liquids Other Than Unstabilized Crude Oil Received Stored Indicator:
UnStabilized Crude Calculation Method:
is UnStablized Crude Received Stored Indicator:
UnStabilized Crude Basis for Mole Fraction:
Other UnStabilized Crude Basis for Mole Fraction:

Subpart MM: Suppliers of Petroleum Products

Gas Information Details

Gas NameCarbon Dioxide
Gas Quantity47,087,463 (Metric Tons)
Own Result?


SubpartMMFacilityDataDetails:
Type of Facility:Refinery


AggregateProductsDetails:
Are you reporting optional procedures for blended products that do not contain biomass per the requirements of 98.393(i)?


AggregateProductsRowDetails:
Unique ID1
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID2
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID3
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID4
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID5
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID6
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID7
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID8
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID9
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID10
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID11
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID12
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID13
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID14
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID15
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID16
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID17
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID18
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID19
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID20
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID21
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID22
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID23
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID24
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID25
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID26
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID27
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID28
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID29
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)
Unique ID30
Is the product entering the facility or leaving the facility? 98.396(b); 98.396(c)
Product Name Code 98.396(a)(1); 98.396(a)(5); 98.396(b)(1); 98.396(c)(1)
Measured Quantity Units 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Product Annual Quantity 98.396(a)(2); 98.396(a)(6); 98.396(a)(14); 98.396(b)(2); 98.396(c)(2)
Percent Petroleum Based 98.396(a)(3); 98.396(a)(7); 98.396(b)(3); 98.396(c)(3) percent
Annual CO2 Quantity, MT 98.396(a)(16); 98.396(a)(17); 98.396(a)(18); 98.396(b)(7); 98.396(c)(7)
Is Calculation Method 2 Used for this Product?No
Number of Samples 98.396(a)(9)(i); 98.396(a)(11)(i); 98.396(b)(5)(i); 98.396(c)(5)(i)
Sampling Standard Method Used 98.396(a)(9)(ii); 98.396(a)(11)(ii); 98.396(b)(5)(ii); 98.396(c)(5)(ii)
Carbon Share (mass %) 98.396(a)(9)(iii); 98.396(a)(11)(iii); 98.396(b)(5)(iii); 98.396(c)(5)(iii)
Standard Method Used to Test Carbon Share 98.396(a)(9)(iv); 98.396(a)(11)(iv); 98.396(b)(5)(iv); 98.396(c)(5)(iv)
Calculated CO2 Quantity Emission Factor 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Calculated CO2 Quantity Emission Factor Units 98.396(a)(9)(v); 98.396(a)(11)(v); 98.396(b)(5)(v); 98.396(c)(5)(v)
Density Test Results (metric tons/ barrel) 98.396(a)(10)(i); 98.396(a)(12)(i); 98.396(b)(6)(i); 98.396(c)(6)(i)
Standard Method Used to Test Density 98.396(a)(10)(ii); 98.396(a)(12)(ii); 98.396(b)(6)(ii); 98.396(c)(6)(ii)


TotalCarbonDioxideQuantityDetails:


TotalCarbonDioxideQuantityRowDetails:
Reporter Type 98.396(b); 98.396(c)Refinery
Sum of CO2 Quantity for All Products 98.396(a)(19); 98.396(b)(8); 98.396(c)(8)47087463
Quantity of Crude Oil Entering the Refinery (barrels) 98.396(a)(20)
Quantity of Bulk Natural Gas Liquids Received for Processing 98.396(a)(21)
Quantity of Bulk Natural Gas Liquids Units of Measure 98.396(a)(21)
Crude Oil Injected Into Supply/Reservoir, barrels 98.396(a)(22)


Subpart PP: Suppliers of Carbon Dioxide

Gas Information Details

Gas NameCarbon Dioxide
Gas Quantity
Own Result?

Supplier Type: capture 98.420(a)(1)
Calculation Methodology: Streams

Meter Details:

Meter Name: SMR CO2 Product
Meter Description:
Meter Type: CO2 Stream
Measurement Type: Mass
Annual Mass of CO2 (Metric Tons):
Biomass-Based Percent: 0

Quarterly Mass Flow Data
QuarterMass Flow RateCO2 ConcentrationMeasurement Standard
First Quarter (Metric Tons) (wt. %CO2 expressed as a fraction) Metering systems which meet or exceed the appropriate API and/or MPMS standards for installation and performance.
Second Quarter (Metric Tons) (wt. %CO2 expressed as a fraction) Metering systems which meet or exceed the appropriate API and/or MPMS standards for installation and performance.
Third Quarter (Metric Tons) (wt. %CO2 expressed as a fraction) Metering systems which meet or exceed the appropriate API and/or MPMS standards for installation and performance.
Fourth Quarter (Metric Tons) (wt. %CO2 expressed as a fraction) Metering systems which meet or exceed the appropriate API and/or MPMS standards for installation and performance.


End Use Details
End Use CategoryQuantity of CO2
Food and beverage (Metric Tons)
Industrial and municipal water/wastewater treatment (Metric Tons)
Metal fabrication, including welding and cutting (Metric Tons)
Greenhouse uses for plant growth (Metric Tons)
Fumigants (e.g., grain storage) and herbicides (Metric Tons)
Pulp and paper (Metric Tons)
Cleaning and solvent use (Metric Tons)
Fire fighting (Metric Tons)
Transportation and storage of explosives (Metric Tons)
Injection of CO2 for enhanced oil and natural gas recovery that is covered by 40 CFR Part 98, Subpart UU (Metric Tons)
Geologic sequestration of carbon dioxide that is covered by 40 CFR Part 98, Subpart RR (Metric Tons)
Research and Development (Metric Tons)
Other (if other please provide a short description of the use) (Metric Tons)
Unknown (Metric Tons)

Number of days substitute data procedures were used for mass or volume: 0
Number of days substitute data procedures were used for concentration: 0
Number of days substitute data procedures were used for density: 0

Types of Equipment Used
Equipment TypeStandard Used to Calibrate Equipment
ScaleMetering systems which meet or exceed the appropriate API and/or MPMS standards for installation and performance.


Subpart TT: Industrial Waste Landfills

Gas Information Details

Gas NameCarbon Dioxide
Gas Quantity0 (Metric Tons)
Own Result?

Gas NameBiogenic Carbon dioxide
Gas Quantity0 (Metric Tons)
Own Result?

Gas NameMethane
Gas Quantity188.72 (Metric Tons)
Own Result?

Gas NameNitrous Oxide
Gas Quantity0 (Metric Tons)
Own Result?

Landfill Details:
Was the landfill open or closed Closed
First year the landfill accepted waste1960
If the landfill is closed, the last year that the landfill received waste1990
Landfill Capacity713088 (Metric Tons)
Does the landfill have a landfill gas collection systemN
Passive vents and/or flares are present (vents or flares that are not considered part of the gas collection system)N
An indication of whether leachate recirculation was used during the reporting yearN
The typical frequency of use of leachate recirculation over the past ten (10) yearsNot used for the past ten (10) years
Each type of cover material used and Landfill surface area containing waste
Organic cover54633 (Square Meters)
Number of waste streams2
Annual modeled methane generation TT1209.69 (Metric Tons)
Annual modeled methane generation TT1 user overrided valueN

Equation TT-1 Details:
The fraction of CH4 in landfill gas (F), is it based on a measured value or default valueDefault
Fraction by volume of CH4 in landfill gas ()
An MCF value other than the default of 1 was usedN

Waste Stream For Method3 Details:
Capacity of the landfill used (or the total quantity of waste-in-place) at the end of the "YrData" from design drawings or engineering estimates713088 (Metric Tons)
Are waste quantity data available?waste quantity data are not available for any years
The year in which the landfill last received waste(YrData)1990
Do you know the year when the landfill opened?Yes
The year the landfill first received waste from company records, or 1960 (whichever is more recent)1960

Methane Generation and Emissions for Landfills without LFG Collection Systems

Methane Oxidation Fraction
Methane Oxidation Fraction TT-6 0.10


Gas Collection Systems details
Methane Generation Equation TT6188.72 (Metric Tons)

Waste Stream Summary:

Stream Identification and Method(s) used to determine historical waste stream quantity for SWMUs C, E, F, and G

Stream NameSWMUs C, E, F, and G
Stream DescriptionReject asphalt, fly ash, spent catalysts, slop oil emulsion, API sludges, leaded tank bottoms, tower sludges, acid and caustic wastes
Type(s) Of Waste Present In The Waste Stream
other industrial solid waste
Range of years for which both disposal and production data were used in Equation TT-2 to calculate the average waste disposal factor for the landfill
First year this waste stream was placed in the landfill1960
Last year this waste stream was placed in the landfill1990
Method(s) used to determine historical waste stream quantity
Reporting YearMethod #1Method #2Method #3Method #4DecayrateWaste disposed quantity (UOM)Waste stream DOC value (UOM)Is defaulted value from table TT1Is value measured using 60 day anaerobic biodegradation testIs based on total volatile solids measurements
1960NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1961NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1962NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1963NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1964NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1965NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1966NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1967NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1968NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1969NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1970NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1971NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1972NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1973NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1974NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1975NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1976NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1977NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1978NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1979NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1980NNYN0.0425885.37 (Metric Tons)0.2 (Metric Tons)YNN
1981NNYN0.042797.39 (Metric Tons)0.2 (Metric Tons)YNN
1982NNYN0.042797.39 (Metric Tons)0.2 (Metric Tons)YNN
1983NNYN0.042797.39 (Metric Tons)0.2 (Metric Tons)YNN
1984NNYN0.042797.39 (Metric Tons)0.2 (Metric Tons)YNN
1985NNYN0.042797.39 (Metric Tons)0.2 (Metric Tons)YNN
1986NNYN0.042797.39 (Metric Tons)0.2 (Metric Tons)YNN
1987NNYN0.042797.39 (Metric Tons)0.2 (Metric Tons)YNN
1988NNYN0.042797.39 (Metric Tons)0.2 (Metric Tons)YNN
1989NNYN0.042797.39 (Metric Tons)0.2 (Metric Tons)YNN
1990NNYN0.042797.39 (Metric Tons)0.2 (Metric Tons)YNN

Stream Identification and Method(s) used to determine historical waste stream quantity for SWMU A

Stream NameSWMU A
Stream Descriptionsoil, rock, lime, sulfur, sand, concrete, refractory, soda ash, spent catalysts
Type(s) Of Waste Present In The Waste Stream
other industrial solid waste
Range of years for which both disposal and production data were used in Equation TT-2 to calculate the average waste disposal factor for the landfill
First year this waste stream was placed in the landfill1978
Last year this waste stream was placed in the landfill1990
Method(s) used to determine historical waste stream quantity
Reporting YearMethod #1Method #2Method #3Method #4DecayrateWaste disposed quantity (UOM)Waste stream DOC value (UOM)Is defaulted value from table TT1Is value measured using 60 day anaerobic biodegradation testIs based on total volatile solids measurements
1978NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1979NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1980NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1981NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1982NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1983NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1984NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1985NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1986NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1987NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1988NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1989NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
1990NNYN0.0410886.21688 (Metric Tons)0.024 (Metric Tons)NNY
  • Method #1: Used one of the waste quantity measurement methods specified in 98.463(a)(2)(i): direct mass measurements, direct volume measurements multiplied by waste stream density, mass balance procedures (difference between the mass of process inputs and the mass of process outputs), or the number of loads multiplied by the mass of waste per load based on the working capacity of the vehicle or container.
  • Method #2: Calculated the average waste disposal rate per Equation TT-2 and calculated the waste disposal quantities for historic years in which direct waste disposal measurements are not available using historical production data per Equation TT-3.
  • Method #3: Calculated an average annual bulk waste disposal quantity for historic years when waste quantity data as determined by other methods are available consecutively for the most recent disposal years (Equation TT-4a).
  • Method #4: Calculated an average annual bulk waste disposal quantity for historic years when waste quantity data as determined by other methods are available for sporadic (non-consecutive) years (Equation TT-4b).