Facility Name:Philadelphia Refinery
Facility Identifier:
Facility Reporting Year:2020
Facility Location:
Address: 3144 PASSYUNK AVENUE
City: PHILADELPHIA
State: PA
Postal Code: 19145

Facility Site Details:
CO2 equivalent emissions from facility subparts C-II, SS, and TT (metric tons):127,289
CO2 equivalent emissions from supplier subparts LL-QQ (metric tons):
Biogenic CO2 emissions from facility subparts C-II, SS, and TT (metric tons):0
Cogeneration Unit Emissions Indicator:N
GHG Report Start Date:2020-01-01
GHG Report End Date:2020-12-31
Description of Changes to Calculation Methodology:
Did you use an EPA-approved BAMM in this reporting year for Subpart C?
Did you use an EPA-approved BAMM in this reporting year for Subpart Y?
Plant Code Indicator:Y
Primary NAICS Code:324110
Second Primary NAICS Code:

Parent Company Details:
Parent Company Name:PHILADELPHIA ENERGY SOLUTIONS LLC
Address:3144 Passyunk Avenue, PHILADELPHIA,  PA 19145
Percent Ownership Interest:100

Subpart C: General Stationary Fuel Combustion

Gas Information Details

Gas NameCarbon Dioxide
Gas Quantity123,274.2 (Metric Tons)
Own Result?

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

Gas NameMethane
Gas Quantity2.39 (Metric Tons)
Own Result?

Gas NameNitrous Oxide
Gas Quantity0.239 (Metric Tons)
Own Result?

Unit Details:
Unit Name : 45 Boiler
Unit Type : OB (Boiler, other)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 350 (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 : 2020-01-01
Tier Methodology End Date : 2020-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
29570.9 (Metric Tons) 0.58 (Metric Tons) 0.058 (Metric Tons) 14.5 (Metric Tons) 17.3 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 365
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 : 365
Total number of molecular weight substitute data values : 0
Frequency of molecular weight determinations : Daily
Molar Volume Constant (MVC) used : 849.5 (scf/kg-mole)

Unit Name : 3 Boiler House #37 Boiler
Unit Type : OB (Boiler, other)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 495 (mmBtu/hr)
Plant Code : 52106 (numeric, maximum of 6 digits)

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 : 2020-01-01
Tier Methodology End Date : 2020-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
35.8 (Metric Tons) 0.00 (Metric Tons) 0.000 (Metric Tons) 0 (Metric Tons) 0 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 365
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 : 365
Total number of molecular weight substitute data values : 0
Frequency of molecular weight determinations : Daily
Molar Volume Constant (MVC) used : 849.5 (scf/kg-mole)

Unit Name : 3 Boiler House #39 Boiler
Unit Type : OB (Boiler, other)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 495 (mmBtu/hr)
Plant Code : 52106 (numeric, maximum of 6 digits)

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 : 2020-01-01
Tier Methodology End Date : 2020-12-31

Fuel Emission Details :
Total CO2 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
93204.8 (Metric Tons) 1.80 (Metric Tons) 0.180 (Metric Tons) 45.1 (Metric Tons) 53.7 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 365
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 : 365
Total number of molecular weight substitute data values : 0
Frequency of molecular weight determinations : Daily
Molar Volume Constant (MVC) used : 849.5 (scf/kg-mole)

Unit Name : Marine Vapor Recovery Unit
Unit Type : TODF (Thermal oxidizer, direct fired, no heat recovery)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 46.4 (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 2 (Equation C-2a)
Tier Methodology Start Date : 2020-01-01
Tier Methodology End Date : 2020-12-31
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
462.7 (Metric Tons) 0.01 (Metric Tons) 0.001 (Metric Tons) 0.2 (Metric Tons) 0.3 (Metric Tons)



Non-Operating Unit Details:
Unit Name : 867 In-Line Heater
Configuration Type :
Unit Type : OB (Boiler, other)
Unit Description : 6H-402

Unit Name : 210 H-101 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 210 H-201 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 860 2H-3 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 860 2H-5 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 860 2H-7 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 860 2H-8 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 864 PH-1 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 864 PH-7 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 864 PH-11 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 864 PH-12 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 865 11H-1 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 865 11H-2 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 866 12H-1 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 868 8H-101
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : CP-870 H-01/H-02
Configuration Type :
Unit Type : OCS (Other combustion source)
Unit Description : 870 heaters

Unit Name : 859 1H-1 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 867 South Claus Burner
Configuration Type :
Unit Type : TODF (Thermal oxidizer, direct fired, no heat recovery)

Unit Name : 3 Boiler House #40 Boiler
Configuration Type :
Unit Type : OB (Boiler, other)

Unit Name : 1332 H-2 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 231 B-101 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 433 H-1 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 867 North Claus Burner
Configuration Type :
Unit Type : TODF (Thermal oxidizer, direct fired, no heat recovery)

Unit Name : 867 TGU2 Incineration
Configuration Type :
Unit Type : ICI (Incinerator, commercial and industrial)

Unit Name : 1332 H-3 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 867 TGU1 Incinerator
Configuration Type :
Unit Type : ICI (Incinerator, commercial and industrial)

Unit Name : 1232 B-104 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 1232 CO Boiler
Configuration Type :
Unit Type : OCS (Other combustion source)

Unit Name : 1332 H-1 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 137 F-2 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 1332 H-400 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 1332 H-401 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 1332 H-601 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 1332 H-602 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 210 13H-1 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 860 2H-2 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 860 2H-4 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 137 F-1 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Unit Name : 137 F-3 Heater
Configuration Type :
Unit Type : PRH (Process Heater)

Subpart Y: Petroleum Refineries

Gas Information Details

Gas NameCarbon Dioxide
Gas Quantity3,323.2 (Metric Tons)
Own Result?

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

Gas NameMethane
Gas Quantity22.03 (Metric Tons)
Own Result?

Gas NameNitrous Oxide
Gas Quantity0.033 (Metric Tons)
Own Result?

Flare Gas Details

Name or ID: 1231 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: 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)(B) - Equation Y-2 Heat Content Monitored
NameValueOwn Result?
CO2Emissions585.1 (Metric Tons)N

NameValueOwn Result?
CH4Emissions1.77 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.006 (Metric Tons)N

Y2 Equation Details

Frequency of measurement data: Daily
Annual volume of flare gas combusted: 28.7 MMscf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: Ultrasonic Flow Meters
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Conditions on which the annual volume of flare gas was determined: 60 degrees F and 14.7 psia
Annual average higher heating value of the flare gas combusted: 343 MMBtu/MMscf
Method used to determine the annual average higher heating value: Other (specify)
Number of days missing data procedures were used for annual average higher heating value: 41
Conditions on which the annual average higher heating value was determined: 60 degrees F and 14.7 psia

Name or ID: North Yard LPG 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: Unit flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Default Value
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 (Metric Tons)N

NameValueOwn Result?
CH4Emissions0 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0 (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: 860 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: Unit flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Default Value
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)(B) - Equation Y-2 Heat Content Monitored
NameValueOwn Result?
CO2Emissions0 (Metric Tons)N

NameValueOwn Result?
CH4Emissions0 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0 (Metric Tons)N

Y2 Equation Details

Frequency of measurement data: Daily
Annual volume of flare gas combusted: 0 MMscf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: Ultrasonic Flow Meter
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Conditions on which the annual volume of flare gas was determined: 60 degrees F and 14.7 psia
Annual average higher heating value of the flare gas combusted: 0 MMBtu/MMscf
Method used to determine the annual average higher heating value: Other (specify)
Number of days missing data procedures were used for annual average higher heating value: 0
Conditions on which the annual average higher heating value was determined: 60 degrees F and 14.7 psia

Name or ID: 860 North 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: Unit flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Default Value
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)(B) - Equation Y-2 Heat Content Monitored
NameValueOwn Result?
CO2Emissions2738.1 (Metric Tons)N

NameValueOwn Result?
CH4Emissions8.26 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.027 (Metric Tons)N

Y2 Equation Details

Frequency of measurement data: Daily
Annual volume of flare gas combusted: 51.4 MMscf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: Ultrasonic Flow Meter
Number of days missing data procedures were used for annual volume of flare gas combusted: 58
Conditions on which the annual volume of flare gas was determined: 60 degrees F and 14.7 psia
Annual average higher heating value of the flare gas combusted: 902 MMBtu/MMscf
Method used to determine the annual average higher heating value: Other (specify)
Number of days missing data procedures were used for annual average higher heating value: 0
Conditions on which the annual average higher heating value was determined: 60 degrees F and 14.7 psia

Name or ID: 433 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: Unit flare
Other Flare service type:

Basis for the fraction of carbon in the flare gas contributed by methane value: Default Value
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)(B) - Equation Y-2 Heat Content Monitored
NameValueOwn Result?
CO2Emissions0 (Metric Tons)N

NameValueOwn Result?
CH4Emissions0 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0 (Metric Tons)N

Y2 Equation Details

Frequency of measurement data: Daily
Annual volume of flare gas combusted: 0.00 MMscf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: Ultrasonic Flow Meter
Number of days missing data procedures were used for annual volume of flare gas combusted: 0
Conditions on which the annual volume of flare gas was determined: 60 degrees F and 14.7 psia
Annual average higher heating value of the flare gas combusted: 0 MMBtu/MMscf
Method used to determine the annual average higher heating value: Other (specify)
Number of days missing data procedures were used for annual average higher heating value: 0
Conditions on which the annual average higher heating value was determined: 60 degrees F and 14.7 psia

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 :


Uncontrolled Blowdown Systems

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

Equipment Leak Details

NameValueOwn Result?
TotalCH4Emissions12 (Metric Tons)

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

Storage Tank Details

Stored Liquids Other Than Unstabilized Crude Oil Calculation Method:
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 Quantity690,290.3 (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)


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)690290.31
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)