GHG Summary Report

CO2 equivalent emissions from facility subparts C-II, SS, and TT (metric tons):940,006.3
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 P?
Did you use an EPA-approved BAMM in this reporting year for Subpart Y?
Plant Code Indicator:N
Primary NAICS Code:324110
Second Primary NAICS Code:

Parent Company Details:

Parent Company Name:PHILLIPS 66
Address:3010 Briar Park Drive, Houston, TX 77042
Percent Ownership Interest:100

Subpart C: General Stationary Fuel Combustion

Gas Information Details

Gas Name	Carbon Dioxide
Gas Quantity	399,166.1 (Metric Tons)
Own Result?

Gas Name	Biogenic Carbon dioxide
Gas Quantity	0 (Metric Tons)
Own Result?

Gas Name	Methane
Gas Quantity	21.41 (Metric Tons)
Own Result?

Gas Name	Nitrous Oxide
Gas Quantity	4.28 (Metric Tons)
Own Result?

Unit Details:

Unit Name : GP-AG-2
Unit Type : OCS (Other combustion source)
Unit Description :
Other Unit Name :

Small Unit Aggregation Details:
Use Ivt Indicator: Y
Highest Maximum Rated Heat Input Capacity: 1.8
Cumulative Maximum Rated Heat Input Capacity:

Emission Details:
Annual CO₂ mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)
Annual Fossil fuel based CO2 Emissions: 1922.6 (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 emissions	Total CH4 emissions	Total N2O emissions	Total CH4 emissions CO2e	Total N2O emissions CO2e
1922.6 (Metric Tons)	0.03 (Metric Tons)	0.003 (Metric Tons)	0.8 (Metric Tons)	0.9 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 11
Total number of carbon content substitute data values : 1
Frequency of carbon content determinations : Monthly
Total number of operating hours in the reporting year for which missing data substitution was used for fuel usage : 696

Molecular Weight Information :
Total number of valid molecular weight determinations : 11
Total number of molecular weight substitute data values : 1
Frequency of molecular weight determinations : Monthly
Molar Volume Constant (MVC) used : 836.6 (scf/kg-mole)

Unit Name : CP-1
Unit Type : OCS (Other combustion source)
Unit Description :
Other Unit Name :

Common Pipe Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 183
Cumulative Maximum Rated Heat Input Capacity: 1211

Emission Details:
Annual Biogenic CO2 Emissions: 0 (metric tons)
Annual Fossil fuel based CO2 Emissions: 396986.1 (metric tons)

Tier Fuel Details:

Fuel : Fuel Gas
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 emissions	Total CH4 emissions	Total N2O emissions	Total CH4 emissions CO2e	Total N2O emissions CO2e
396989.1 (Metric Tons)	21.38 (Metric Tons)	4.276 (Metric Tons)	534.5 (Metric Tons)	1274.3 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 131
Total number of carbon content substitute data values : 0
Frequency of carbon content determinations : Weekly
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 : 131
Total number of molecular weight substitute data values : 0
Frequency of molecular weight determinations : Weekly
Molar Volume Constant (MVC) used : 836.6 (scf/kg-mole)

Unit Name : GP-AG-5
Unit Type : OCS (Other combustion source)
Unit Description :
Other Unit Name :

Small Unit Aggregation Details:
Use Ivt Indicator: Y
Highest Maximum Rated Heat Input Capacity: 90
Cumulative Maximum Rated Heat Input Capacity: 208

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

Tier Fuel Details:

Total CO2 emissions	Total CH4 emissions	Total N2O emissions	Total CH4 emissions CO2e	Total N2O emissions CO2e
()	0 (Metric Tons)	0 (Metric Tons)	0 (Metric Tons)	0 (Metric Tons)

Unit Name : Knock Engines - Pump House
Unit Type : OCS (Other combustion source)
Unit Description :
Other Unit Name : Knock Engine

Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 0.125 (mmBtu/hr)

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

Tier Fuel Details:

Fuel : Motor Gasoline
Tier Name : Tier 1 (Equation C-1)
Tier Methodology Start Date : 2020-01-01
Tier Methodology End Date : 2020-12-31

Fuel Emission Details :

Total CO2 emissions	Total CH4 emissions	Total N2O emissions	Total CH4 emissions CO2e	Total N2O emissions CO2e
94.8 (Metric Tons)	0.00 (Metric Tons)	0.001 (Metric Tons)	0.1 (Metric Tons)	0.2 (Metric Tons)

Unit Name : GP-AG-4
Unit Type : OCS (Other combustion source)
Unit Description :
Other Unit Name :

Small Unit Aggregation Details:
Use Ivt Indicator: Y
Highest Maximum Rated Heat Input Capacity: 0.6
Cumulative Maximum Rated Heat Input Capacity:

Emission Details:
Annual CO₂ mass emissions from sorbent: 0 (Metric Tons)
Annual Biogenic CO2 Emissions: 0 (metric tons)
Annual Fossil fuel based CO2 Emissions: 159.6 (metric tons)

Tier Fuel Details:

Fuel : Natural Gas (Weighted U.S. Average)
Tier Name : Tier 1 (Equation C-1a, natural gas billing in therms)
Tier Methodology Start Date : 2020-01-01
Tier Methodology End Date : 2020-12-31

Fuel Emission Details :

Total CO2 emissions	Total CH4 emissions	Total N2O emissions	Total CH4 emissions CO2e	Total N2O emissions CO2e
159.6 (Metric Tons)	0.00 (Metric Tons)	0.000 (Metric Tons)	0.1 (Metric Tons)	0.1 (Metric Tons)

Subpart P: Hydrogen Production

CEMS Monitoring Location (CML) Details

Gas Information Details

Gas Name	Carbon Dioxide
Gas Quantity	325,094.6 (Metric Tons)
Own Result?

Gas Name	Biogenic Carbon dioxide
Gas Quantity	0 (Metric Tons)
Own Result?

Gas Name	Methane
Gas Quantity	0 (Metric Tons)
Own Result?

Gas Name	Nitrous Oxide
Gas Quantity	0 (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: Unit 94 - No 1 H2 Plant
Unit Type: Hydrogen production process unit
Unit Description:
CO2Emissions: 194302.0 (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: ()

No Cems Hydrogen Unit Details:
Unit Name: Unit 97 - No. 2 H2 Plant
Unit Type: Hydrogen production process unit
Unit Description:
CO2Emissions: 130792.6 (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: ()

Subpart Y: Petroleum Refineries

Gas Information Details

Gas Name	Carbon Dioxide
Gas Quantity	212,256.5 (Metric Tons)
Own Result?

Gas Name	Biogenic Carbon dioxide
Gas Quantity	0 (Metric Tons)
Own Result?

Gas Name	Methane
Gas Quantity	54.81 (Metric Tons)
Own Result?

Gas Name	Nitrous Oxide
Gas Quantity	1.034 (Metric Tons)
Own Result?

Flare Gas Details

Name or ID: Main Plant 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: Chromatographic analysis: manufacturer's instructions
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

Name	Value	Own Result?
CO2Emissions	2355.5 (Metric Tons)	N

Name	Value	Own Result?
CH4Emissions	7.11 (Metric Tons)	N

Name	Value	Own Result?
N2OEmissions	0.024 (Metric Tons)	N

Y2 Equation Details

Frequency of measurement data: Daily
Annual volume of flare gas combusted: 47.49 MMscf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: F3 (98.253(b)(1)(ii)(B), Equation Y-2)
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: 68 degrees F and 14.7 psia
Annual average higher heating value of the flare gas combusted: 888 MMBtu/MMscf
Method used to determine the annual average higher heating value: Chromatographic analysis: manufacturer's instructions
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: 68 degrees F and 14.7 psia

Catalytic Cracking and Reforming Units

No. 2 Reformer - Catalyst Regeneration (Description: Type: Catalytic Reforming Unit)

Name	Value	Own Result?
CO2Emissions	44.2 (Metric Tons)

Method used to calculate CO2 emissions:Equation Y-11 - 98.253(e)(3)

Name	Value	Own Result?
CH4Emissions	0.00 (Metric Tons)

Method used to calculate CH4 emissions:Equation Y-9 with a default emission factor

Name	Value	Own Result?
N2OEmissions	0.000 (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)

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

Name	Value	Own Result?
CO2Emissions	0.0 (Metric Tons)

Method used to calculate CO2 emissions:Equation Y-11 - 98.253(e)(3)

Name	Value	Own Result?
CH4Emissions	0 (Metric Tons)

Method used to calculate CH4 emissions:Equation Y-9 with a default emission factor

Name	Value	Own Result?
N2OEmissions	0 (Metric Tons)

Unit 34 - FCCU (Description: Type: Fluid Catalytic Cracking Unit)

Name	Value	Own Result?
CO2Emissions	172345.3 (Metric Tons)

Method used to calculate CO2 emissions:Equation Y-6 and Y-7a - 98.253(c)(2)

Name	Value	Own Result?
CH4Emissions	5.05 (Metric Tons)

Method used to calculate CH4 emissions:Equation Y-9 with a default emission factor

Name	Value	Own Result?
N2OEmissions	1.010 (Metric Tons)

Method used to calculate N2O emissions:Equation Y-10 with a default emission factor

Name	Value	Substitute Indicator	Times Substituted
AnnualAverageExhaustGasFlowRate	()

Manufacturer's method for annual average volumetric flow rate of exhaust gas:

Name	Value	Substitute Indicator	Times Substituted
PercentCO2	()		0

Manufacturer's method for annual average percent CO2 in exhaust gas stream:A continuous emissions montior is used to measure %CO2. The following information submitted through e-GGRT constitutes confidential business information, trade secret information, and/or business proprietary information that is exempt from public disclosure due to the confidential nature of the information (referred to herein as "CBI"). annual average %CO2 (98.256(f)(7) and 98.256(f)(8)) T This information has been handled internally by Phillips 66 on a generally confidential basis and we do not believe that it is in the public domain. If and when this information must be disclosed externally, the release of the information is burdened with appropriate safeguards, such as written confidentiality agreements or claims of trade secret/confidential information. Further, public disclosure of this information would result in significant economic harm to the Company and compromise its competitive position within the marketplace. Accordingly, we request that EPA, its agents, employees, and/or contractors manage and protect the CBI in accordance with applicable law. If in the future EPA makes a decision to disclose some or all of this information, we request that EPA provide Phillips 66 with 15 days advance notice to seek judicial relief.

Name	Value	Substitute Indicator	Times Substituted
PercentCO	()		0

Manufacturer's method for annual average percent CO in exhaust gas stream:A continuous emissions montior calibrated to meet industry standards is used to measure %CO. The following information submitted through e-GGRT constitutes confidential business information, trade secret information, and/or business proprietary information that is exempt from public disclosure due to the confidential nature of the information (referred to herein as "CBI"). annual average %CO (98.256(f)(7) and 98.256(f)(8)) This information has been handled internally by Phillips 66 on a generally confidential basis and we do not believe that it is in the public domain. If and when this information must be disclosed externally, the release of the information is burdened with appropriate safeguards, such as written confidentiality agreements or claims of trade secret/confidential information. Further, public disclosure of this information would result in significant economic harm to the Company and compromise its competitive position within the marketplace. Accordingly, we request that EPA, its agents, employees, and/or contractors manage and protect the CBI in accordance with applicable law. If in the future EPA makes a decision to disclose some or all of this information, we request that EPA provide Phillips 66 with 15 days' advance notice to seek judicial relief.

Name	Value	Substitute Indicator	Times Substituted
PercentO2ExhaustGas	()		0

Manufacturer's method for annual average percent O2 in exhaust gas stream:A continuous emissions montior calibrated to meet industry standards is used to measure %O2. The following information submitted through e-GGRT constitutes confidential business information, trade secret information, and/or business proprietary information that is exempt from public disclosure due to the confidential nature of the information (referred to herein as "CBI"). annual average %O2 (98.256(f)(8)) This information has been handled internally by Phillips 66 on a generally confidential basis and we do not believe that it is in the public domain. If and when this information must be disclosed externally, the release of the information is burdened with appropriate safeguards, such as written confidentiality agreements or claims of trade secret/confidential information. Further, public disclosure of this information would result in significant economic harm to the Company and compromise its competitive position within the marketplace. Accordingly, we request that EPA, its agents, employees, and/or contractors manage and protect the CBI in accordance with applicable law. If in the future EPA makes a decision to disclose some or all of this information, we request that EPA provide Phillips 66 with 15 days' advance notice to seek judicial relief.

Name	Value	Substitute Indicator	Times Substituted
PercentO2Inlet	()

Sulfur Recovery Details

Sour Gas Details

is Sour Gas Stream Sent Off Site Indicator :Y

Name	Value	Own Result?
CalculatedCO2Emissions	37511.1 (Metric Tons)

Name	Value	Substitute Indicator	Times Substituted
AnnualVolumetricFlow	()		0

Annual Volumetric Flow Method :The annual volume of sour gas feed is measured according to API Technical Report 2571 - Fuel Gas Measurement.

Name	Value	Substitute Indicator	Times Substituted
AverageMoleFractionofCarboninSourGas	()		0

Average Mole Fraction of Carbon in Sour Gas Method :Other (specify)

Delayed Coking Details

Unit Name: Coker Unit 39 - 2 Drum Delayed Coker
Unit Type: Delayed Coking Unit
Unit Description:

Total number of associated delayed coking vessels (or coke drums): 2
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, T_init: pressure correlation and Equation Y-18d
Type of emission factor was used in Equation Y-18f: default factor

Name	Value	Own Result?
CH4Emissions	21.41 (Metric Tons)	N

Process Vents Details

Unit Name:No. 1 H2 Plant PSA Vent
Unit Type:Process Vent
Unit Description:

Name	Value	Own Result?
CO2Emissions	0.4 (Metric Tons)

Name	Value	Own Result?
CH4Emissions	0.06 (Metric Tons)

Name	Value	Substitute Indicator	Times Substituted
AnnualVolumetricFlowDischarged	119093 (scf)

The unit or operation associated with the emission:Other
Control device used to reduce emissions:None
Annual Volume Metric Flow Method:Engineering calculation
Other Annual Volume Metric Flow Method:

InterVentsDetails

Number of cumulative Venting Events4
Total Venting Time1.1

MoleFractionDetails

CO2 Mole Fraction Details

Name	Value	Substitute Indicator	Times Substituted
CO2AnnualAverageMoleFraction	0.07 (fraction (number between 0 and 1))

CO2 Annual Average Mole Fraction Method:Engineering estimates/process knowledge
Other CO2 Annual Average Mole Fraction Method:

CH4 Mole Fraction Details

Name	Value	Substitute Indicator	Times Substituted
CH4AnnualAverageMoleFraction	0.03 (fraction (number between 0 and 1))

CH4 Annual Average Mole Fraction Method:Engineering estimates/process knowledge
Other CH4 Annual Average Mole Fraction Method:

N2O Mole Fraction Details
N2O Annual Average Mole Fraction Method:
Other N2O Annual Average Mole Fraction Method:

Unit Name:No. 2 H2 Plant PSA Vent
Unit Type:Process Vent
Unit Description:

Name	Value	Own Result?
CO2Emissions	0 (Metric Tons)

Name	Value	Own Result?
CH4Emissions	0 (Metric Tons)

Name	Value	Substitute Indicator	Times Substituted
AnnualVolumetricFlowDischarged	0 (scf)

The unit or operation associated with the emission:Other
Control device used to reduce emissions:None
Annual Volume Metric Flow Method:Engineering calculation
Other Annual Volume Metric Flow Method:

InterVentsDetails

Number of cumulative Venting Events0
Total Venting Time0

MoleFractionDetails

CO2 Mole Fraction Details

Name	Value	Substitute Indicator	Times Substituted
CO2AnnualAverageMoleFraction	0 (fraction (number between 0 and 1))

CO2 Annual Average Mole Fraction Method:Engineering estimates/process knowledge
Other CO2 Annual Average Mole Fraction Method:

CH4 Mole Fraction Details

Name	Value	Substitute Indicator	Times Substituted
CH4AnnualAverageMoleFraction	0 (fraction (number between 0 and 1))

Uncontrolled Blowdown Systems

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

Equipment Leak Details

Name	Value	Own Result?
TotalCH4Emissions	18.9 (Metric Tons)

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

Storage Tank Details

Name	Value	Own Result?
StabilizedCrudeTotalCH4Emissions	2.28 (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 Name	Carbon Dioxide
Gas Quantity	14,623,008.2 (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 ID	1
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 ID	2
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 ID	3
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 ID	4
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 ID	5
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 ID	6
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 ID	7
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 ID	8
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 ID	9
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 ID	10
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 ID	11
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 ID	12
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 ID	13
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 ID	14
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 ID	15
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)	14623008.2417
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)