Facility Name:Marathon Petroleum Corporation
Facility Identifier:
Facility Reporting Year:2020
Facility Location:
Address: 3815 116th Avenue SW
City: Dickinson
State: ND
Postal Code: 58601

Facility Site Details:
CO2 equivalent emissions from facility subparts C-II, SS, and TT (metric tons):42,129.3
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:The NACIS Code of the faclity changed as the facility converted from a Petroleum Refinery to a Renewable Diesel Plant. Petroleum Operations – January 1, 2020 through May 8, 2020 Startup/Shutdown Period for coversion to a renewable production facility – May 9, 2020 through November 17, 2020 Chemical Plant Operations – November 18, 2020 through December 31, 2020 -This is a revision based on audit findings
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?
Did you use an EPA-approved BAMM in this reporting year for Subpart P?
Plant Code Indicator:N
Primary NAICS Code:324110
Second Primary NAICS Code:
Additional NAICS Codes: 325199
Parent Company Details:
Parent Company Name:MARATHON PETROLEUM CORP
Address:539 South Main Street, Findlay,  OH 45840
Percent Ownership Interest:100

Subpart C: General Stationary Fuel Combustion

Gas Information Details

Gas NameCarbon Dioxide
Gas Quantity33,196.7 (Metric Tons)
Own Result?

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

Gas NameMethane
Gas Quantity1.14 (Metric Tons)
Own Result?

Gas NameNitrous Oxide
Gas Quantity0.203 (Metric Tons)
Own Result?

Unit Details:
Unit Name : CP-NG
Unit Type : OCS (Other combustion source)
Unit Description :
Other Unit Name :
Common Pipe Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 92.7
Cumulative Maximum Rated Heat Input Capacity: 212.3

Emission Details:
Annual Biogenic CO2 Emissions: 0 (metric tons)
Annual Fossil fuel based CO2 Emissions: 13275.1 (metric tons)

Tier Fuel Details:
Fuel : Natural Gas (Weighted U.S. Average)
Tier Name : Tier 1 (Equation C-1b, natural gas billing in mmBtu)
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
13275.1 (Metric Tons) 0.25 (Metric Tons) 0.025 (Metric Tons) 6.3 (Metric Tons) 7.5 (Metric Tons)


Unit Name : CP-RFG
Unit Type : OCS (Other combustion source)
Unit Description :
Other Unit Name :
Common Pipe Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 92.7
Cumulative Maximum Rated Heat Input Capacity: 198.7

Emission Details:
Annual Biogenic CO2 Emissions: 0 (metric tons)
Annual Fossil fuel based CO2 Emissions: 18981.2 (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 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
18981.2 (Metric Tons) 0.86 (Metric Tons) 0.172 (Metric Tons) 21.4 (Metric Tons) 51.1 (Metric Tons)

Carbon Content Substitute Data Information :
Total number of valid carbon content determinations : 133
Total number of carbon content substitute data values : 37
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 : 133
Total number of molecular weight substitute data values : 37
Frequency of molecular weight determinations : Daily
Molar Volume Constant (MVC) used : 836.6 (scf/kg-mole)

Unit Name : VCU Assist Gas
Unit Type : TODF (Thermal oxidizer, direct fired, no heat recovery)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 42 (mmBtu/hr)

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

Tier Fuel Details:
Fuel : Propane
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 emissionsTotal CH4 emissionsTotal N2O emissionsTotal CH4 emissions CO2eTotal N2O emissions CO2e
63.3 (Metric Tons) 0.00 (Metric Tons) 0.001 (Metric Tons) 0.1 (Metric Tons) 0.2 (Metric Tons)


Unit Name : VCU
Unit Type : TODF (Thermal oxidizer, direct fired, no heat recovery)
Unit Description :
Individual Unit Details:
Use Ivt Indicator: Y
Maximum Rated Heat Input Capacity: 42 (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 1 (Equation C-1)
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
369.7 (Metric Tons) 0.02 (Metric Tons) 0.004 (Metric Tons) 0.5 (Metric Tons) 1.1 (Metric Tons)


Unit Name : GP-Comfort Heat
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: 0.195
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: 507.4 (metric tons)

Tier Fuel Details:
Fuel : Natural Gas (Weighted U.S. Average)
Tier Name : Tier 1 (Equation C-1b, natural gas billing in mmBtu)
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
507.4 (Metric Tons) 0.01 (Metric Tons) 0.001 (Metric Tons) 0.2 (Metric Tons) 0.3 (Metric Tons)



Subpart P: Hydrogen Production


CEMS Monitoring Location (CML) Details

Gas Information Details

Gas NameCarbon Dioxide
Gas Quantity6,827.6 (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: R-1901
Unit Type: Hydrogen production process unit
Unit Description:
CO2Emissions: 6827.6 (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 NameCarbon Dioxide
Gas Quantity1,618.7 (Metric Tons)
Own Result?

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

Gas NameMethane
Gas Quantity15.7 (Metric Tons)
Own Result?

Gas NameNitrous Oxide
Gas Quantity0.016 (Metric Tons)
Own Result?

Flare Gas Details

Name or ID: PK-2402
Description:
Type: Flare
Is the flare serviced by a flare gas recovery system ? N
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: 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?
CO2Emissions1587.1 (Metric Tons)N

NameValueOwn Result?
CH4Emissions4.79 (Metric Tons)N

NameValueOwn Result?
N2OEmissions0.016 (Metric Tons)N

Y3 Equation Details

Total number of start-up, shutdown, or malfunction (SSM) events exceeding 500,000 scf/day: 1

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 :P-1300
Unit Type :Sulfur Recovery Plant
Unit Description :

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

NameValueOwn Result?
CalculatedCO2Emissions31.6 (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 :Sour gas measured by calibrated flowmeters, which are operated consistent with manufacturer's specifications
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 :

Uncontrolled Blowdown Systems

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

Equipment Leak Details

NameValueOwn Result?
TotalCH4Emissions10.7 (Metric Tons)

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

Storage Tank Details


NameValueOwn Result?
StabilizedCrudeTotalCH4Emissions0.21 (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 Quantity960,048.7 (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)


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)960048.7022
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)


BlendedProductsDetails:


BlendedProductsRowDetails:
Unique ID1
Is the product entering the facility or leaving the facility? 98.396(d)(1)(iii)
Blended Product Name 98.396(d)
Blended Product ID 98.396(d)
Annual CO2 Quantity, MT 98.396(d)(1)(ii)
Total Number of Blending Components 98.396(d)(2), 98.396(d)(3)