GHG Summary Report

CO2 equivalent emissions from facility subparts C-II, SS, and TT (metric tons):16,193.2
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 Y?
Did you use an EPA-approved BAMM in this reporting year for Subpart C?
Plant Code Indicator:N
Primary NAICS Code:324110
Second Primary NAICS Code:

Parent Company Details:

Parent Company Name:HARTREE CHANNELVIEW LLC
Address:16518 De Zavalla Road, Channelview, TX 77530
Percent Ownership Interest:100

Subpart C: General Stationary Fuel Combustion

Gas Information Details

Gas Name	Carbon Dioxide
Gas Quantity	8,567.2 (Metric Tons)
Own Result?

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

Gas Name	Methane
Gas Quantity	0.17 (Metric Tons)
Own Result?

Gas Name	Nitrous Oxide
Gas Quantity	0.017 (Metric Tons)
Own Result?

Unit Details:

Unit Name : H-1 Crude Pre-Flash Charge Heater
Unit Type : PRH (Process Heater)
Unit Description :

Individual Unit Details:
Use Ivt Indicator: N
Maximum Rated Heat Input Capacity: 79 (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 : Monthly

Tier 2 Monthly HHV Details :

January	February	March	April	May	June	July	August	September	October	November	December
N	N	N	N	N	N	N	N	N	N	N	N

Fuel Emission Details :

Total CO2 emissions	Total CH4 emissions	Total N2O emissions	Total CH4 emissions CO2e	Total N2O emissions CO2e
2041.0 (Metric Tons)	0.04 (Metric Tons)	0.004 (Metric Tons)	1 (Metric Tons)	1.1 (Metric Tons)

Equation C2a/C9a Inputs :
Fuel Quantity : 37345064 (scf/year)
Use Default High Heat Value : true
High Heat Value : 0.00103 (mmBtu/scf)

Unit Name : H-2 Crude Pre-Flash Bottoms Heater
Unit Type : PRH (Process Heater)
Unit Description :

Individual Unit Details:
Use Ivt Indicator: N
Maximum Rated Heat Input Capacity: 40 (mmBtu/hr)

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

Tier Fuel Details:

January	February	March	April	May	June	July	August	September	October	November	December
N	N	N	N	N	N	N	N	N	N	N	N

Fuel Emission Details :

Total CO2 emissions	Total CH4 emissions	Total N2O emissions	Total CH4 emissions CO2e	Total N2O emissions CO2e
2073.3 (Metric Tons)	0.04 (Metric Tons)	0.004 (Metric Tons)	1 (Metric Tons)	1.2 (Metric Tons)

Equation C2a/C9a Inputs :
Fuel Quantity : 37936304 (scf/year)
Use Default High Heat Value : true
High Heat Value : 0.00103 (mmBtu/scf)

Unit Name : H-3 Crude Charge Heater
Unit Type : PRH (Process Heater)
Unit Description :

Individual Unit Details:
Use Ivt Indicator: N
Maximum Rated Heat Input Capacity: 80 (mmBtu/hr)

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

Tier Fuel Details:

January	February	March	April	May	June	July	August	September	October	November	December
N	N	N	N	N	N	N	N	N	N	N	N

Fuel Emission Details :

Total CO2 emissions	Total CH4 emissions	Total N2O emissions	Total CH4 emissions CO2e	Total N2O emissions CO2e
3452.8 (Metric Tons)	0.07 (Metric Tons)	0.007 (Metric Tons)	1.6 (Metric Tons)	1.9 (Metric Tons)

Equation C2a/C9a Inputs :
Fuel Quantity : 63178662 (scf/year)
Use Default High Heat Value : true
High Heat Value : 0.00103 (mmBtu/scf)

Unit Name : H-4 Hot Oil Heater
Unit Type : PRH (Process Heater)
Unit Description :

Individual Unit Details:
Use Ivt Indicator: N
Maximum Rated Heat Input Capacity: 37 (mmBtu/hr)

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

Tier Fuel Details:

January	February	March	April	May	June	July	August	September	October	November	December
N	N	N	N	N	N	N	N	N	N	N	N

Fuel Emission Details :

Total CO2 emissions	Total CH4 emissions	Total N2O emissions	Total CH4 emissions CO2e	Total N2O emissions CO2e
801.1 (Metric Tons)	0.02 (Metric Tons)	0.002 (Metric Tons)	0.4 (Metric Tons)	0.5 (Metric Tons)

Equation C2a/C9a Inputs :
Fuel Quantity : 14659161 (scf/year)
Use Default High Heat Value : true
High Heat Value : 0.00103 (mmBtu/scf)

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

Common Pipe Details:
Use Ivt Indicator: N
Maximum Rated Heat Input Capacity: 22.7
Cumulative Maximum Rated Heat Input Capacity: 34.7

Emission Details:
Annual Biogenic CO2 Emissions: 0 (metric tons)
Annual Fossil fuel based CO2 Emissions: 199.0 (metric tons)

Tier Fuel Details:

January	February	March	April	May	June	July	August	September	October	November	December
N	N	N	N	N	N	N	N	N	N	N	N

Fuel Emission Details :

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

Equation C2a/C9a Inputs :
Fuel Quantity : 3640435 (scf/year)
Use Default High Heat Value : true
High Heat Value : 0.00103 (mmBtu/scf)

Subpart Y: Petroleum Refineries

Gas Information Details

Gas Name	Carbon Dioxide
Gas Quantity	6,330.9 (Metric Tons)
Own Result?

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

Gas Name	Methane
Gas Quantity	50.68 (Metric Tons)
Own Result?

Gas Name	Nitrous Oxide
Gas Quantity	0.063 (Metric Tons)
Own Result?

Flare Gas Details

Name or ID: FL-031
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)(ii)(B) - Equation Y-2 Heat Content Monitored

Name	Value	Own Result?
CO2Emissions	6330.9 (Metric Tons)	N

Name	Value	Own Result?
CH4Emissions	19.11 (Metric Tons)	N

Name	Value	Own Result?
N2OEmissions	0.063 (Metric Tons)	N

Y2 Equation Details

Frequency of measurement data: Daily
Annual volume of flare gas combusted: 74.77 MMscf
Specific consensus-based standard method or describe the procedure specified by the flow meter manufacturer: Flare Meter FT4093
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: 1440 MMBtu/MMscf
Method used to determine the annual average higher heating value: ASTM D3588-98 (Reapproved 2003)
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

Name	Value	Own Result?
TotalCH4Emissions	31.2 (Metric Tons)

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

Storage Tank Details

Name	Value	Own Result?
StabilizedCrudeTotalCH4Emissions	0.37 (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:

Name	Value	Own Result?
UnStabilizedCrudeTotalCH4Emissions	0 (Metric Tons)

UnStabilized Crude Calculation Method:Equation Y-23
is UnStablized Crude Received Stored Indicator:
UnStabilized Crude Basis for Mole Fraction:Equation Y-23 default
Other UnStabilized Crude Basis for Mole Fraction:

Subpart MM: Suppliers of Petroleum Products

Gas Information Details

Gas Name	Carbon Dioxide
Gas Quantity	858,051.9 (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)

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)	858051.9392
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)