Page 1 of 26

**Subpart MM**

**— Suppliers of Petroleum Products**  **§ 98. 390**  **Definition of the source category.** This source category

consists of petroleum refineries and importers and exporters of petroleum products and natural gas liquids as listed in Table MM
- 1 of this subpart. (a) A petroleum refinery

for the purpose of this subpart is any facility engaged in producing petroleum products through the distillation of crude oil. (b) A refiner is the owner or operator of a petroleum refinery
. (c) Importer has the same meaning given in § 98. 6 and includes any entity that imports petroleum products or natural gas liquids as listed in Table MM
- 1 of this subpart. Any blender or refiner of refined or semi
- refined petroleum products shall be considered an importer if it otherwise satisfies the aforementioned definition. (d) Exporter has the same meaning given in § 98. 6 and includes any entity that exports petroleum products or natural gas liquids as listed in Table MM
- 1 of this subpart. Any blender or refiner of refined or semi
- refined petroleum products shall be considered an exporter if it otherwise satisfies the aforementioned definition. **§ 98. 391**  **Reporting threshold.** Any supplier of petroleum products who meets the requirements of § 98. 2(a)(4) must report GHG emissions. **§ 98. 392**  **GHGs To report.** Suppliers of petroleum products must report the CO 2 emissions that would result from the complete combustion or oxidation of each petroleum product and natural gas liquid pro duced, used as feedstock, imported, or exported during the calendar ye ar. Additionally , refiners mustPage 2 of 26

report CO 2 emissions that would result from the complete combustion or oxidation of any biomass co
- processed with petroleum feedstocks. **§ 98. 393**  **Calculati ng GHG emissions.**  (a) Calculation for individual products produced, imported, or exported
. (1) Except as provided in paragraphs (h) and (i) of this section, any refiner, importer, or exporter shall calculate CO 2 emissions from each individual petroleum pro duct and natural gas liquid using Equation MM
- 1 of this section.

Where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each petroleum product or natural gas liquid “i” (metric tons). Producti = Annual volume o f product “i” produced, imported, or exported by the reporting party (barrels). For refiners, this volume only includes products ex refinery gate, and excludes products that entered the refinery but are not reported under § 98. 396(a)(2). For natural gas li quids, volumes shall reflect the individual components of the product as listed in Table MM
- 1 to subpart MM. EF i = Product
- specific CO 2 emission factor (metric tons CO 2 per barrel). (2) In the event that an individual petroleum product is produced as a solid rather than liquid any refiner, importer, or exporter shall calculate CO 2 emissions using Equation MM
- 1 of this section. Where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each petroleum product “i” (metric tons). Producti = Annual mass of product “i” produced, imported, or exported by the reporting party (metric tons). For refiners, this mass only inc ludes products ex refinery gate, and excludes products that entered the refinery but are not reported under § 98. 396(a)(2).Page 3 of 26

EF i = Product
- specific CO 2 emission factor (metric tons CO 2 per metric ton of

product). (b) Calculation for individual products that enter a refinery as a non - crude feedstock
. (1) Except as provided in paragraphs (h) and (i) of this section, any refiner shall calculate CO 2 emissions from each non
- crude feedstock using Equation MM
- 2 of this section.

Where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each non
- crude feedstock “j” (metric tons). Feedstock

j = Annual volume of a petroleum product or natural gas liquid “j” that enters the refinery to be further refined or otherwise used on site (barrels). For natural gas liquids, volumes shall reflect the individual components of the product as listed in table MM
- 1 of this subpart. EF j = Feedstock
- specific CO 2 emission factor (metric tons CO 2 per barrel). (2) In the event that a non
- crude feedst ock enters a refinery as a solid rather than liquid, the refiner shall calculate CO 2 emissions using Equation MM
- 2 of this section. Where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each non
- crude feedstock “ j” (metric tons). Feedstock

j = Annual mass of a petroleum product “j” that enters the refinery to be further refined or otherwise used on site (metric tons). EF j = Feedstock
- specific CO 2 emission factor (metric tons CO 2 per metric ton of

feedstock). (c) Calculation for biomass co
- processed with petroleum feedstocks
. (1) Refiners shall calculate CO 2 emissions from each ty pe of biomass that enters a refinery and is co
- processed with petroleum feedstocks using Equation MM
- 3 of this section.

Where:Page 4 of 26

CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each ty

pe of biomass “m” (metric tons). Biomass m = Annual volume of a specific ty pe of biomass that enters the refinery and is co - processed with petroleum feedstocks to pro duce a petroleum product reported under paragraph (a) of this section (barrels). EF m = Biomass
- specific CO 2 emission factor (metric tons CO 2 per barrel). (2) In the event that biomass enters a refinery as a solid rather than liquid and is co
processed with petroleum feedstocks, the refiner shall calculate CO 2 emissions from each type of biomass using Equation MM
- 3 of this section. Where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each ty

pe of biomass “m” (metric tons). Biomass m = Total annual mass of a specific type of biomass that enters the refinery to be co - processed with petroleum feedstocks to produce a petroleum product reported under paragraph (a) of this section (metric tons). EF m = Biomass
- specific CO 2 emission factor (metric tons CO 2 per metric ton of

biomass). (d) Summary

calculation for refinery

products
. Refiners shall calculate annual CO 2 emissions from all products using Equation MM
- 4 of this section.

Where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of all petroleum products and natural gas liquids (ex refinery gate) minus non
- crude feedstocks and any biomass to be co
- processed with petroleum feedstocks. CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each petroleum product or natural gas liquid “i” (metric tons). CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each non
- crude feedstock “j” (metric tons). CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each ty

pe of biomass “m” (metric tons).Page 5 of 26

(e) Summary

calculation for importer and exporter products
. Importers and exporters shall calculate annual CO 2 emissio ns from all petroleum products and natural gas liquids imported or exported, respectivel y, using Equations MM
- 1 and MM
- 5 of this section.

Where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each petroleum product or natural gas liquid “i” (metric tons). CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of all petroleum products and natural gas liquids. (f) Emission factors for petroleum products and natural gas liquids
. The emission factor (EF i,j ) for each petroleum product and natural gas liquid shall be determined using either of the calculation methods described in paragraphs (f)(1) or (f)(2) of this section. The same calculation method must be used for the entire quantity of the product for the reporting year. For refiners, the quantity of a product that enters a refinery (i.e., a non
- crude feedstock) is considered separate from the quantity

of a product ex refinery

gate. (1) Calculation Method 1
. To determine the emiss ion factor (i.e., EF i in Equation MM
- 1) for solid products, multiply the default carbon share factor (i.e., percent carbon by mass) in column B of Table MM
- 1 to this subpart for the appropriate product by 44/12. For all other products, use the default CO 2 emission factor listed in column C of Table MM
- 1 of this subpart for the appropriate product. (2) Calculation Method 2
. (i) For solid products, develop emission factors according to Equation MM
- 6 of this section using a value of 1 for density and direct m easurements of carbon share according to methods set forth in § 98. 394(c). For all other products, develop emissionPage 6 of 26

factors according to Equation MM
- 6 of this section using direct measurements of density and carbon share according to methods set forth in § 98. 394(c).

Where: EF i,j = Emission factor of the petroleum product or natural gas liquid (metric tons

CO 2 per barrel or per metric ton of product). Density = Density of the petroleum product or natural gas liquid (metric tons per barrel for non
- solid p roducts, 1 for solid products). Carbon share = Percent of total mass that carbon represents in the petroleum product or

natural gas liquid, expressed as a fraction (e.g., 75% would be expressed as 0.75 in the above equation). 44/12 = Conversion factor for carbon to carbon dioxide. (ii) If you use a standard method that involves gas chromatography to determine the percent mass of each component in a product, calculate the product's carbon share using Equation MM
- 7 of this section.

Where: Carbon Share = Percent of total mass that carbon represents in the petroleum product or

natural gas liquid. %Composition i* * *n = Percent of total mass that each molecular component in the

petroleum product or natural gas liquid represents as determined b y the procedure s in the selected standard method. %Mass i* * *n = Percent of total mass that carbon represents in each molecular component

of the petroleum product or natural gas liquid. (g) Emission factors for biomass co
- processed with petroleum feedstocks
. Refiners shall use the most appropriate default CO 2 emission factor (EF m) for biomass in Table MM
- 2 of this subpart to calculate CO 2 emissions in paragraph (c) of this section.Page 7 of 26

(h) Special procedures for blended biomass
- based fuels
. In the event that some portion of a petroleum product is biomass
- based and was not derived b y co - processing biomass and petroleum feedstocks together (i.e., the petroleum product was produced b y blending a petroleum
- based product with a biomass
- based fuel ), the reporting party shall calculate emissions for the petroleum product according to one of the methods in paragraphs (h)(1) through (h)(4) of this section, as appropriate. (1) A reporter using Calculation Method 1 to determine the emission factor of a petroleum product shall calculate the CO 2 emissions associated with that product using Equation MM
- 8 of this section in place of Equation MM
- 1 of this section.

Where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidatio n of each petroleum product “i” (metric tons). Producti = Annual volume of each petroleum product “i” produced, imported, or

exported by

the reporting party

(barrels). For refiners, this volume only includes products ex refinery gate. EF i = Petroleum product - specific CO 2 emission factor (metric tons CO 2 per barrel)

from Table MM
- 1 of this subpart. %Vol i = Percent volume of product “i” that is petroleum
- based, not including any

denaturant that may

be present in any

ethanol product, expressed as a fraction (e .g., 75% would be expressed as 0.75 in the above equation). (2) A refinery

using Calculation Method 1 of this subpart to determine the emission factor of a non
- crude petroleum feedstock shall calculate the CO 2 emissions associated with that feedstock using Equation MM
- 9 of this section in place of Equation MM
- 2 of this section.

Where:Page 8 of 26

CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each non
- crude feedstock “j” (metric tons). Feedstock

j = Annual volume of each pe troleum product “j” that enters the refinery as a feedstock to be further refined or otherwise used on site (barrels). EF j = Non
- crude petroleum feedstock
- specific CO 2 emission factor (metric tons

CO 2 per barrel). %Vol j = Percent volume of feedstock “j” th at is petroleum
- based, not including any

denaturant that may

be present in any

ethanol product, expressed as a fraction (e.g., 75% would be expressed as 0.75 in the above equation). (3) Calculation Method 2 procedures for products
. (i) A reporter using Calculation Method 2 of this subpart to determine the emission factor of a petroleum product that does not contain denatured ethanol must calculate the CO 2 emissions associated with that product using Equation MM
- 10 of this section in place of Equation MM
- 1 of this section.

where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each product “i” (metric tons). Producti = Annual volume of each petroleum product “i” produced, imported, or

expo rted by

the reporting party

(barrels). For refiners, this volume only includes products ex refinery gate. EF i = Product
- specific CO 2 emission factor (metric tons CO 2 per barrel). EF m = Default CO 2 emission factor from Table MM
- 2 to subpart MM that most

clo sely represents the component of product “i” that is biomass
- based. %Vol m = Percent volume of petroleum product “i” that is biomass
- based, expressed as

a fraction (e.g., 75% would be expressed as 0.75 in the above equation). (ii) In the event that a petrol eum product contains denatured ethanol, importers and exporters must follow Calculation Method 1 procedures in paragraph (h)(1) of this section; and refineries must sample the petroleum portion of the blended biomass
- based fuel prior to blending and calcul ate CO 2 emissions using Equation MM
- 10a of this section.Page 9 of 26

where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each biomass
- blended fuel “i” (metric tons). Product

p = Annual volume of the petroleum
- based portion of each biomass blended fuel

“i” produced b y the refiner (barrels). EF i = Petroleum product
- specific CO 2 emission factor (metric tons CO 2 per barrel). (4) Calculation Method 2 procedures for non
- crude feedstocks
. (i) A refiner using Calculation Method 2 of this subpart to determine the emission factor of a non
- crude petroleum feedstock that does not contain denatured ethanol must calculate the CO 2 emissions associated with that feedstock using Equation MM
- 11 of th is section in place of Equation MM
- 2 of this section.

where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of each non
- crude feedstock “j” (metric tons). Feedstock

j = Annual volume of each petroleum product “j” that enters the refinery to be further refined or otherwise used on site (barrels). EF j = Feedstock
- specific CO 2 emission factor (metric tons CO 2 per barrel). EF m = Default CO 2 emission factor from Table MM
- 2 to subpart MM that most

closely represents the component of petroleum product “j” that is biomass
based. %Vol m = Percent volume of non
- crude feedstock “j” that is biomass
- based, expressed

as a fraction (e.g., 75% would be expressed as 0.75 in the above equation). (ii) In the event that a non
- crude feed stock contains denatured ethanol, refiners must follow Calculation Method 1 procedures in paragraph (h)(2) of this section. (i) Optional procedures for blended products that do not contain biomass
. (1) In the event that a reporter produces, imports, or exp orts a blended product that does not include biomass, the reporter may

calculate emissions for the blended product according to the method in paragraphPage 10 of 26

(i)(2) of this section. In the event that a refiner receives a blended non
- crude feedstock that does not include biomass, the refiner may calculate emission for the blended non
- crude feedstock according to the method in paragraph (i)(3) of this section. The procedures in this section may be used only if all of the following criteria are met: (i) The reporter knows the relative proportion of each component of the blend (i.e., the mass or volume percentage). (ii) Each component of blended product “i” or blended non
- crude feedstock “j” meets the strict definition of a product listed in Table MM
- 1 to subpart MM. (iii) The blended product or non
- crude feedstock is not comprised entirel y of natural gas liquids. (iv) The reporter uses Calculation Method 1. (v) Solid components are blended only with other solid components. (2) The reporter must calculate emissions for the blended product using Equation MM
- 12 of this section in place of Equation MM
- 1 of this section.

where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of a blended product “i” (metric tons). Blending Componenti...n = Annual volume or mass of each blending component that is

blended (barrels or metric tons). EF i...n = CO 2 emission factors specific to each blending component (metric tons CO 2

per barrel or per metric ton of product). n = Number of blending components blended into blended product “i”. (3) For refineries, the reporter must calculate emissions for the blended non
- crude feedstock using Equation MM
- 13 of this section in place of Equation MM
- 2 of this section.Page 11 of 26

where: CO 2 . = Annual CO 2 emissions that would result from the complete combustion or

oxidation of a blended non
- crude feedstock “j” (metric tons). Blending Componenti...n = Annual volume or mass of each blending component that is

blended (barrels or metric tons). EF i...n = CO 2 em ission factors specific to each blending component (metric tons CO 2

per barrel or per metric ton of product). n = Number of blending components blended into blended non
- crude feedstock

“j”. (4) For refineries, if a blending component “k” used in paragraph (i)(2) of this section enters the refinery

before blending as non
- crude feedstock: (i) The emissions that would result from the complete combustion or oxidation of non
crude feedstock “k” must still be calculated separately using Equation MM
- 2 of this section and applied in Equation MM
- 4 of this section. (ii) The quantity

of blending component “k” applied in Equation MM
- 12 of this section and the quantity

of non
- crude feedstock “k” applied in Equation MM
- 2 of this section must be determined using the same m ethod or practice. **§ 98. 394**  **Monitoring and QA/QC requirements.** (a) Determination of quantity
. (1) The quantity of petroleum products, natural gas liquids, and biomass, shall be determined as follows: (i) Where an appropriate standard method published by a consensus - based standards organization exists, such a method shall be used. Consensus
- based standards organizations include, but are not limited to, the following: ASTM International, the American National Standards Institute (ANSI), the American Gas Assoc iation (AGA), the American Society ofPage 12 of 26

Mechanical Engineers (ASME), the American Petroleum Institute (API), and the North American Energy

Standards Board (NAESB). (ii) Where no appropriate standard method developed by a consensus - based standards organizatio n exists, industry standard practices shall be followed. (iii) For products that are liquid at 60 degrees Fahrenheit and one standard atmosphere, all measurements of quantity shall be temperature
- adjusted and pressure
- adjusted to these conditions. For all other products, reporters shall use appropriate standard conditions specified in the standard method; if temperature and pressure conditions are not specified in the standard method or if a reporter uses an industry standard practice to determine quantity, the reporter shall use appropriate standard conditions according to established industry practices. (2) All measurement equipment (including, but not limited to, flow meters and tank gauges) used for compliance with this subpart shall be appropriate for the standard method or industry standard practice followed under paragraph (a)(1)(i) or (a)(1)(ii) of this section. (3) The annual quantity

of crude oil received shall be determined according to one of the following methods. You may use an appropriate stand ard method published by a consensus based standards organization or you may use an industry

standard practice. (b) Equipment Calibration
. (1) All measurement equipment shall be calibrated prior to its first use for reporting under this subpart, using an ap propriate standard method published by a consensus based standards organization or according to the equipment manufacturer's directions. (2) Measurement equipment shall be recalibrated at the minimum frequency specified by the standard method used or by th e equipment manufacturer's directions. (3) For units and processes that operate continuously with infrequent outages, it may not be possible to complete the calibration of a flow meter or other measurement device withoutPage 13 of 26

disrupting normal process operation . In such cases, the owner or operator may postpone the calibration until the next scheduled maintenance outage. The best available information from company records may be used in the interim. Such postponements shall be documented in the monitoring plan that is required under § 98. 3(g)(5). (c) Procedures for Calculation Method 2 of this subpart
. (1) Reporting parties shall collect one sample of each petroleum product or natural gas liquid on any day of each calendar month of the reporting ye ar in which the quantity of that product was measured in accordance with the requirements of this subpart. For example, if a given product was measured as entering the refinery

continuously throughout the reporting year, twelve samples of that product shall be collected over the reporting ye ar, one on any day of each calendar month of that year. If a given product was onl y measured from April 15 through June 10 of the reporting year, a refiner would collect three samples during that ye ar, one during each of the calendar m onths of April, May and June on a day

when the product was measured as either entering or exiting the refinery . Each sample shall be collected using an appropriate standard method published by a consensus - based standards organization. (2) Mixing and handling of samples shall be performed using an appropriate standard method published by

a consensus - based standards organization. (3) Density measurement. (i) For all products that are not solid, reporters shall test for density using an appropriate standard method published by a consensus - based standards organization. (ii) The density value for a given petroleum product shall be generated b y either making a phy sical composite of all of the samples collected for the reporting year and testing that single sample or b y measuring the individual samples throughout the ye ar and defining thePage 14 of 26

representative density value for the sample set b y numerical means, i.e., a mathematical composite. If a phys ical composite is chosen as the option to obtain the density value, the reporter shall submit each of the individual samples collected during the reporting ye ar to the laboratory

responsible for generating the composite sample. (iii) For phys ical composites, the reporter shall handle the individual samples and the laboratory shall mix them in accordance with an appropriate standard method published by a consensus - based standards organization. (iv) All measurements of density shall be temperature
- adjusted and pressure
- adjusted to the conditions assumed for determining the quantities of the product reported under this subpart. (4) Carbon share measurement. (i) Reporters shall test for carbon share using an appropriate standard method published by a consensus - based standards organization. (ii) If a standard method that involves gas chromatography is used to determine the percent mass of each component in a product, the molecular formula for each component shall be obtained from the information provided in the standard method and the atomic mass of each element in a given molecular component shall be obtained from the periodic table of the elements. (iii) The carbon share value for a given petroleum product shall be generated by either making a phys ical composite of all of the samples collected for the reporting year and testing th at single sample or b y m easuring the individual samples throughout the ye ar and defining the representative carbon share value for the sample set by numerical means, i.e., a mathematical composite. If a phys ical composite is chosen as the option to obtain the carbon share value, thePage 15 of 26

reporter shall submit each of the individual samples collected during the reporting ye ar to the laboratory

responsible for generating the composite sample. (iv) For phys ical composites, the reporter shall handle the individual s amples and the laboratory

shall mix them in accordance with an appropriate standard method published by a consensus - based standards organization. **§ 98. 395**  **Procedures for estimating missing data.** (a) Determination of quantity
. Whenever the quality assurance procedures in § 98. 394(a) cannot be followed to measure the quantity of one or more petroleum products, natural gas liquids, ty pes of biomass, feedstocks, or crude oil during any period (e.g., if a meter malfunctions), the following missing data procedure s shall be used: (1) For quantities of a product that are purchased or sold, a period of missing data shall be substituted using a reporter's established procedures for billing purposes in that period as agreed to by the party selling or purchasing the pro duct. (2) For quantities of a product that are not purchased or sold but of which the custody is transferred, a period of missing data shall be substituted using a reporter's established procedures for tracking purposes in that period as agreed to by the p arty involved in custody transfer of the product. (b) Determination of emission factor
. Whenever any of the procedures in § 98. 394(c) cannot be followed to develop an emission factor for any reason, Calculation Method 1 of this subpart must be used in plac e of Calculation Method 2 of this subpart for the entire reporting ye ar. **§ 98. 396**  **Data reporting requirements.** In addition to the information required b y § 98. 3(c), the following requirements apply :Page 16 of 26

(a) Refin ers shall report the following information for each facility : (1) [Reserved] (2) For each petroleum product or natural gas liquid listed in Table MM
- 1 of this subpart that enters the refinery

to be further refined or otherwise used on site, report the annu al quantity in metric tons or barrels. For natural gas liquids, quantity shall reflect the individual components of the product. (3) For each feedstock reported in paragraph (a)(2) of this section that was produced b y blending a petroleum
- based product with a biomass
- based product, report the percent of the volume reported in paragraph (a)(2) of this section that is petroleum
- based (excluding any denaturant that may

be present in any

ethanol product). (4)
- (5) [Reserved] (6) For each petroleum product and natural gas liquid (ex refinery gate) listed in Table MM
- 1 of this subpart, report the annual quantity in metric tons or barrels. For natural gas liquids, quantity shall reflect the individual components of the product. Petroleum products and natural gas liquids that enter the refinery , but are not reported in (a)(2), shall not be reported under this paragraph. (7) For each product reported in paragraph (a)(6) of this section that was produced by blending a petroleum
- based product with a biomass
- based product , report the percent of the volume reported in paragraph (a)(6) of this section that is petroleum
- based (excluding any denaturant that may

be present in any

ethanol product). (8) [Reserved] (9) For every

feedstock reported in paragraph (a)(2) of this secti on for which Calculation Method 2 of this subpart was used to determine an emissions factor, report:Page 17 of 26

(i) The number of samples collected according to § 98. 394(c) (ii) The sampling standard method used. (iii) The carbon share test results in percent mass. ( iv) The standard method used to test carbon share. (v) The calculated CO 2 emissions factor in metric tons CO 2 per barrel or per metric ton of product. (10) For every

non - solid feedstock reported in paragraph (a)(2) of this section for which Calculation Method 2 of this subpart was used to determine an emissions factor, report: (i) The density test results in metric tons per barrel. (ii) The standard method used to test density
. (11) For every

petroleum product and natural gas liquid reported in paragraph (a)(6) of this section for which Calculation Method 2 of this subpart was used to determine an emissions factor, report: (i) The number of samples collected according to § 98. 394(c). (ii) The sampling standard method used. (iii) The carbon share test results in percent mass. (iv) The standard method used to test carbon share. (v) The calculated CO 2 emissions factor in metric tons CO 2 per barrel or per metric ton of product. (12) For every

non - solid petroleum product and natural gas liquid reported in paragraph (a)(6) for which Calculation Method 2 was used to determine an emissions factor, report: (i) The density test results in metric tons per barrel. (ii) The standard method used to test density
.Page 18 of 26

(13) [Reserved] (14) For each specific type of biomass that enters the refinery to be co
- processed with petroleum feedstocks to produce a petroleum product reported in paragraph (a)(6) of this section, report the annual quantity in metric tons or barrels. (15) [Reserved] (16) The CO 2 emissions in metric tons that w ould result from the complete combustion or oxidation of each petroleum product and natural gas liquid (ex refinery gate) reported in paragraph (a)(6) of this section that were calculated according to § 98. 393(a) or (h). (17) The CO 2 emissions in metric to ns that would result from the complete combustion or oxidation of each feedstock reported in paragraph (a)(2) of this section that were calculated according to § 98. 393(b) or (h). (18) The CO 2 emissions in metric tons that would result from the complete co mbustion or oxidation of each ty

pe of biomass feedstock co
- processed with petroleum feedstocks reported in paragraph (a)(14) of this section, calculated according to § 98. 393(c). (19) The sum of CO 2 emissions that would result from the complete combustion or oxidation of all products, calculated according to § 98. 393(d). (20) For all crude oil that enters the refinery , report the annual quantity in barrels. (21) The quantity of bulk NGL s in metric tons or barrels received for processing during the reporting ye ar. Report only quantities of bulk NGL s not reported in (a)(2) of this section. (22) Volume of crude oil in barrels that you injected into a crude oil suppl y or reservoir. (b) In addition to the information required b y § 98. 3(c), each importer shall rep ort all of the following information at the corporate level: (1) [Reserved]Page 19 of 26

(2) For each petroleum product and natural gas liquid listed in Table MM
- 1 of this subpart, report the annual quantity in metric tons or barrels. For natural gas liquids, quantity shall reflect the individual components of the product. (3) For each product reported in paragraph (b)(2) of this section that was produced b y blending a petroleum
- based product with a biomass
- based product, report the percent of the volume reported in paragraph (b)(2) of this section that is petroleum
- based (excluding any denaturant that may

be present in any

ethanol product). (4) [Reserved] (5) For each product reported in paragraph (b)(2) of this section for which Calculation Method 2 of this subpart use d was used to determine an emissions factor, report: (i) The number of samples collected according to § 98. 394(c). (ii) The sampling standard method used. (iii) The carbon share test results in percent mass. (iv) The standard method used to test carbon share. (v) The calculated CO 2 emissions factor in metric tons CO 2 per barrel or per metric ton of product. (6) For each non
- solid product reported in paragraph (b)(2) of this section for which Calculation Method 2 of this subpart was used to determine an emissions factor, report: (i) The density test results in metric tons per barrel. (ii) The standard method used to test density
. (7) The CO 2 emissions in metric tons that would result from the complete combustion or oxidation of each imported petroleum prod uct and natural gas liquid reported in paragraph (b)(2) of this section, calculated according to § 98. 393(a).Page 20 of 26

(8) The sum of CO 2 emissions that would result from the complete combustion oxidation of all imported products, calculated according to § 98. 393(e ). (c) In addition to the information required b y § 98. 3(c), each exporter shall report all of the following information at the corporate level: (1) [Reserved] (2) For each petroleum product and natural gas liquid listed in Table MM
- 1 of this subpart, repo rt the annual quantity in metric tons or barrels. For natural gas liquids, quantity shall reflect the individual components of the product. (3) For each product reported in paragraph (c)(2) of this section that was produced by blending a petroleum
- based product with a biomass
- based product, report the percent of the volume reported in paragraph (c)(2) of this section that is petroleum based (excluding any denaturant that may

be present in any

ethanol product). (4) [Reserved] (5) For each product reported in paragraph (c)(2) of this section for which Calculation Method 2 of this subpart was used to determine an emissions factor, report: (i) The number of samples collected according to § 98. 394(c). (ii) The sampling standard method used. (iii) The carbon share test results in percentmass. (iv) The standard method used to test carbon share. (v) The calculated CO 2 emissions factor in metric tons CO 2 per barrel or per metric ton of product. (6) For each non
- solid product reported in paragraph (c)(2) of this sectio n for which Calculation Method 2 of this subpart used was used to determine an emissions factor, report:Page 21 of 26

(i) The density test results in metric tons per barrel. (ii) The standard method used to test density
. (7) The CO 2 emissions in metric tons that would result from the complete combustion or oxidation of for each exported petroleum product and natural gas liquid reported in paragraph (c)(2) of this section, calculated according to § 98. 393(a). (8) The sum of CO 2 emissions that would result from the complete combustion or oxidation of all exported products, calculated according to § 98. 393(e). (d) Blended non
- crude feedstock and products
. (1) Refineries, exporters, and importers must report the following information for each blended product and non
- crude feedstock where emissions were calculated according to § 98. 393(i): (i) Volume or mass of each blending component. (ii) The CO 2 emissions in metric tons that would result from the complete combustion or oxidation of each blended non
- crude feedstock or product, using Equation MM
- 12 or Equation MM
- 13 of this section. (iii) Whether it is a blended non
- crude feedstock or a blended product. (2) For a product that enters the refinery to be further refined or otherwise used on site that is a blended non
- crude feedstock, refiners must meet the reporting requirements of paragraph (a)(2) of this section by reflecting the individual components of the b lended non
- crude feedstock. (3) For a product that is produced, imported, or exported that is a blended product, refiners, importers, and exporters must meet the reporting requirements of paragraphs (a)(6), (b)(2), and (c)(2) of this section, as applicable, by reflecting the individual components of the blended product.Page 22 of 26

**§ 98. 397**  **Records that must be retained.** (a) All reporters shall retain copies of all reports submitted to EPA under § 98. 396. In addition, all reporters shall maintain sufficient records to support information contained in those reports, including but not limited to information on the characteristics of their feedstocks and products. (b) Reporters shall maintain records to support quantities that are reported under this subpart, inc luding records documenting any estimations of missing data and the number of calendar day s in the reporting year for which substitute data procedures were followed. For all reported quantities of petroleum products, natural gas liquids, and biomass, reporters shall maintain metering, gauging, and other records normally maintained in the course of business to document product and feedstock flows including the date of initial calibration and the frequency of recalibration for the measurement equipment used. ( c) Reporters shall retain laboratory reports, calculations and worksheets used to estimate the CO 2 emissions of the quantities of petroleum products, natural gas liquids, biomass, and feedstocks reported under this subpart. (d) Reporters shall maintain lab oratory reports, calculations and worksheets used in the measurement of density

and carbon share for any petroleum product or natural gas liquid for which CO 2 emissions were calculated using Calculation Method 2. (e) Estimates of missing data shall be documented and records maintained showing the calculations. (f) Reporters described in this subpart shall also retain all records described in § 98. 3(g). **§ 98. 398**  **Definitions.**Page 23 of 26

Except as specified in this section, all terms used in this subpart have the same me aning given in the Clean Air Act and subpart A of this part. Bulk NGLs for purposes of reporting under this subpart means mixtures of NGL s that are sold or delivered as undifferentiated product. Natural Gas Liquids (NGLs) for the purposes of reporting unde r this subpart means hydrocarbons that are separated from natural gas as liquids through the process of absorption, condensation, adsorption, or other methods, and are sold or delivered as differentiated product. Generally , such liquids consist of ethane, propane, butanes, or pentanes plus. **Table MM -**  **1 to Subpart MM of Part 98**

**— Default Factors for Petroleum Products and**  **Natural Gas Liquids 1 2** 

**Products Column A: density**  **(m etric tons/bbl)**  **Column B:**

**carbon share (% of m**  **ass) Column C:** 

**em ission factor**  **(m etric tons**  **CO 2** **/bbl) Finished Motor Gasoline**  Conventional

— Summer

Regular 0.1181 86.66 0.3753 Midgrade 0.1183 86.63 0.3758 Premium 0.1185 86.61 0.3763 Conventional

—Winter

Regular 0.1155 86.50 0.3663 Midgrade 0.1161 86.55 0.3684 Premium 0.1167 86.59 0.3705 Reformulated

— Summer Regular 0.1167 86.13 0.3686 Midgrade 0.1165 86.07 0.3677 Premium 0.1164 86.00 0.3670 Reformulated

—Winter Regular 0.1165 86.05 0.3676 Midgrade 0.1165 86.06 0.3676 Premium 0.1166 86.06 0.3679 Gasoline

—Other 0.1185 86.61 0.3763Page 24 of 26

**Blendstocks** CBOB

— Summer

Regular 0.1181 86.66 0.3753 Midgrade 0.1183 86.63 0.3758 Premium 0.1185 86.61 0.3763 CBOB

—Winter

Regular 0.1155 86.50 0.3663 Midgrade 0.1161 86.55 0.3684 Premium 0.1167 86.59 0.3705 RBOB

— Summer

Regular 0.1167 86.13 0.3686 Midgrade 0.1165 86.07 0.3677 Premium 0.1164 86.00 0.3670 RBOB

—Winter

Regular 0.1165 86.05 0.3676 Midgrade 0.1165 86.06 0.3676 Premium 0.1166 86.06 0.3679 Blendstocks

—Other 0.1185 86.61 0.3763 **Oxygenates** Methanol 0.1268 37.48 0.1743 GTBA 0.1257 64.82 0.2988 MTBE 0.1181 68.13 0.2950 ETBE 0.1182 70.53 0.3057 TAME 0.1229 70.53 0.3178 DIPE 0.1156 70.53 0.2990 **Distillate Fuel Oil** Distillate No. 1

Ultra Low Sulfur 0.1346 86.40 0.4264 Lo w Sulfur 0.1346 86.40 0.4264 High Sulfur 0.1346 86.40 0.4264 Distillate No. 2

Ultra Low Sulfur 0.1342 87.30 0.4296 Lo w Sulfur 0.1342 87.30 0.4296 High Sulfur 0.1342 87.30 0.4296Page 25 of 26

Distillate Fuel Oil No. 4 0.1452 86.47 0.4604 Residual Fuel Oil No. 5 (Navy Special) 0.1365 85.67 0.4288 Residual Fuel Oil No. 6 (a.k.a. Bunker C) 0.1528 84.67 0.4744 Kerosene
- Ty

pe Jet Fuel 0.1294 86.30 0.4095 Kerosene 0.1346 86.40 0.4264 Diesel

—Other 0.1452 86.47 0.4604 **Petrochem ical Feedstocks** 

Naphthas (<401 °F) 0.1158 84.11 0.3571 Other Oils (>401 °F) 0.1390 87.30 0.4450 Unfinished Oils Heavy Gas Oils 0.1476 85.80 0.4643 Residuum 0.1622 85.70 0.5097 **Other Petroleum**

**Products and Natural Gas Liquids** Aviation Gasoline 0.1120 85.00 0.3490 Special Naphthas 0.1222 84.76 0.3798 Lubricants 0.1428 85.80 0.4492 Waxes 0.1285 85.30 0.4019 Petroleum Coke 0.1818 92.28 0.6151 Asphalt and Road Oil 0.1634 83.47 0.5001 Still Gas 0.1405 77.70 0.4003 Ethane 3 0.0579 79.89 0.170 Ethylene 4 0.0492 85.63 0.154 Propane 3 0.0806 81.71 0.241 Propylene 3 0.0827 85.63 0.260 Butane 3 0.0928 82.66 0.281 Butylene 3 0.0972 85.63 0.305 Isobutane 3 0.0892 82.66 0.270 Isobutylene 3 0.0949 85.63 0.298 Isobutylene 0.0936 85.63 0.2939 Pentanes Plus 0.1055 83.63 0.3235 Miscellaneous Products 0.1380 85.49 0.4326 1 In the case of products blended with some portion of biomass
-based fuel, the carbon share in Table MM
- 1 of this subpart represents only the petroleum
-based com ponents.Page 26 of 26

2 Products that are derived entirely from biomass should not be reported, but products that were derived from both biomass and a petroleum product (i.e., co
-processed) should be reported as the petroleum product that it mo st closely represents. 3 The density and emission factors for components of LPG determined at 60 degrees Fahrenheit and saturation pressure (LPGs other than ethylene). 4 The density and emission factor for ethylene determined at 41 degrees Fahrenheit and saturation pressure. **Table MM -**  **2 to Subpart MM of Part 98**

**— Default Factors for Biomass**  **- Based Fuels and**  **Biomass**

**Bi om**  **ass -**  **based fuel and biomass Column A:**  **Density (m**  **etric tons/bbl) Column B: Carbon share**  **(% of m ass)**  **Column C: Emission factor**  **(m etric tons CO**  **2 /bbl)**  Ethanol (100%) 0.1267 52.14 0.2422 Biodiesel (100%, methyl ester) 0.1396 77.30 0.3957 Rendered Animal Fat 0.1333 76.19 0.3724 Vegetable Oil 0.1460 76.77 0.4110