Page 1 of 35

**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 pet roleum 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.Page 2 of 35

Any supplier of petroleum products who meets the
r equirements 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 produc ed, used as feedstock, imported, or exported during the calendar year. Additionally, refiners must report CO 2 emissions that would result from the complete combustion or oxidation of any biomass co
-processed with petroleum feedstocks. § 98.393 Calculating 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 produc t and natural gas liquid using Equation MM

– 1 of this section.

Where:
CO 2 i = Annual CO 2 emissions that would result from the complete combustion or oxidation of each petroleum product or natural gas liquid “i” (metric tons). Product i = Annual volume of p roduct “i” produced, imported, or exported by the reporting party (barrels). For refiners, this volume only includes products ex refinery gate, andPage 3 of 35 excludes products that entered the refinery but are not reported under §98.396(a)( 2 ). For natural gas liqui ds, 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 i = Annual CO 2 emissions that would result from the complete combustion or oxidation of each petroleum product “i ” (metric tons). Product i = Annual mass of product “i” produced, imported, or exported by the reporting party (metric tons). For refiners, this mass only includes products ex refinery gate , and excludes products that entered the refinery but are not repor ted under § 98.396(a)( 2 ) . 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 thi s section, any refiner shall calculate CO 2 emissions from each non
crude feedstock using Equation MM

– 2 of this section.

Where:Page 4 of 35

CO 2 j = Annual CO 2 emissions that would result from the complete combustion or oxidation of each non
crude feedstock “j” (metri c 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 feedstock enters a refinery as a solid rather than liquid, the refiner shall calculate CO 2 emissions usin g Equation MM

– 2 of this section. Where:
CO 2 j = 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 b e 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 emis sions from each type of biomass that enters a refinery and is co
-processed with petroleum feedstocks using Equation MM

– 3 of this section.

Where:Page 5 of 35

CO 2 m = Annual CO 2 emissions that would result from the complete combustion or oxidation of each type of biomass “m” (metric tons). Biomass m = Annual volume of a specific type of biomass that enters the refinery and is co
- processed with petroleum feedstocks to produce a petroleum product reported under paragraph (a) of this section (barrels). EFm = 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 m = Annual CO 2 emissions that would result from the complete combustion or oxidation of each type 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). EFm = Biomass
- specific CO 2 emission factor (met ric 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 r = Annual CO 2 emissions that would result from the complete combustion or oxidation of allPage 6 of 35 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 i = 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 j = Annual CO 2 emissions that would result from the complete combustion or oxidation of each non
crude feedstock “j” (metric tons). CO 2 m = Annual CO 2 emissions th at would result from the complete combustion or oxidation of each type of biomass “m” (metric tons). (e) Summary calculation for importer and exporter products . Importers and exporters shall calculate annual CO 2 emissions from all petroleum products and na tural gas liquids imported or exported, respectively, using Equations MM

– 1 and MM

– 5 of this section.

Where:
CO 2 i = Annual CO 2 emissions that would result from the complete combustion or oxidation of each petroleum product or natural gas liquid “i” (metr ic tons). CO 2 x = 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 p etroleum product and natural gas liquid shall be determined using either of the calculation methods described in paragraphs (f)(1) or (f)(2) ofPage 7 of 35

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 emission 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 measurements of carbon share according t o methods set forth in §98.394(c). For all other products, develop emission 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:Page 8 of 35

EF i,j = Emission f actor 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 products, 1 for solid products). Carbon s hare = 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 us e 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 by the procedures 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 appropriatePage 9 of 35

defau lt CO 2 emission factor (EFm ) for biomass in Table MM

– 2 of this subpart to calculate CO 2 emissions in paragraph (c) of this section. (h) Special procedures for blended biomass
- based fuels . In the event that some portion of a petroleum product is biomass
bas ed and was not derived by co
- processing biomass and petroleum feedstocks together (i.e., the petroleum product was produced by blending a petroleum
-based product with a biomass
- based fuel), the reporting party shall calculate emissions for the petroleum pr oduct 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 w ith that product using Equation MM

– 8 of this section in place of Equation MM

– 1 of this section.

Where:
CO 2 i = Annual CO 2 emissions that would result from the complete combustion or oxidation of each petroleum product “i” (metric tons). Product i = 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 barre l) from Table MM

– 1 of this subpart.Page 10 of 35

%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:
CO 2 j = 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 as a fe edstock 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” 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). (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 2Page 11 of 35

emissions associated with that product using Equation MM

– 10 of this section in place of Equation MM

– 1 of this section.

Where:
CO 2 i = Annual CO 2 emissio ns that would result from the complete combustion or oxidation of each product “i” (metric tons). Product i = 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 = Product
- specific CO 2 emission factor (metric tons CO 2 per barrel). EFm = Default CO 2 emission factor from Table MM

– 2 to subpart MM that most closely 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 petroleum product contains denatured ethanol, importers and exporters must f ollow 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 calculate CO 2 emissions using Equation MM

– 10a of this section.

Where:Page 12 of 35

CO 2 i = 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 by 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
- c rude petroleum feedstock that does not contain denatured ethanol must calculate the CO 2 emissions associated with that feedstock using Equation MM

– 11 of this section in place of Equation MM

– 2 of this section.

Where:
CO 2 j = Annual CO 2 emissions that woul d 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
- s pecific CO 2 emission factor (metric tons CO 2 per barrel). EFm = 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 feedsto ck “j” that is biomass
-based, expressed as a fraction (e.g., 75% would be expressed as 0.75 in the above equation).Page 13 of 35

(ii) In the event that a non
- crude feedstock 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 exports a blended product that does not include biomass, the reporter may calculate emissions for the bl ended product according to the method in paragraph (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 entirely of natural gas liquids. (i v) The reporter uses Calculation Method 1.Page 14 of 35

(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 i = Annual CO 2 emissions that would result from the complete combustion or oxidation of a blended product “i” (metric tons). Blending Component i...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.

Where:
CO 2 j = Annual CO 2 emissions that would result from the complete combustion or oxidation of a blended non - crude feedstock “j” (metric tons). Blending Component i...n = Annual volume or mass of each blending component that is blended (barrels or metric tons).Page 15 of 35

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 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 resu lt 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 method or practice.
§ 98.394 Monitoring and QA/QC requirements. (a) Determination of quantity. (1) The quantity of p etroleum 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 Natio nal Standards Institute (ANSI), the American GasPage 16 of 35

Association (AGA), the American Society of Mechanical Engineers (ASME), the American Petroleum Institute (API), and the North American Energy Standards Board (NAESB). (ii) Where no appropriate standard metho d developed by a
consensus -based standards organization 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
- adjust ed 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 use s 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 c ompliance 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 standard method published by a consensus
-Page 17 of 35

based standards organization or you may use an industry standard practice. (b) Equipment Calibration. (1) All measurement equ ipment shall be calibrated prior to its first use for reporting under this subpart, using an appropriate standard method published by a consensus based standards organization or according to the equipment manufacturer's directions. (2) Measurement equipmen t shall be recalibrated at the minimum frequency specified by the standard method used or by the 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 without 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
reco rds 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 year in which the quantity ofPage 18 of 35

that product was measured in accordance with the requirements of this subpart. For example, if a given product was measured as entering the refi nery continuously throughout the reporting year, twelve samples of that product shall be collected over the reporting year, one on any day of each calendar month of that year. If a given product was only measured from April 15 through June 10 of the report ing year, a refiner would collect three samples during that year, one during each of the calendar months 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 by either making a physic al composite of all of the samples collected for the reporting year and testing that single sample or by measuring the individual samples throughout the year and defining the representative density value for thePage 19 of 35

sample set by numerical means , i.e., a mathematical composite. If a physical composite is chosen as the option to obtain the density value, the reporter shall submit each of the individual samples collected during the reporting year to the laboratory responsible for generating the composite sample. (iii) For physical 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 shal l 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 metho d 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 in formation 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.Page 20 of 35

(iii) The carbon share value for a given petroleum product shall be generated by either making a physical composite of all of the samples collected for the reporting year and testing that single sample or by measuring the individual samples throughout the year and defining the representative carbon share value for the sample set by numerical means , i.e., a mathematical composite. If a physical composite is chosen as the option to obtain the carbon share value, the reporter shall submit each of the individual samples collected during the reporting year to the laboratory responsible for generati ng the composite sample. (iv) For physical 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. § 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, types of biomass, feedstocks, or crude oil during any period (e.g., if a meter malfunctions), the following missing data procedures 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'sPage 21 of 35

established procedures for billing purposes in that period as agree d to by the party selling or purchasing the product. (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 party 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 place of Calculation Method 2 of this subpart for the entire reporting year. § 98.396 Data reporting requirements. In addition to the information requ ired by §98.3(c), the following requirements apply: (a) Refiners 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 annual quantity in metric tons or barrels. For natural gas li quids , quantity shall reflect the individual components of the product.Page 22 of 35

(3) For each feedstock reported in paragraph (a)(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 (a)(2) of this section that is petroleum
based (excluding any denaturant that may be present in any ethanol product). (4) [Reserved] (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 compone nts 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]Page 23 of 35

(9) For every 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 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 f actor, 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.Page 24 of 35

(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 Calcula tion 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. (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 would 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 tons that would result from the complete combustion or oxidation of each feedstock rep orted 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 combustion or oxidation of each type of biomassPage 25 of 35

feedstock co
-processed with petroleum f eedstocks reported in paragraph (a)( 1 4 ) 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 NGLs in metric tons or barrels received for processing during the reporting year. Report only quantities of bulk NGLs not reported in (a)(2) of this section. (22) Volume of crude oil in barrels that you injected into a crude oil supply or reservoir. (b) In addition to the information required by §98.3(c), each importer 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, 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 by blending a petroleum
-based product with a biomass
-based product, report the percent of the volume reportedPage 26 of 35

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 used was used to determine an emissions factor, report: (i) The number of samples collected according to §98.394(c). (ii) The sampling stan dard 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 product and natural gas liquid reported in paragraph (b)(2) of this section, calculated according to §98.393(a).Page 27 of 35

(8) The sum of CO 2 emissio ns 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 by §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, 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 (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 repo rted 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.Page 28 of 35

(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 (c)(2) of this section for which Calculation Method 2 of this subpart used 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 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 repor t 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 c ombustion or oxidation of each blended non
- crudePage 29 of 35

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 blended non
- crude feedstock. (3) For a pro duct 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. § 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 informatio n 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, including records documenting any estimations of missing data and the number of calendar days in the reporting year for which substitute dataPage 30 of 35

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 f or 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 subpa rt. (d) Reporters shall maintain laboratory 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. Except as specified in this section, all terms used in this subpart have the same meaning given in the Clean Air Act and subpart A of this part.Page 31 of 35

Bulk NGLs for purposes of reporting under this subpart means mixtures of NGLs that are sold or delivered as undifferentiated product. Natural Gas Liquids (NGLs) for the purposes of reporting under 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. Ge nerally, 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 (metric**  **tons/bbl) Column B:** 

**carbon share**  **(% of mass)**  **Column C:**

**emission factor (metric 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

—WinterPage 32 of 35

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

**carbon share**  **(% of mass)**  **Column C:**

**emission factor (metric tons**  CO 2 /**bbl)** 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 0.3763 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 0.3178Page 33 of 35

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

**carbon share**  **(% of mass)**  **Column C:**

**emission factor (metric tons**  CO 2 /**bbl)** DIPE 0.1156 70.53 0.2990 Distillate Fuel Oil Distillate No. 1

Ultra Low Sulfur 0.1346 86.40 0.4264 Low 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 Low Sulfur 0.1342 87.30 0.4296 High Sulfur 0.1342 87.30 0.4296 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 - Type Jet Fuel 0.1294 86.30 0.4095 Kerosene 0.1346 86.40 0.4264 Diesel

—Other 0.1452 86.47 0.4604 Petrochemical 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 0.4019Page 34 of 35

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

**carbon share**  **(% of mass)**  **Column C:**

**emission factor (metric tons**  CO 2 /**bbl)** 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. 1 70 Ethylene 4 0. 0492 85.63 0. 154 Propane 3 0. 0806 81.71 0. 241 Propylene 3 0. 0827 85.63 0. 2 60 Butane 3 0. 0928 82.66 0. 281 Butylene 3 0. 0972 85.63 0. 30 5 Isobutane 3 0. 0892 82.66 0. 270 Isobutylene 3 0. 0949 85.63 0. 29 8 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 components. 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 most closely represents. 3 The density and emission factors for components of LPG determined at 60 oF and saturation pressure (LPGs other than ethylene) 4 The density and emission factor for ethylene determined at 41oF and saturation pressure. **Table MM –** **2 to Subpart MM of Part 98** **— Default Factors for Biomass**  **** **Based Fuels and Biomass**

**Biomass -** **based fuel and biomass**  **Column A: Density**  **(metric tons/bbl)**  **Column B: Carbon**

**share (% of mass)**  **Column C:**

**Emission factor (metric tons**  CO 2 /**bbl)** Ethanol (100%) 0.1267 52.14 0.2422 Biodiesel (100%, 0.1396 77.30 0.3957Page 35 of 35

**Biomass -** **based fuel and biomass**  **Column A: Density**  **(metric tons/bbl)**  **Column B: Carbon**

**share (% of mass)**  **Column C:**

**Emission factor (metric tons**  CO 2 /**bbl)** methyl ester) Rendered Animal Fat 0.1333 76.19 0.3724 Vegetable Oil 0.1460 76.77 0.4110