(13) Sampling analysis results of carbon content of petroleum coke as determined for QA/QC of supplier data under §98.314(d) (percent by weight expressed as a decimal fraction).
(14) Number of separate chloride process lines located at the facility.
(15) The number of times in the reporting year that missing data procedures were followed to measure the carbon contents of petroleum coke (number of months); petroleum coke consumption (number of months); carbon-containing waste generated (number of months); and carbon contents of the carbon-containing waste (number of times during year).
    [74 FR 56374, Oct. 30, 2009, as amended at 75 FR 66469, Oct. 28, 2010; 79 FR 63799, Oct. 24, 2014]
Subpart FF  -  Underground Coal Mines
(§98.326)
Underground coal mines liberating 36,500,000 actual cubic feet of CH4 or more per year
In addition to the information required by §98.3(c), each annual report must contain the following information for each mine:
(a) Quarterly CH4 liberated from each ventilation monitoring point, (metric tons CH4). Where MSHA reports are the monitoring method chosen under §98.324(b), each annual report must include the MSHA reports used to report quarterly CH4 concentration and volumetric flow rate as attachments.
(b) Weekly CH4 liberated from each degasification system monitoring point (metric tons CH4).
(c) Quarterly CH4 destruction at each ventilation and degasification system destruction device or point of offsite transport (metric tons CH4).
(d) Quarterly CH4 emissions (net) from all ventilation and degasification systems (metric tons CH4).
(e) Quarterly CO2 emissions from on-site destruction of coal mine gas CH4, where the gas is not a fuel input for energy generation or use (e.g., flaring) (metric tons CO2).
(f) Quarterly volumetric flow rate for each ventilation monitoring point and units of measure (scfm or acfm), date and location of each measurement, and method of measurement (quarterly sampling or continuous monitoring), used in Equation FF-1 of this subpart. Specify whether the volumetric flow rate measurement at each ventilation monitoring point is on dry basis or wet basis; and, if a flow meter is used, indicate whether or not the flow meter automatically corrects for moisture content.
(g) Quarterly CH4 concentration for each ventilation monitoring point, dates and locations of each measurement, and method of measurement (sampling or continuous monitoring). Specify whether the CH4 concentration measurement at each ventilation monitoring point is on dry basis or wet basis.
(h) Weekly volumetric flow rate used to calculate CH4 liberated from degasification systems and units of measure (acfm or scfm), and method of measurement (sampling or continuous monitoring), used in Equation FF-3 of this subpart. Specify whether the volumetric flow rate measurement at each degasification monitoring point is on dry basis or wet basis; and, if a flow meter is used, indicate whether or not the flow meter automatically corrects for moisture content.
(i) Quarterly CH4 concentration (%) used to calculate CH4 liberated from degasification systems, and if the data is based on CEMS or weekly sampling. Specify whether the CH4 concentration measurement at each degasification monitoring point is on dry basis or wet basis.
(j) Weekly volumetric flow rate used to calculate CH4 destruction for each destruction device and each point of offsite transport, and units of measure (acfm or scfm).
(k) Weekly CH4 concentration (%) used to calculate CH4 flow to each destruction device and each point of offsite transport (C).
(l) Dates in quarterly reporting period where active ventilation of mining operations is taking place.
(m) Dates in quarterly reporting period where degasification of mining operations is taking place.
(n) Dates in quarterly reporting period when continuous monitoring equipment is not properly functioning, if applicable.
(o) Temperature (°R), pressure (atm), moisture content (if applicable), and the moisture correction factor (if applicable) used in Equations FF-1 and FF-3 of this subpart; and the gaseous organic concentration correction factor, if Equation FF-9 of this subpart was required. Moisture content is required to be reported only if CH4 concentration is measured on a wet basis and volumetric flow is measured on a dry basis, if CH4 concentration is measured on a dry basis and volumetric flow is measured on a wet basis; and, if a flow meter is used, the flow meter does not automatically correct for moisture content.
(p) For each destruction device, a description of the device, including an indication of whether destruction occurs at the coal mine or off-site. If destruction occurs at the mine, also report an indication of whether a back-up destruction device is present at the mine, the annual operating hours for the primary destruction device, the annual operating hours for the back-up destruction device (if present), and the destruction efficiencies assumed (percent).
(q) A description of the gas collection system (manufacturer, capacity, and number of wells) the surface area of the gas collection system (square meters), and the annual operating hours of the gas collection system.
(r) Identification information and description for each well, shaft, and vent hole, including paragraphs (r)(1) through (r)(3) of this section:
(1) Indication of whether the well, shaft, or vent hole is monitored individually, or as part of a centralized monitoring point. Note which method (sampling or continuous monitoring) was used.
(2) Start date and close date of each well, shaft, and vent hole. If the well, shaft, or vent hole is operating through the end of the reporting year, December 31st of the reporting year shall be the close date for purposes of reporting.
(3) Number of days the well, shaft, or vent hole was in operation during the reporting year. To obtain the number of days in the reporting year, divide the total number of hours that the system was in operation by 24 hours per day.
(s) For each centralized monitoring point, identification of the wells and shafts included in the point. Note which method (sampling or continuous monitoring) was used.
(t) Mine Safety and Health Administration (MSHA) identification for this coal mine.
    [75 FR 39763, July 12, 2010, as amended at 76 FR 73903, Nov. 29, 2011; 78 FR 71967, Nov. 29, 2013; 81 FR 89265, Dec. 9, 2016]
Subpart GG  -  Zinc Production
(§98.336)
25,000 metric tons CO2e/year
In addition to the information required by §98.3(c), each annual report must contain the information specified in paragraphs (a) or (b) of this section, as applicable, for each Waelz kiln or electrothermic furnace.
(a) If a CEMS is used to measure CO2 emissions, then you must report under this subpart the relevant information required for the Tier 4 Calculation Methodology in §98.36 and the information listed in this paragraph (a):
(1) Annual zinc product production capacity (tons).
(2) Annual production quantity for each zinc product (tons).
(3) Annual facility production quantity for each zinc product (tons).
(4) Number of Waelz kilns at each facility used for zinc production.
(5) Number of electrothermic furnaces at each facility used for zinc production.
(b) If a CEMS is not used to measure CO2 emissions, then you must report the information listed in this paragraph (b):
(1) Identification number and annual process CO2 emissions from each individual Waelz kiln or electrothermic furnace (metric tons).
(2) Annual zinc product production capacity (tons).
(3) Annual production quantity for each zinc product (tons).
(4) Number of Waelz kilns at each facility used for zinc production.
(5) Number of electrothermic furnaces at each facility used for zinc production.
(6) [Reserved]
(7) [Reserved]
(8) Whether carbon content of each carbon-containing input material charged to each kiln or furnace is based on reports from the supplier or through self measurement using applicable ASTM standard method.
(9) If carbon content of each carbon-containing input material charged to each kiln or furnace is based on self measurement, the ASTM Standard Test Method used.
(10) [Reserved]
(11) Whether carbon content of the carbon electrode used in each furnace is based on reports from the supplier or through self measurement using applicable ASTM standard method.
(12) If carbon content of carbon electrode used in each furnace is based on self measurement, the ASTM standard method used.
(13) If you use the missing data procedures in §98.335(b), you must report how the monthly mass of carbon-containing materials with missing data was determined and the number of months the missing data procedures were used.
    [74 FR 56374, Oct. 30, 2009, as amended at 75 FR 66470, Oct. 28, 2010; 79 FR 63799, Oct. 24, 2014]
Subpart HH  -  Municipal Solid Waste Landfills
(§98.346)
Municipal solid waste landfills that generate CH4 in amounts equivalent to 25,000 metric tons CO2e or more per year
In addition to the information required by §98.3(c), each annual report must contain the following information for each landfill.
(a) A classification of the landfill as "open" (actively received waste in the reporting year) or "closed" (no longer receiving waste), the year in which the landfill first started accepting waste for disposal, the last year the landfill accepted waste (for open landfills, enter the estimated year of landfill closure), the capacity (in metric tons) of the landfill, an indication of whether leachate recirculation is used during the reporting year and its typical frequency of use over the past 10 years (e.g., used several times a year for the past 10 years, used at least once a year for the past 10 years, used occasionally but not every year over the past 10 years, not used), an indication as to whether scales are present at the landfill, and the waste disposal quantity for each year of landfilling required to be included when using Equation HH-1 of this subpart (in metric tons, wet weight).
(b) Method for estimating reporting year and historical waste disposal quantities, reason for its selection, and the range of years it is applied. For years when waste quantity data are determined using the methods in §98.343(a)(3), report separately the quantity of waste determined using the methods in §98.343(a)(3)(i) and the quantity of waste determined using the methods in §98.343(a)(3)(ii). For historical waste disposal quantities that were not determined using the methods in §98.343(a)(3), provide the population served by the landfill for each year the Equation HH-2 of this subpart is applied, if applicable, or, for open landfills using Equation HH-3 of this subpart, provide the value of landfill capacity (LFC) used in the calculation.
(c) Waste composition for each year required for Equation HH-1 of this subpart, in percentage by weight, for each waste category listed in Table HH-1 to this subpart that is used in Equation HH-1 of this subpart to calculate the annual modeled CH4 generation.
(d) For each waste type used to calculate CH4 generation using Equation HH-1 of this subpart, you must report:
(1) Degradable organic carbon (DOC) and fraction of DOC dissimilated (DOCF) values used in the calculations.
(2) Decay rate (k) value used in the calculations.
(e) Fraction of CH4 in landfill gas (F), an indication of whether the fraction of CH4 was determined based on measured values or the default value, and the methane correction factor (MCF) used in the calculations. If an MCF other than the default of 1 is used, provide an indication of whether active aeration of the waste in the landfill was conducted during the reporting year, a description of the aeration system, including aeration blower capacity, the fraction of the landfill containing waste affected by aeration, the total number of hours during the year the aeration blower was operated, and other factors used as a basis for the selected MCF value.
(f) The surface area of the landfill containing waste (in square meters), identification of the type(s) of cover material used (as either organic cover, clay cover, sand cover, or other soil mixtures).
(g) The modeled annual methane generation rate for the reporting year (metric tons CH4) calculated using Equation HH-1 of this subpart.
(h) For landfills without gas collection systems, the annual methane emissions (i.e., the methane generation, adjusted for oxidation, calculated using Equation HH-5 of this subpart), reported in metric tons CH4, the oxidation fraction used in the calculation, and an indication of whether passive vents and/or passive flares (vents or flares that are not considered part of the gas collection system as defined in §98.6) are present at this landfill.
(i) For landfills with gas collection systems, you must report:
(1) Total volumetric flow of landfill gas collected for destruction for the reporting year (cubic feet at 520 °R or 60 degrees Fahrenheit and 1 atm).
(2) Annual average CH4 concentration of landfill gas collected for destruction (percent by volume).
(3) Monthly average temperature and pressure for each month at which flow is measured for landfill gas collected for destruction, or statement that temperature and/or pressure is incorporated into internal calculations run by the monitoring equipment.
(4) An indication as to whether flow was measured on a wet or dry basis, an indication as to whether CH4 concentration was measured on a wet or dry basis, and if required for Equation HH-4 of this subpart, monthly average moisture content for each month at which flow is measured for landfill gas collected for destruction.
(5) An indication of whether destruction occurs at the landfill facility, off-site, or both. If destruction occurs at the landfill facility, also report for each measurement location:
(i) The number of destruction devices associated with the measurement location.
(ii) The annual operating hours of the gas collection system associated with the measurement location.
(iii) For each destruction device associated with the measurement location, report:
(A) The destruction efficiency (decimal).
(B) The annual operating hours where active gas flow was sent to the destruction device.
(6) Annual quantity of recovered CH4 (metric tons CH4) calculated using Equation HH-4 of this subpart for each measurement location.
(7) A description of the gas collection system (manufacturer, capacity, and number of wells), the surface area (square meters) and estimated waste depth (meters) for each area specified in Table HH-3 to this subpart, the estimated gas collection system efficiency for landfills with this gas collection system and an indication of whether passive vents and/or passive flares (vents or flares that are not considered part of the gas collection system as defined in §98.6) are present at the landfill.
(8) Methane generation corrected for oxidation calculated using Equation HH-5 of this subpart, reported in metric tons CH4, and the oxidation fraction used in the calculation.
(9) Methane generation (GCH4) value used as an input to Equation HH-6 of this subpart. Specify whether the value is modeled (GCH4 from HH-1 of this subpart) or measured (R from Equation HH-4 of this subpart).
(10) Methane generation corrected for oxidation calculated using Equation HH-7 of this subpart, reported in metric tons CH4, and the oxidation fraction used in the calculation.
(11) Methane emissions calculated using Equation HH-6 of this subpart, reported in metric tons CH4, and the oxidation fraction used in the calculation.
(12) Methane emissions calculated using Equation HH-8 of this subpart, reported in metric tons CH4, and the oxidation fraction used in the calculation.
(13) Methane emissions for the landfill (i.e., the subpart HH total methane emissions). Choose the methane emissions from either Equation HH-6 or Equation HH-8 of this subpart that best represents the emissions from the landfill. If the quantity of recovered CH4 from Equation HH-4 of this subpart is used as the value of GCH4 in Equation HH-6, use the methane emissions calculated using Equation HH-8 as the methane emissions for the landfill.
    [74 FR 56374, Oct. 30, 2009, as amended at 75 FR 66472, Oct. 28, 2010; 78 FR 71970, Nov. 29, 2013; 81 FR 89266, Dec. 9, 2016]
Subpart II  -  Industrial Wastewater Management
(§98.356)
25,000 metric tons CO2e/year
    In addition to the information required by §98.3(c), each annual report must contain the following information for each wastewater treatment system.
    (a) Identify the anaerobic processes used in the industrial wastewater treatment system to treat industrial wastewater and industrial wastewater treatment sludge, provide a unique identifier for each anaerobic process, indicate the average depth in meters of each anaerobic lagoon, and indicate whether biogas generated by each anaerobic process is recovered. Provide a description or diagram of the industrial wastewater treatment system, identifying the processes used, indicating how the processes are related to each other, and providing a unique identifier for each anaerobic process. Each anaerobic process must be identified as one of the following:
    (1) Anaerobic reactor.
    (2) Anaerobic deep lagoon (depth more than 2 meters).
    (3) Anaerobic shallow lagoon (depth less than 2 meters).
    (4) Anaerobic sludge digester.
    (b) For each anaerobic wastewater treatment process (reactor, deep lagoon, or shallow lagoon) you must report:
    (1) Weekly average COD or BOD5 concentration of wastewater entering each anaerobic wastewater treatment process, for each week the anaerobic process was operated.
    (2) Volume of wastewater entering each anaerobic wastewater treatment process for each week the anaerobic process was operated.
    (3) Maximum CH4 production potential (B0) used as an input to Equation II-1 or II-2 of this subpart, from Table II-1 to this subpart.
    (4) Methane conversion factor (MCF) used as an input to Equation II-1 or II-2 of this subpart, from Table II-1 to this subpart.
    (5) Annual mass of CH4 generated by each anaerobic wastewater treatment process, calculated using Equation II-1 or II-2 of this subpart.
    (6) If the facility performs an ethanol production processing operation as defined in §98.358, you must indicate if the facility uses a wet milling process or a dry milling process.
    (c) For each anaerobic wastewater treatment process from which biogas is not recovered, you must report the annual CH4 emissions, calculated using Equation II-3 of this subpart.
    (d) For each anaerobic wastewater treatment process and anaerobic sludge digester from which some biogas is recovered, you must report:
    (1) Annual quantity of CH4 recovered from the anaerobic process calculated using Equation II-4 of this subpart.
    (2) Total weekly volumetric biogas flow for each week (up to 52 weeks/year) that biogas is collected for destruction.
    (3) Weekly average CH4 concentration for each week that biogas is collected for destruction.
    (4) Weekly average biogas temperature for each week at which flow is measured for biogas collected for destruction, or statement that temperature is incorporated into monitoring equipment internal calculations.
    (5) Whether flow was measured on a wet or dry basis, whether CH4 concentration was measured on a wet or dry basis, and if required for Equation II-4 of this subpart, weekly average moisture content for each week at which flow is measured for biogas collected for destruction, or statement that moisture content is incorporated into monitoring equipment internal calculations.
    (6) Weekly average biogas pressure for each week at which flow is measured for biogas collected for destruction, or statement that pressure is incorporated into monitoring equipment internal calculations.
    (7) CH4 collection efficiency (CE) used in Equation II-5 of this subpart.
    (8) Whether destruction occurs at the facility or off-site. If destruction occurs at the facility, also report whether a back-up destruction device is present at the facility, the annual operating hours for the primary destruction device, the annual operating hours for the back-up destruction device (if present), the destruction efficiency for the primary destruction device, and the destruction efficiency for the back-up destruction device (if present).
    (9) For each anaerobic process from which some biogas is recovered, you must report the annual CH4 emissions, as calculated by Equation II-6 of this subpart.
    (e) The total mass of CH4 emitted from all anaerobic processes from which biogas is not recovered (calculated in Equation II-3 of this subpart) and from all anaerobic processes from which some biogas is recovered (calculated in Equation II-6 of this subpart) using Equation II-7 of this subpart.
[75 FR 39767, July 12, 2010, as amended at 76 FR 73905, Nov. 29, 2011; 81 FR 89267, Dec. 9, 2017]
Subpart JJ  -  Manure Management
(§98.366)
Manure management systems with combined CH4 and N2O emissions in amounts equivalent to 25,000 metric tons CO2e or more per year
    (a) In addition to the information required by §98.3(c), each annual report must contain the following information:
    (1) List of manure management system components at the facility.
    (2) Fraction of manure from each animal type that is handled in each manure management system component.
    (3) Average annual animal population (for each animal type) for static populations or the results of Equation JJ-4 for growing populations.
    (4) Average number of days that growing animals are kept at the facility (for each animal type).
    (5) The number of animals produced annually for growing populations (for each animal type).
    (6) Typical animal mass (for each animal type).
    (7) Total facility emissions (results of Equation JJ-15).
    (8) CH4 emissions from manure management system components listed in §98.360(b), except digesters (results of Equation JJ-2).
    (9) VS value used (for each animal type).
    (10) B0 value used (for each animal type).
    (11) Methane conversion factor used for each MMS component.
    (12) Average ambient temperature used to select each methane conversion factor.
    (13) N2O emissions (results of Equation JJ-13).
    (14) N value used for each animal type.
    (15) N2O emission factor selected for each MMS component.
    (b) Facilities with anaerobic digesters must also report:
    (1) CH4 emissions from anaerobic digesters (results of Equation JJ-5).
    (2) CH4 flow to the digester combustion device for each digester (results of Equation JJ-6, or value from fully integrated monitoring system as described in 98.363(b)).
    (3) CH4 destruction for each digester (results of Equation JJ-11).
    (4) CH4 leakage for each digester (results of Equation JJ-12).
    (5) Total annual volumetric biogas flow for each digester (results of Equation JJ-7).
    (6) Average annual CH4 concentration for each digester (results of Equation JJ-8).
    (7) Average annual temperature at which gas flow is measured for each digester (results of Equation JJ-9).
    (8) Average annual gas flow pressure at which gas flow is measured for each digester (results of Equation JJ-10).
    (9) Destruction efficiency used for each digester.
    (10) Number of days per year that each digester was operating.
    (11) Collection efficiency used for each digester.

Subpart LL  -  Suppliers of Coal-Based Liquid Fuels
(§98.386)
Producers of coal-to-liquid products:  All in

Importers & Exporters: 25,000 metric tons CO2e/year
    In addition to the information required by §98.3(c), the following requirements apply:
    (a) Producers shall report the following information for each coal-to-liquid facility:
    (1) [Reserved]
    (2) For each product listed in Table MM-1 of subpart MM of this part that enters the coal-to-liquid facility to be further processed or otherwise used on site, report the total annual 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 by blending a fossil fuel-based product with a biomass-based product, report the percent of the volume reported in paragraph (a)(2) of this section that is fossil fuel-based (excluding any denaturant that may be present in any ethanol product).
    (4) --  (5) [Reserved]
    (6) For each product (leaving the coal-to-liquid facility) listed in Table MM-1 of subpart MM of this part, report the total annual quantity in metric tons or barrels. For natural gas liquids, quantity shall reflect the individual components of the product. Those products that enter the facility, 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 fossil fuel-based product with a biomass-based product, report the percent of the volume reported in paragraph (a)(6) of this section that is fossil fuel-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 section for which Calculation Method 2 in §98.393(f)(2) 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 CO2 emissions factor in metric tons CO2 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 in §98.393(f)(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.
    (11) For every product reported in paragraph (a)(6) of this section for which Calculation Method 2 in §98.393(f)(2) 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 CO2 emissions factor in metric tons CO2 per barrel or metric ton of product.
    (12) For every non-solid product reported in paragraph (a)(6) of this section for which Calculation Method 2 of subpart MM of this part 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 coal-to-liquid facility to be co-processed with fossil fuel-based feedstock to produce a product reported in paragraph (a)(6) of this section, report the annual quantity in metric tons or barrels.
    (15) [Reserved]
    (16) The CO2 emissions in metric tons 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).
    (17) The CO2 emissions in metric tons that would result from the complete combustion or oxidation of each product (leaving the coal-to-liquid facility) reported in paragraph (a)(6) of this section that were calculated according to §98.393(a) or (h).
    (18) Annual CO2 emissions in metric tons that would result from the complete combustion or oxidation of each type of biomass feedstock co-processed with fossil fuel-based feedstocks reported in paragraph (a)(14) of this section, calculated according to §98.393(c).
    (19) Annual CO2 emissions that would result from the complete combustion or oxidation of all products, calculated according to §98.393(d).
    (20) Annual 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 paragraph (a)(2) of this section.
    (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 product listed in Table MM-1 of subpart MM of this part, report the total annual quantity in metric tons or barrels. For natural gas liquids, quantity shall reflect the individual components of the product as listed in Table MM-1 of subpart MM of this part.
    (3) For each product reported in paragraph (b)(2) of this section that was produced by blending a fossil fuel-based product with a biomass-based product, report the percent of the volume reported in paragraph (b)(2) of this section that is fossil fuel-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 in §98.393(f)(2) used 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 CO2 emissions factor in metric tons 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 in §98.393(f)(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.
    (7) The CO2 emissions in metric tons that would result from the complete combustion or oxidation of each imported product reported in paragraph (b)(2) of this section, calculated according to §98.393(a).
    (8) The total sum of CO2 emissions that would result from the complete combustion or 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 product listed in table MM-1 of subpart MM of this part, report the total 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 fossil fuel-based product with a biomass-based product, report the percent of the volume reported in paragraph (c)(2) of this section that is fossil fuel-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 in §98.393(f)(2) 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 CO2 emissions factor in metric tons CO2 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 in §98.393(f)(2) 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 CO2 emissions in metric tons that would result from the complete combustion or oxidation of each exported product reported in paragraph (c)(2) of this section, calculated according to §98.393(a).
    (8) Total sum of CO2 emissions that would result from the complete combustion or oxidation of all exported products, calculated according to §98.393(e).
    (d) Blended feedstock and products. (1) Producers, exporters, and importers must report the following information for each blended product and feedstock where emissions were calculated according to §98.393(i):
    (i) Volume or mass of each blending component.
    (ii) The CO2 emissions in metric tons that would result from the complete combustion or oxidation of each blended feedstock or product, using Equation MM-12 or Equation MM-13 of §98.393.
    (iii) Whether it is a blended feedstock or a blended product.
    (2) For a product that enters the facility to be further refined or otherwise used on site that is a blended feedstock, producers must meet the reporting requirements of paragraph (a)(2) of this section by reflecting the individual components of the blended feedstock.
    (3) For a product that is produced, imported, or exported that is a blended product, producers, 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.
[74 FR 56374, Oct. 30, 2009, as amended at 75 FR 66475, Oct. 28, 2010; 78 FR 71972, Nov. 29, 2013; 81 FR 89267, Dec. 9, 2016]
Subpart MM  -  Suppliers of Petroleum Products
(§98.396)
(A) All petroleum refineries that distill crude oil.
(B) Importers of an annual quantity of petroleum products and natural gas liquids that is equivalent to 25,000 metric tons CO2e or more.
(C) Exporters of an annual quantity of petroleum products and natural gas liquids that is equivalent to 25,000 metric tons CO2e or more.
    In addition to the information required 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 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 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)-(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 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 CO2 emissions factor in metric tons CO2 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 CO2 emissions factor in metric tons CO2 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.
    (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 CO2 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 CO2 emissions in metric tons 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 CO2 emissions in metric tons that would result from the complete combustion or oxidation of each type 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 CO2 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 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 used 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 CO2 emissions factor in metric tons CO2 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 CO2 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).
    (8) The sum of CO2 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 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 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 CO2 emissions factor in metric tons CO2 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 CO2 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 CO2 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 CO2 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 blended 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.
[74 FR 56374, Oct. 30, 2009, as amended at 75 FR 66477, Oct. 28, 2010; 78 FR 71973, Nov. 29, 2013]
Subpart NN  -  Suppliers of Natural Gas and Natural Gas Liquids
(§98.406)
(A) All fractionators.
(B) Local natural gas distribution companies that deliver 460,000 thousand standard cubic feet or more of natural gas per year.
    (a) In addition to the information required by §98.3(c), the annual report for each NGL fractionator covered by this rule shall contain the following information.
    (1) Annual quantity (in barrels) of each NGL product supplied (including fractionated NGL products received from other NGL fractionators) in the following product categories: Ethane, propane, normal butane, isobutane, and pentanes plus (Fuelh in Equations NN-1 and NN-2 of this subpart).
    (2) Annual quantity (in barrels) of each NGL product received from other NGL fractionators in the following product categories: Ethane, propane, normal butane, isobutane, and pentanes plus (Fuelg in Equation NN-7 of this subpart).
    (3) Annual volumes in Mscf of natural gas received for processing.
    (4) Annual quantities (in barrels) of y-grade, o-grade, and other bulk NGLs:
    (i) Received.
    (ii) Supplied to downstream users.
    (5) Annual quantity (in barrels) of propane that the NGL fractionator odorizes at the facility and delivers to others.
    (6) Annual CO2 emissions (metric tons) that would result from the complete combustion or oxidation of the quantities in paragraphs (a)(1) and (a)(2) of this section, calculated in accordance with §98.403(a) and (c)(1).
    (7) Annual CO2 mass emissions (metric tons) that would result from the combustion or oxidation of fractionated NGLs supplied less the quantity received from other fractionators, calculated in accordance with §98.403(c)(2). If the calculated value is negative, the reporter shall report the value as zero.
    (8) The specific industry standard used to measure each quantity reported in paragraph (a)(1) of this section.
    (9) If the NGL fractionator developed reporter-specific EFs or HHVs, report the following for each product type:
    (i) The specific industry standard(s) used to develop reporter-specific higher heating value(s) and/or emission factor(s), pursuant to §98.404(b)(2) and (c)(3).
    (ii) The developed HHV(s).
    (iii) The developed EF(s).
    (b) In addition to the information required by §98.3(c), the annual report for each LDC shall contain the following information.
    (1) Annual volume in Mscf of natural gas received by the LDC at its city gate stations for redelivery on the LDC's distribution system, including for use by the LDC (Fuelh in Equations NN-1 and NN-2 of this subpart).
    (2) Annual volume in Mscf of natural gas placed into storage or liquefied and stored (Fuel1 in Equation NN-5a).
    (3) Annual volume in Mscf of natural gas withdrawn from on-system storage and annual volume in Mscf of vaporized liquefied natural gas (LNG) withdrawn from storage for delivery on the distribution system (Fuel2 in Equation NN-5a).
    (4) [Reserved]
    (5) Annual volume in Mscf of natural gas that bypassed the city gate(s) and was supplied through the LDC distribution system. This includes natural gas from producers and natural gas processing plants from local production, or natural gas that was vaporized upon receipt and delivered, and any other source that bypassed the city gate (Fuelz in Equation NN-5b).
    (6) Annual volume in Mscf of natural gas delivered to downstream gas transmission pipelines and other local distribution companies (Fuel in Equation NN-3 of this subpart).
    (7) Annual volume in Mscf of natural gas delivered by the LDC to each large end-user as defined in §98.403(b)(2)(i) of this section.
    (8) The total annual CO2 mass emissions (metric tons) associated with the volumes in paragraphs (b)(1) through (b)(7) of this section, calculated in accordance with §98.403(a) and (b)(1) through (b)(3).
    (9) Annual CO2 emissions (metric tons) that would result from the complete combustion or oxidation of the annual supply of natural gas to end-users registering less than 460,000 Mscf, calculated in accordance with §98.403(b)(4). If the calculated value is negative, the reporter shall report the value as zero.
    (10) The specific industry standard used to develop the volume reported in paragraph (b)(1) of this section.
    (11) If the LDC developed reporter-specific EFs or HHVs, report the following:
    (i) The specific industry standard(s) used to develop reporter-specific higher heating value(s) and/or emission factor(s), pursuant to §98.404 (b)(2) and (c)(3).
    (ii) The developed HHV(s).
    (iii) The developed EF(s).
    (12) For each large end-user reported in paragraph (b)(7) of this section, report:
    (i) The customer name, address, and meter number(s).
    (ii) Whether the quantity of natural gas reported in paragraph (b)(7) of this section is the total quantity delivered to a large end-user's facility, or the quantity delivered to a specific meter located at the facility.
    (iii) If known, report the EIA identification number of each LDC customer.
    (13) The annual volume in Mscf of natural gas delivered by the LDC (including natural gas that is not owned by the LDC) to each of the following end-use categories. For definitions of these categories, refer to EIA Form 176 (Annual Report of Natural Gas and Supplemental Gas Supply & Disposition) and Instructions.
    (i) Residential consumers.
    (ii) Commercial consumers.
    (iii) Industrial consumers.
    (iv) Electricity generating facilities.
    (14) The name of the U.S. state or territory covered in this report submission.
    (c) Each reporter shall report the number of days in the reporting year for which substitute data procedures were used for the following purpose:
    (1) To measure quantity.
    (2) To develop HHV(s).
    (3) To develop EF(s).
    [74 FR 56374, Oct. 30, 2009, as amended at 75 FR 66479, Oct. 28, 2010; 78 FR 71977, Nov. 29, 2013; 81 FR 89269, Dec. 9, 2016]
Subpart OO  -  Suppliers of Industrial Greenhouse Gases
(§98.416)
Producers:  All in

Importers & Exporters with annual bulk imports or exports of N2O, fluorinated GHG, and CO2that in combination are equivalent to 25,000 metric tons CO2e or more.
    In addition to the information required by §98.3(c), each annual report must contain the following information:
    (a) Each fluorinated GHG, fluorinated HTF, or nitrous oxide production facility shall report the following information:
    (1) Mass in metric tons of nitrous oxide and each fluorinated GHG or fluorinated HTF produced at that facility by process, except for amounts that are captured solely to be shipped off site for destruction.
    (2) Mass in metric tons of nitrous oxide and each fluorinated GHG or fluorinated HTF transformed at that facility, by process.
    (3) Mass in metric tons of each fluorinated GHG or fluorinated HTF that is destroyed at that facility and that was previously produced as defined at §98.410(b). Quantities to be reported under paragraph (a)(3) of this section include but are not limited to quantities that are shipped to the facility by another facility for destruction and quantities that are returned to the facility for reclamation but are found to be irretrievably contaminated and are therefore destroyed.
    (4) [Reserved]
    (5) Total mass in metric tons of nitrous oxide and each fluorinated GHG or fluorinated HTF sent to another facility for transformation.
    (6) Total mass in metric tons of each fluorinated GHG or fluorinated HTF sent to another facility for destruction, except fluorinated GHGs and fluorinated HTFs that are not included in the mass produced in §98.413(a) because they are removed from the production process as byproducts or other wastes. Quantities to be reported under paragraph (a)(6) of this section could include, for example, fluorinated GHGs that are returned to the facility for reclamation but are found to be irretrievably contaminated and are therefore sent to another facility for destruction.
    (7) Total mass in metric tons of each fluorinated GHG or fluorinated HTF that is sent to another facility for destruction and that is not included in the mass produced in §98.413(a) because it is removed from the production process as a byproduct or other waste.
    (8)-(9) [Reserved]
    (10) Mass in metric tons of nitrous oxide and each fluorinated GHG or fluorinated HTF fed into the transformation process, by process.
    (11) Mass in metric tons of each fluorinated GHG or fluorinated HTF that is fed into the destruction device and that was previously produced as defined at §98.410(b). Quantities to be reported under paragraph (a)(11) of this section include but are not limited to quantities that are shipped to the facility by another facility for destruction and quantities that are returned to the facility for reclamation but are found to be irretrievably contaminated and are therefore destroyed.
    (12) Mass in metric tons of nitrous oxide and each fluorinated GHG or fluorinated HTF that is measured coming out of the production process, by process.
    (13) Mass in metric tons of used nitrous oxide and of each used fluorinated GHG or fluorinated HTF added back into the production process (e.g., for reclamation), including returned heels in containers that are weighed to measure the mass in §98.414(a), by process.
    (14) Names and addresses of facilities to which any nitrous oxide, fluorinated GHGs, or fluorinated HTFs were sent for transformation, and the quantities (metric tons) of nitrous oxide and of each fluorinated GHG or fluorinated HTF that were sent to each for transformation.
    (15) Names and addresses of facilities to which any fluorinated GHGs or fluorinated HTFs were sent for destruction, and the quantities (metric tons) of each fluorinated GHG or fluorinated HTF that were sent to each for destruction.
    (16) Where missing data have been estimated pursuant to §98.415, the reason the data were missing, the length of time the data were missing, the method used to estimate the missing data, and the estimates of those data.
    (b) Any facility or importer that destroys fluorinated GHGs or fluorinated HTFs shall submit a one-time report containing the information in paragraphs (b)(1) through (6) of this section for each destruction process by the applicable date set forth in paragraph (b)(7) of this section. Facilities and importers that previously submitted one-time reports under this paragraph for all destruction devices used to destroy fluorinated GHGs or fluorinated HTFs are exempt from this requirement unless they meet the conditions in paragraph (b)(6) of this section.
    (1) Destruction efficiency (DE).
    (2) Methods used to determine the destruction efficiency.
    (3) Methods used to record the mass of fluorinated GHG or fluorinated HTF destroyed.
    (4) Chemical identity of the fluorinated GHG(s) used in the performance test conducted to determine DE.
    (5) Name of all applicable federal or state regulations that may apply to the destruction process.
    (6) If any process changes (including the acquisition of a new destruction device) affect unit destruction efficiency or the methods used to record the mass of fluorinated GHG or fluorinated HTF destroyed, then a revised report must be submitted to reflect the changes. The revised report must be submitted to EPA within 60 days of the change.
    (7)(i) Any fluorinated GHG production facility or importer that destroys fluorinated GHGs must submit the one-time destruction report by March 31, 2011 or within 60 days of commencing fluorinated GHG destruction, whichever is later.
    (ii) Any fluorinated GHG production facility or importer that destroys fluorinated HTFs that are not also fluorinated GHGs must submit the one-time destruction report by March 31, 2019 or within 60 days of commencing fluorinated HTF destruction, whichever is later.
    (iii) Any facility that destroys fluorinated GHGs or fluorinated HTFs but does not produce or import fluorinated GHGs must submit the one-time destruction report by March 31, 2019 or within 60 days of commencing fluorinated GHG or fluorinated HTF destruction, whichever is later.
    (c) Each bulk importer of fluorinated GHGs, fluorinated HTFs, or nitrous oxide shall submit an annual report that summarizes its imports at the corporate level, except for shipments including less than twenty-five kilograms of fluorinated GHGs, fluorinated HTFs, or nitrous oxide, transshipments, and heels that meet the conditions set forth at §98.417(e). The report shall contain the following information for each import:
    (1) Total mass in metric tons of nitrous oxide and each fluorinated GHG or fluorinated HTF imported in bulk, including each fluorinated GHG or fluorinated HTF constituent of the fluorinated GHG or fluorinated HTF product that makes up between 0.5 percent and 100 percent of the product by mass.
    (2) Total mass in metric tons of nitrous oxide and each fluorinated GHG or fluorinated HTF imported in bulk and sold or transferred to persons other than the importer for use in processes resulting in the transformation or destruction of the chemical.
    (3) Date on which the fluorinated GHGs, fluorinated HTFs, or nitrous oxide were imported.
    (4) Port of entry through which the fluorinated GHGs, fluorinated HTFs, or nitrous oxide passed.
    (5) Country from which the imported fluorinated GHGs, fluorinated HTFs, or nitrous oxide were imported.
    (6) Commodity code of the fluorinated GHGs, fluorinated HTFs, or nitrous oxide shipped.
    (7) Importer number for the shipment.
    (8) Total mass in metric tons of each fluorinated GHG or fluorinated HTF destroyed by the importer.
    (9) If applicable, the names and addresses of the persons and facilities to which the nitrous oxide, fluorinated GHGs, or fluorinated HTFs were sold or transferred for transformation, and the quantities (metric tons) of nitrous oxide and of each fluorinated GHG or fluorinated HTF that were sold or transferred to each facility for transformation.
    (10) If applicable, the names and addresses of the persons and facilities to which the fluorinated GHGs or fluorinated HTFs were sold or transferred for destruction, and the quantities (metric tons) of each fluorinated GHG or fluorinated HTF that were sold or transferred to each facility for destruction.
    (d) Each bulk exporter of fluorinated GHGs, fluorinated HTFs, or nitrous oxide shall submit an annual report that summarizes its exports at the corporate level, except for shipments including less than twenty-five kilograms of fluorinated GHGs, fluorinated HTFs, or nitrous oxide, transshipments, and heels. The report shall contain the following information for each export:
    (1) Total mass in metric tons of nitrous oxide and each fluorinated GHG or fluorinated HTF exported in bulk.
    (2) Names and addresses of the exporter and the recipient of the exports.
    (3) Exporter's Employee Identification Number.
    (4) Commodity code of the fluorinated GHGs, fluorinated HTFs, or nitrous oxide shipped.
    (5) Date on which, and the port from which, the fluorinated GHGs, fluorinated HTFs, or nitrous oxide were exported from the United States or its territories.
    (6) Country to which the fluorinated GHGs, fluorinated HTFs, or nitrous oxide were exported.
    (e) By March 31, 2011, or within 60 days of commencing fluorinated GHG production, whichever is later, a fluorinated GHG production facility shall submit a one-time report describing the following information:
    (1) The method(s) by which the producer in practice measures the mass of fluorinated GHGs produced, including the instrumentation used (Coriolis flowmeter, other flowmeter, weigh scale, etc.) and its accuracy and precision.
    (2) The method(s) by which the producer in practice estimates the mass of fluorinated GHGs fed into the transformation process, including the instrumentation used (Coriolis flowmeter, other flowmeter, weigh scale, etc.) and its accuracy and precision.
    (3) The method(s) by which the producer in practice estimates the fraction of fluorinated GHGs fed into the transformation process that is actually transformed, and the estimated precision and accuracy of this estimate.
    (4) The method(s) by which the producer in practice estimates the masses of fluorinated GHGs fed into the destruction device, including the method(s) used to estimate the concentration of the fluorinated GHGs in the destroyed material, and the estimated precision and accuracy of this estimate.
    (5) The estimated percent efficiency of each production process for the fluorinated GHG produced.
    (f) By March 31, 2011, all fluorinated GHG production facilities shall submit a one-time report that includes the concentration of each fluorinated GHG constituent in each fluorinated GHG product as measured under §98.414(n). If the facility commences production of a fluorinated GHG product that was not included in the initial report or performs a repeat measurement under §98.414(n) that shows that the identities or concentrations of the fluorinated GHG constituents of a fluorinated GHG product have changed, then the new or changed concentrations, as well as the date of the change, must be reflected in a revision to the report. The revised report must be submitted to EPA by the March 31st that immediately follows the measurement under §98.414(n).
    (g) Isolated intermediates that are produced and transformed at the same facility are exempt from the reporting requirements of this section.
    (h) Low-concentration constituents are exempt from the reporting requirements of this section.
    (i) Each facility that destroys fluorinated GHGs or fluorinated HTFs but does not otherwise report under this section shall report the mass in metric tons of each fluorinated GHG or fluorinated HTF that is destroyed at that facility and that was previously produced as defined at §98.410(b) or (d), as applicable. Quantities to be reported under this paragraph (i) include but are not limited to quantities that are shipped to the facility by another facility for destruction and quantities that are returned to the facility for reclamation but are found to be irretrievably contaminated and are therefore destroyed.
    (j) By March 31, 2019, all facilities that produce fluorinated HTFs that are not also fluorinated GHGs shall submit a one-time report that includes the concentration of each fluorinated HTF or fluorinated GHG constituent in each fluorinated HTF product as measured under §98.414(n). If the facility commences production of a fluorinated HTF product that was not included in the initial report or performs a repeat measurement under §98.414(n) that shows that the identities or concentrations of the fluorinated HTF or fluorinated GHG constituents of a fluorinated HTF product have changed, then the new or changed concentrations, as well as the date of the change, must be provided in a revised report. The revised report must be submitted to EPA by the March 31st that immediately follows the new or repeat measurement under §98.414(n).
[74 FR 56374, Oct. 30, 2009, as amended at 75 FR 79168, Dec. 17, 2010; 76 FR 73905, Nov. 29, 2011; 81 FR 89272, Dec. 9, 2016]
Subpart PP  -  Suppliers of Carbon Dioxide
(§98.426)
Producers:  All in

Bulk importers & exporters with annual bulk imports or exports of N2O, fluorinated GHG, and CO2that in combination are equivalent to 25,000 metric tons CO2e or more

    In addition to the information required by §98.3(c) of subpart A of this part, the annual report shall contain the following information, as applicable:
    (a) If you use Equation PP-1 of this subpart, report the following information for each mass flow meter or CO2 stream that delivers CO2 to containers:
    (1) Annual mass in metric tons of CO2.
    (2) Quarterly mass in metric tons of CO2.
    (3) Quarterly concentration of the CO2 stream.
    (4) The standard used to measure CO2 concentration.
    (5) The location of the flow meter in your process chain in relation to the points of CO2 stream capture, dehydration, compression, and other processing.
    (b) If you use Equation PP-2 of this subpart, report the following information for each volumetric flow meter or CO2 stream that delivers CO2 to containers:
    (1) Annual mass in metric tons of CO2.
    (2) Quarterly volume in standard cubic meters of CO2.
    (3) Quarterly concentration of the CO2 stream in volume or weight percent.
    (4) Report density as follows:
    (i) Quarterly density of the CO2 stream in metric tons per standard cubic meter if you report the concentration of the CO2 stream in paragraph (b)(3) of this section in weight percent.
    (ii) Quarterly density of CO2 in metric tons per standard cubic meter if you report the concentration of the CO2 stream in paragraph (b)(3) of this section in volume percent.
    (5) The method used to measure density.
    (6) The standard used to measure CO2 concentration.
    (7) The location of the flow meter in your process chain in relation to the points of CO2 stream capture, dehydration, compression, and other processing.
    (c) For the aggregated annual mass of CO2 emissions calculated using Equation PP-3a or PP-3b, report the following:
    (1) If you use Equation PP-3a of this subpart, report the annual CO2 mass in metric tons from all flow meters and CO2 streams that deliver CO2 to containers.
    (2) If you use Equation PP-3b of this subpart, report:
    (i) The total annual CO2 mass through main flow meter(s) in metric tons.
    (ii) The total annual CO2 mass through subsequent flow meter(s) in metric tons.
    (iii) The total annual CO2 mass supplied in metric tons.
    (iv) The location of each flow meter in relation to the point of segregation.
    (d) If you use Equation PP-4 of this subpart, report at the corporate level the annual mass of CO2 in metric tons in all CO2 containers that are imported or exported.
    (e) Each reporter shall report the following information:
    (1) The type of equipment used to measure the total flow of the CO2 stream or the total mass or volume in CO2 containers.
    (2) The standard used to operate and calibrate the equipment reported in (e)(1) of this section.
    (3) The number of days in the reporting year for which substitute data procedures were used for the following purpose:
    (i) To measure quantity.
    (ii) To measure concentration.
    (iii) To measure density.
    (f) Report the aggregated annual quantity of CO2 in metric tons that is transferred to each of the following end use applications, if known:
    (1) Food and beverage.
    (2) Industrial and municipal water/wastewater treatment.
    (3) Metal fabrication, including welding and cutting.
    (4) Greenhouse uses for plant growth.
    (5) Fumigants (e.g., grain storage) and herbicides.
    (6) Pulp and paper.
    (7) Cleaning and solvent use.
    (8) Fire fighting.
    (9) Transportation and storage of explosives.
    (10) Injection of carbon dioxide for enhanced oil and natural gas recovery that is covered by subpart UU of this part.
    (11) Geologic sequestration of carbon dioxide that is covered by subpart RR of this part.
    (12) Research and development.
    (13) Other.
    (g) Each production process unit that captures a CO2 stream for purposes of supplying CO2 for commercial applications or in order to sequester or otherwise inject it underground when custody of the CO2 is maintained shall report the percentage of that stream, if any, that is biomass-based during the reporting year.
    (h) If you capture a CO2 stream from an electricity generating unit that is subject to subpart D of this part and transfer CO2 to any facilities that are subject to subpart RR of this part, you must:
    (1) Report the facility identification number associated with the annual GHG report for the subpart D facility;
    (2) Report each facility identification number associated with the annual GHG reports for each subpart RR facility to which CO2 is transferred; and
    (3) Report the annual quantity of CO2 in metric tons that is transferred to each subpart RR facility.
    [74 FR 56374, Oct. 30, 2009, as amended at 75 FR 79171, Dec. 17, 2010; 78 FR 71977, Nov. 29, 2013; 80 FR 64660, Oct. 23, 2015]
Subpart QQ  -  Importers and Exporters of Fluorinated Greenhouse Gases Contained in Pre-Charged Equipment or Closed-Cell Foams
(§98.436)
Importers and exporters of an annual quantity of fluorinated greenhouse gases contained in pre-charged equipment or closed-cell foams that is equivalent to 25,000 metric tons CO2e or more.

    (a) Each importer of fluorinated GHGs contained in pre-charged equipment or closed-cell foams must submit an annual report that summarizes its imports at the corporate level, except for transshipments, as specified:
    (1) Total mass in metric tons of each fluorinated GHG imported in pre-charged equipment or closed-cell foams.
    (2) For each type of pre-charged equipment with a unique combination of charge size and charge type, the identity of the fluorinated GHG used as a refrigerant or electrical insulator, charge size (holding charge, if applicable), and number imported.
    (3) For closed-cell foams that are imported inside of equipment, the identity of the fluorinated GHG contained in the foam, the mass of the fluorinated GHG contained in the foam in each piece of equipment, and the number of pieces of equipment imported with each unique combination of mass and identity of fluorinated GHG within the closed-cell foams.
    (4) For closed cell-foams that are not imported inside of equipment, the identity of the fluorinated GHG in the foam, the density of the fluorinated GHG in the foam (kg fluorinated GHG/cubic foot), and the volume of foam imported (cubic feet) for each type of closed-cell foam with a unique combination of fluorinated GHG density and identity.
    (5) Dates on which the pre-charged equipment or closed-cell foams were imported.
    (6) If the importer does not know the identity and mass of the fluorinated GHGs within the closed-cell foam, the importer must report the following:
    (i) Total mass in metric tons of CO2e of the fluorinated GHGs imported in closed-cell foams.
    (ii) For closed-cell foams that are imported inside of equipment, the mass of the fluorinated GHGs in CO2e contained in the foam in each piece of equipment and the number of pieces of equipment imported for each equipment type.
    (iii) For closed-cell foams that are not imported inside of equipment, the density in CO2e of the fluorinated GHGs in the foam (kg CO2e/cubic foot) and the volume of foam imported (cubic feet) for each type of closed-cell foam.
    (iv) Dates on which the closed-cell foams were imported.
    (v) Name of the foam manufacturer for each type of closed-cell foam where the identity and mass of the fluorinated GHGs is unknown.
    (vi) Certification that the importer was unable to obtain information on the identity and mass of the fluorinated GHGs within the closed-cell foam from the closed-cell foam manufacturer or manufacturers.
    (b) Each exporter of fluorinated GHGs contained in pre-charged equipment or closed-cell foams must submit an annual report that summarizes its exports at the corporate level, except for transshipments, as specified:
    (1) Total mass in metric tons of each fluorinated GHG exported in pre-charged equipment or closed-cell foams.
    (2) For each type of pre-charged equipment with a unique combination of charge size and charge type, the identity of the fluorinated GHG used as a refrigerant or electrical insulator, charge size (including holding charge, if applicable), and number exported.
    (3) For closed-cell foams that are exported inside of equipment, the identity of the fluorinated GHG contained in the foam in each piece of equipment, the mass of the fluorinated GHG contained in the foam in each piece of equipment, and the number of pieces of equipment exported with each unique combination of mass and identity of fluorinated GHG within the closed-cell foams.
    (4) For closed-cell foams that are not exported inside of equipment, the identity of the fluorinated GHG in the foam, the density of the fluorinated GHG in the foam (kg fluorinated GHG/cubic foot), and the volume of foam exported (cubic feet) for each type of closed-cell foam with a unique combination of fluorinated GHG density and identity.
    (5) Dates on which the pre-charged equipment or closed-cell foams were exported.
    (6) If the exporter does not know the identity and mass of the fluorinated GHG within the closed-cell foam, the exporter must report the following:
    (i) Total mass in metric tons of CO2e of the fluorinated GHGs exported in closed-cell foams.
    (ii) For closed-cell foams that are exported inside of equipment, the mass of the fluorinated GHGs in CO2e contained in the foam in each piece of equipment and the number of pieces of equipment imported for each equipment type.
    (iii) For closed-cell foams that are not exported inside of equipment, the density in CO2e of the fluorinated GHGs in the foam (kg CO2 e/cubic foot) and the volume of foam imported (cubic feet) for each type of closed-cell foam.
    (iv) Dates on which the closed-cell foams were exported.
    (v) Name of the foam manufacturer for each type of closed-cell foam where the identity and mass of the fluorinated GHGg is unknown.
    (vi) Certification that the exporter was unable to obtain information on the identity and mass of the fluorinated GHGs within the closed-cell foam from the closed-cell foam manufacturer or manufacturers.
    [74 FR 56374, Oct. 30, 2009, as amended at 78 FR 71978, Nov. 29, 2013]
Subpart RR  -  Geologic Sequestration of Carbon Dioxide
(§98.446)
All in
    In addition to the information required by §98.3(c), report the information listed in this section.
    (a) If you receive CO2 by pipeline, report the following for each receiving flow meter:
    (1) The total net mass of CO2 received (metric tons) annually.
    (2) If a volumetric flow meter is used to receive CO2 report the following unless you reported yes to paragraph (a)(4) of this section:
    (i) The volumetric flow through a receiving flow meter at standard conditions (in standard cubic meters) in each quarter.
    (ii) The volumetric flow through a receiving flow meter that is redelivered to another facility without being injected into your well (in standard cubic meters) in each quarter.
    (iii) The CO2 concentration in the flow (volume percent CO2 expressed as a decimal fraction) in each quarter.
    (3) If a mass flow meter is used to receive CO2 report the following unless you reported yes to paragraph (a)(4) of this section:
    (i) The mass flow through a receiving flow meter (in metric tons) in each quarter.
    (ii) The mass flow through a receiving flow meter that is redelivered to another facility without being injected into your well (in metric tons) in each quarter.
    (iii) The CO2 concentration in the flow (weight percent CO2 expressed as a decimal fraction) in each quarter.
    (4) If the CO2 received is wholly injected and not mixed with any other supply of CO2, report whether you followed the procedures in §98.444(a)(4).
    (5) The standard or method used to calculate each value in paragraphs (a)(2) through (a)(3) of this section.
    (6) The number of times in the reporting year for which substitute data procedures were used to calculate values reported in paragraphs (a)(2) through (a)(3) of this section.
    (7) Whether the flow meter is mass or volumetric.
    (8) A numerical identifier for the flow meter.
    (b) If you receive CO2 in containers, report:
    (1) The mass (in metric tons) or volume at standard conditions (in standard cubic meters) of contents in containers received in each quarter.
    (2) The concentration of CO2 of contents in containers (volume or wt. percent CO2 expressed as a decimal fraction) in each quarter.
    (3) The mass (in metric tons) or volume (in standard cubic meters) of contents in containers that is redelivered to another facility without being injected into your well in each quarter.
    (4) The net mass of CO2 received (in metric tons) annually.
    (5) The standard or method used to calculate each value in paragraphs (b)(1), (b)(2), and (b)(3) of this section.
    (6) The number of times in the reporting year for which substitute data procedures were used to calculate values reported in paragraphs (b)(1) and (b)(2) of this section.
    (c) If you use more than one receiving flow meter, report the total net mass of CO2 received (metric tons) through all flow meters annually.
    (d) The source of the CO2 received according to the following categories:
    (1) CO2 production wells.
    (2) Electric generating unit.
    (3) Ethanol plant.
    (4) Pulp and paper mill.
    (5) Natural gas processing.
    (6) Gasification operations.
    (7) Other anthropogenic source.
    (8) Discontinued enhanced oil and gas recovery project.
    (9) Unknown.
    (e) Report the date that you began collecting data for calculating total amount sequestered according to §98.448(a)(7) of this subpart.
    (f) Report the following. If the date specified in paragraph (e) of this section is during the reporting year for this annual report, report the following starting on the date specified in paragraph (e) of this section.
    (1) For each injection flow meter (mass or volumetric), report:
    (i) The mass of CO2 injected (metric tons) annually.
    (ii) The CO2 concentration in flow (volume or weight percent CO2 expressed as a decimal fraction) in each quarter.
    (iii) If a volumetric flow meter is used, the volumetric flow rate at standard conditions (in standard cubic meters) in each quarter.
    (iv) If a mass flow meter is used, the mass flow rate (in metric tons) in each quarter.
    (v) A numerical identifier for the flow meter.
    (vi) Whether the flow meter is mass or volumetric.
    (vii) The standard used to calculate each value in paragraphs (f)(1)(ii) through (f)(1)(iv) of this section.
    (viii) The number of times in the reporting year for which substitute data procedures were used to calculate values reported in paragraphs (f)(1)(ii) through (f)(1)(iv) of this section.
    (ix) The location of the flow meter.
    (2) The total CO2 injected (metric tons) in the reporting year as calculated in Equation RR-6 of this subpart.
    (3) For CO2 emissions from equipment leaks and vented emissions of CO2, report the following:
    (i) The mass of CO2 emitted (in metric tons) annually from equipment leaks and vented emissions of CO2 from equipment located on the surface between the flow meter used to measure injection quantity and the injection wellhead.
    (ii) The mass of CO2 emitted (in metric tons) annually from equipment leaks and vented emissions of CO2 from equipment located on the surface between the production wellhead and the flow meter used to measure production quantity.
    (4) For each separator flow meter (mass or volumetric), report:
    (i) CO2 mass produced (metric tons) annually.
    (ii) CO2 concentration in flow (volume or weight percent CO2 expressed as a decimal fraction) in each quarter.
    (iii) If a volumetric flow meter is used, volumetric flow rate at standard conditions (standard cubic meters) in each quarter.
    (iv) If a mass flow meter, mass flow rate (metric tons) in each quarter.
    (v) A numerical identifier for the flow meter.
    (vi) Whether the flow meter is mass or volumetric.
    (vii) The standard used to calculate each value in paragraphs (f)(4)(ii) through (f)(4)(iv) of this section.
    (viii) The number of times in the reporting year for which substitute data procedures were used to calculate values reported in paragraphs (f)(4)(ii) through (f)(4)(iv) of this section.
    (5) The entrained CO2 in produced oil or other fluid divided by the CO2 separated through all separators in the reporting year (weight percent CO2 expressed as a decimal fraction) used as the value for X in Equation RR-9 of this subpart and as determined according to your EPA-approved MRV plan.
    (6) Annual CO2 produced in the reporting year as calculated in Equation RR-9 of this subpart.
    (7) For each leakage pathway through which CO2 emissions occurred, report:
    (i) A numerical identifier for the leakage pathway.
    (ii) The CO2 (metric tons) emitted through that pathway in the reporting year.
    (8) Annual CO2 mass emitted (metric tons) by surface leakage in the reporting year as calculated by Equation RR-10 of this subpart.
    (9) Annual CO2 (metric tons) sequestered in subsurface geologic formations in the reporting year as calculated by Equation RR-11 or RR-12 of this subpart.
    (10) Cumulative mass of CO2 (metric tons) reported as sequestered in subsurface geologic formations in all years since the well or group of wells became subject to reporting requirements under this subpart.
    (11) Date that the most recent MRV plan was approved by EPA and the MRV plan approval number that was issued by EPA.
    (12) An annual monitoring report that contains the following components:
    (i) A narrative history of the monitoring efforts conducted over the previous calendar year, including a listing of all monitoring equipment that was operated, its period of operation, and any relevant tests or surveys that were conducted.
    (ii) A description of any changes to the monitoring program that you concluded were not material changes warranting submission of a revised MRV plan under §98.448(d).
    (iii) A narrative history of any monitoring anomalies that were detected in the previous calendar year and how they were investigated and resolved.
    (iv) A description of any surface leakages of CO2, including a discussion of all methodologies and technologies involved in detecting and quantifying the surface leakages and any assumptions and uncertainties involved in calculating the amount of CO2 emitted.
    (13) If a well is permitted under the Underground Injection Control program, for each injection well, report:
    (i) The well identification number used for the Underground Injection Control permit.
    (ii) The Underground Injection Control permit class.
    (14) If an offshore well is not subject to the Safe Drinking Water Act, for each injection well, report any well identification number and any identification number used for the legal instrument authorizing geologic sequestration.
[75 FR 75078, Dec. 1, 2010, as amended at 76 FR 73906, Nov. 29, 2011; 78 FR 71979, Nov. 29, 2013]
Subpart SS  -  Electrical Equipment Manufacture or Refurbishment
(§98.456)
Total annual purchases of SF6and PFCs that exceed 23,000 pounds
    In addition to the information required by §98.3(c), each annual report must contain the following information for each chemical at the facility level:
    (a) Pounds of SF6 and PFCs stored in containers at the beginning of the year.
    (b) Pounds of SF6 and PFCs stored in containers at the end of the year.
    (c) Pounds of SF6 and PFCs purchased in bulk.
    (d) Pounds of SF6 and PFCs returned by equipment users with or inside equipment.
    (e) Pounds of SF6 and PFCs returned to site from off site after recycling.
    (f) Pounds of SF6 and PFCs inside new equipment delivered to customers.
    (g) Pounds of SF6 and PFCs delivered to equipment users in containers.
    (h) Pounds of SF6 and PFCs returned to suppliers.
    (i) Pounds of SF6 and PFCs sent off site for destruction.
    (j) Pounds of SF6 and PFCs sent off site to be recycled.
    (k) The nameplate capacity of the equipment, in pounds, delivered to customers with SF6 or PFCs inside, if different from the quantity in paragraph (f) of this section.
    (l) A description of the engineering methods and calculations used to determine emissions from hoses or other flow lines that connect the container to the equipment that is being filled.
    (m) The values for EFci of Equation SS-5 of this subpart for each hose and valve combination and the associated valve fitting sizes and hose diameters.
    (n) The total number of fill operations for each hose and valve combination, or, FCi of Equation SS-5 of this subpart.
    (o) If the mass of SF6 or the PFC disbursed to customers in new equipment over the period p is determined according to the methods required in §98.453(h), report the mean value of nameplate capacity in pounds for each make, model, and group of conditions.
    (p) If the mass of SF6 or the PFC disbursed to customers in new equipment over the period p is determined according to the methods required in §98.453(h), report the number of samples and the upper and lower bounds on the 95 percent confidence interval for each make, model, and group of conditions.
    (q) Pounds of SF6 and PFCs used to fill equipment at off-site electric power transmission or distribution locations, or MF, of Equation SS-6 of this subpart.
    (r) Pounds of SF6 and PFCs used to charge the equipment prior to leaving the electrical equipment manufacturer or refurbishment facility, or MC, of Equation SS-6 of this subpart.
    (s) The nameplate capacity of the equipment, in pounds, installed at off-site electric power transmission or distribution locations used to determine emissions from installation, or NI, of Equation SS-6 of this subpart.
    (t) For any missing data, you must report the reason the data were missing, the parameters for which the data were missing, the substitute parameters used to estimate emissions in their absence, and the quantity of emissions thereby estimated.
[75 FR 75078, Dec. 1, 2010, as amended at 78 FR 71979, Nov. 29, 2013]
Subpart TT -- Industrial Waste Landfills
(§98.466)
25,000 metric tons CO2e/year
    In addition to the information required by §98.3(c), each annual report must contain the following information for each landfill.
    (a) Report the following general landfill information:
    (1) A classification of the landfill as "open" (actively received waste in the reporting year) or "closed" (no longer receiving waste).
    (2) The year in which the landfill first started accepting waste for disposal.
    (3) The last year the landfill accepted waste (for open landfills, enter the estimated year of landfill closure).
    (4) The capacity (in metric tons) of the landfill.
    (5) An indication of whether leachate recirculation is used during the reporting year and its typical frequency of use over the past 10 years (e.g., used several times a year for the past 10 years, used at least once a year for the past 10 years, used occasionally but not every year over the past 10 years, not used).
    (b) Report the following waste characterization and modeling information:
    (1) The number of waste steams (including "Other Industrial Solid Waste (not otherwise listed)" and "Inerts") for which Equation TT-1 of this subpart is used to calculate modeled CH4 generation.
    (2) A description of each waste stream (including the types of materials in each waste stream) for which Equation TT-1 of this subpart is used to calculate modeled CH4 generation.
    (3) The fraction of CH4 in the landfill gas, F, (volume fraction, dry basis, corrected to 0% oxygen) for the reporting year and an indication as to whether this was the default value or a value determined through measurement data.
    (4) The methane correction factor (MCF) value used in the calculations. If an MCF value other than the default of 1 is used, provide a description of the aeration system, including aeration blower capacity, the fraction of the landfill containing waste affected by the aeration, the total number of hours during the year the aeration blower was operated, and other factors used as a basis for the selected MCF value.
    (5) For each waste stream, the decay rate (k) value used in the calculations.
    (c) Report the following historical waste information:
    (1) [Reserved]
    (2) For each waste stream identified in paragraph (b) of this section, the method(s) for estimating historical waste disposal quantities and the range of years for which each method applies.
    (3) For each waste stream identified in paragraph (b) of this section for which Equation TT-2 of this subpart is used, provide:
    (i) [Reserved]
    (ii) The year of the data used in Equation TT-2 of §98.463 for the waste disposal quantity and production quantity, for each year used in Equation TT-2 to calculate the average waste disposal factor (WDF).
    (iii) [Reserved]
    (4) If Equation TT-4a of this subpart is used, provide:
    (i) The value of landfill capacity (LFC).
    (ii) YrData.
    (iii) YrOpen.
    (5) If Equation TT-4b of this subpart is used, provide:
    (i) WIP (i.e., the quantity of waste in-place at the start of the reporting year from design drawings or engineering estimates (metric tons) or, for closed landfills for which waste in-place quantities are not available, the landfill's design capacity).
    (ii) The cumulative quantity of waste placed in the landfill for the years for which disposal quantities are available from company record or from Equation TT-3 of this part.
    (iii) YrLast.
    (iv) YrOpen.
    (v) NYrData.
    (d) For each year of landfilling starting with the "Start Year" (S) and each year thereafter up to the current reporting year, report the following information:
    (1) The calendar year for which the following data elements apply.
    (2) The quantity of waste (WX) disposed of in the landfill (metric tons, wet weight) for the specified year for each waste stream identified in paragraph (b) of this section.
    (3) For each waste stream, the degradable organic carbon (DOCX) value (mass fraction) for the specified year and an indication as to whether this was the default value from Table TT-1 to this subpart, a measured value using a 60-day anaerobic biodegradation test as specified in §98.464(b)(4)(i), or a value based on total and volatile solids measurements as specified in §98.464(b)(4)(ii). If DOCX was determined by a 60-day anaerobic biodegradation test, specify the test method used.
    (e) Report the following information describing the landfill cover material:
    (1) The type of cover material used (as either organic cover, clay cover, sand cover, or other soil mixtures).
    (2) For each type of cover material used, the surface area (in square meters) at the start of the reporting year for the landfill sections that contain waste and that are associated with the selected cover type.
    (f) The modeled annual methane generation (GCH4) for the reporting year (metric tons CH4) calculated using Equation TT-1 of this subpart.
    (g) For landfills without gas collection systems, provide:
    (1) The annual methane emissions (i.e., the methane generation (MG), adjusted for oxidation, calculated using Equation TT-6 of this subpart), reported in metric tons CH4.
    (2) An indication of whether passive vents and/or passive flares (vents or flares that are not considered part of the gas collection system as defined in §98.6) are present at this landfill.
    (h) For landfills with gas collection systems, in addition to the reporting requirements in paragraphs (a) through (f) of this section, provide:
    (1) The annual methane generation, adjusted for oxidation, calculated using Equation TT-6 of this subpart, reported in metric tons CH4.
    (2) The oxidation factor used in Equation TT-6 of this subpart.
    (3) All information required under 40 CFR 98.346(i)(1) through (7) and 40 CFR 98.346(i)(9) through (12).
    [75 FR 39773, July 12, 2010, as amended at 76 FR 73909, Nov. 29, 2011; 78 FR 71980, Nov. 29, 2013; 79 FR 63799, Oct. 24, 2014]
Subpart UU  -  Injection of Carbon Dioxide
(§98.476)
All In
If you are subject to this part and report under this subpart, you are not required to report the information in §98.3(c)(4) for this subpart. In addition to the information required by §98.3(c)(1) through §98.3(c)(3) and by §98.3(c)(5) through §98.3(c)(9), you must report the information listed in this section.
(a) If you receive CO2 by pipeline, report the following for each receiving flow meter:
(1) The total net mass of CO2 received (metric tons) annually.
(2) If a volumetric flow meter is used to receive CO2:
(i) The volumetric flow through a receiving flow meter at standard conditions (in standard cubic meters) in each quarter.
(ii) The volumetric flow through a receiving flow meter that is redelivered to another facility without being injected into your well (in standard cubic meters) in each quarter.
(iii) The CO2 concentration in the flow (volume percent CO2 expressed as a decimal fraction) in each quarter.
(3) If a mass flow meter is used to receive CO2:
(i) The mass flow through a receiving flow meter (in metric tons) in each quarter.
(ii) The mass flow through a receiving flow meter that is redelivered to another facility without being injected into your well (in metric tons) in each quarter.
(iii) The CO2 concentration in the flow (weight percent CO2 expressed as a decimal fraction) in each quarter.
(4) The standard or method used to calculate each value in paragraphs (a)(2) through (a)(3) of this section.
(5) The number of times in the reporting year for which substitute data procedures were used to calculate values reported in paragraphs (a)(2) through (a)(3) of this section.
(6) Whether the flow meter is mass or volumetric.
(b) If you receive CO2 in containers, report:
(1) The mass (in metric tons) or volume at standard conditions (in standard cubic meters) of contents in containers in each quarter.
(2) The concentration of CO2 of contents in containers (volume or weight percent CO2 expressed as a decimal fraction) in each quarter.
(3) The mass (in metric tons) or volume (in standard cubic meters) of contents in containers that is redelivered to another facility without being injected into your well in each quarter.
(4) The net total mass of CO2 received (in metric tons) annually.
(5) The standard or method used to calculate each value in paragraphs (b)(1), (b)(2), and (b)(3) of this section.
(6) The number of times in the reporting year for which substitute data procedures were used to calculate values reported in paragraphs (b)(1) and (b)(2) of this section.
(c) If you use more than one receiving flow meter, report the net total mass of CO2 received (metric tons) through all flow meters annually.
(d) The source of the CO2 received according to the following categories:
(1) CO2 production wells.
(2) Electric generating unit.
(3) Ethanol plant.
(4) Pulp and paper mill.
(5) Natural gas processing.
(6) Gasification operations.
(7) Other anthropogenic source.
(8) Discontinued enhanced oil and gas recovery project.
(9) Unknown.
(e) Report the following:
(1) Whether the facility received a Research and Development project exemption from reporting under 40 CFR part 98, subpart RR, for this reporting year. If you received an exemption, report the start and end dates of the exemption approved by EPA.
(2) Whether the facility includes a well or group of wells where a CO2 stream was injected into subsurface geologic formations to enhance the recovery of oil during this reporting year.
(3) Whether the facility includes a well or group of wells where a CO2 stream was injected into subsurface geologic formations to enhance the recovery of natural gas during this reporting year.
(4) Whether the facility includes a well or group of wells where a CO2 stream was injected into subsurface geologic formations for acid gas disposal during this reporting year.
(5) Whether the facility includes a well or group of wells where a CO2 stream was injected for a purpose other than those listed in paragraphs (e)(1) through (4) of this section. If you injected CO2 for another purpose, report the purpose of the injection.
    [75 FR 75078, Dec. 1, 2010, as amended at 78 FR 71981, Nov. 29, 2013]