(a) The carbon dioxide (CO2) supplier source category consists of the following:

(1) Facilities with production process units that capture a CO2 stream for purposes of supplying CO2 for commercial applications or that capture and maintain custody of a CO2 stream in order to sequester or otherwise inject it underground. Capture refers to the initial separation and removal of CO2 from a manufacturing process or any other process.

(2) Facilities with CO2 production wells that extract or produce a CO2 stream for purposes of supplying CO2 for commercial applications or that extract and maintain custody of a CO2 stream in order to sequester or otherwise inject it underground.

(3) Importers or exporters of bulk CO2.

(4) Facilities with process units, including but not limited to direct air capture (DAC), that capture a CO2 stream from ambient air for purposes of supplying CO2 for commercial applications or that capture and maintain custody of a CO2 stream in order to sequester or otherwise inject it underground.

(b) This source category is focused on upstream supply. It does not cover:

(1) Storage of CO2 above ground or in geologic formations.

(2) Use of CO2 in enhanced oil and gas recovery.

(3) Transportation or distribution of CO2.

(4) Purification, compression, or processing of CO2.

(5) On-site use of CO2 captured on site.

(c) This source category does not include CO2 imported or exported in equipment, such as fire extinguishers.

Any supplier of CO2 who meets the requirements of § 98.2(a)(4) of subpart A of this part must report the mass of CO2 captured, extracted, imported, or exported.

(a) Mass of CO2 captured from production process units.

(b) Mass of CO2 extracted from CO2 production wells.

(c) Mass of CO2 imported.

(d) Mass of CO2 exported.

(e) Mass of CO2 captured from DAC process units.

(1) Mass of CO2 captured from ambient air.

(2) Mass of CO2 captured from any on-site heat and/or electricity generation, where applicable.

(a) Except as allowed in paragraph (b) of this section, calculate the annual mass of CO2 captured, extracted, imported, or exported through each flow meter in accordance with the procedures specified in either paragraph (a)(1) or (a)(2) of this section. If multiple flow meters are used, you shall calculate the annual mass of CO2 for all flow meters according to the procedures specified in paragraph (a)(3) of this section.

(1) For each mass flow meter, you shall calculate quarterly the mass of CO2 in a CO2 stream in metric tons by multiplying the mass flow by the composition data, according to Equation PP-1 of this section. Mass flow and composition data measurements shall be made in accordance with § 98.424 of this subpart.

(2) For each volumetric flow meter, you shall calculate quarterly the mass of CO2 in a CO2 stream in metric tons by multiplying the volumetric flow by the concentration and density data, according to Equation PP-2 of this section. Volumetric flow, concentration and density data measurements shall be made in accordance with § 98.424 of this section.

(3) To aggregate data, use either Equation PP-3a or PP-3b in this paragraph, as appropriate.

(i) For facilities with production process units, DAC process units, or production wells that capture or extract a CO2 stream and either measure it after segregation or do not segregate the flow, calculate the total CO2 supplied in accordance with equation PP-3a to paragraph (a)(3)(i) of this section.

(ii) For facilities with production process units or DAC process units that capture a CO2 stream and measure it ahead of segregation, calculate the total CO2 supplied in accordance with equation PP-3b to paragraph (a)(3)(ii) of this section.

(b) As an alternative to paragraphs (a)(1) through (3) of this section for CO2 that is supplied in containers, calculate the annual mass of CO2 supplied in containers delivered by each CO2 stream in accordance with the procedures specified in either paragraph (b)(1) or (b)(2) of this section. If multiple CO2 streams are used to deliver CO2 to containers, you shall calculate the annual mass of CO2 supplied in containers delivered by all CO2 streams according to the procedures specified in paragraph (b)(3) of this section.

(1) For each CO2 stream that delivers CO2 to containers, for which mass is measured, you shall calculate CO2 supply in containers using Equation PP-1 of this section.

(2) For each CO2 stream that delivers to containers, for which volume is measured, you shall calculate CO2 supply in containers using Equation PP-2 of this section.

(3) To aggregate data, sum the mass of CO2 supplied in containers delivered by all CO2 streams in accordance with Equation PP-3a of this section.

(c) Importers or exporters that import or export CO2 in containers shall calculate the total mass of CO2 imported or exported in metric tons based on summing the mass in each CO2 container using weigh bills, scales, or load cells according to Equation PP-4 of this section.

(a) Determination of quantity. (1) Reporters following the procedures in § 98.423(a) shall determine quantity using a flow meter or meters located in accordance with this paragraph.

(i) If the CO2 stream is segregated such that only a portion is captured for commercial application or for injection, you must locate the flow meter according to the following:

(A) For reporters following the procedures in § 98.423(a)(3)(i), you must locate the flow meter(s) after the point of segregation.

(B) For reporters following the procedures in paragraph (a)(3)(ii) of § 98.423, you must locate the main flow meter(s) on the captured CO2 stream(s) prior to the point of segregation and the subsequent flow meter(s) on the CO2 stream(s) for on-site use after the point of segregation. You may only follow the procedures in paragraph (a)(3)(ii) of § 98.423 if the CO2 stream(s) for on-site use is/are the only diversion(s) from the main, captured CO2 stream(s) after the main flow meter location(s).

(ii) Reporters that have a mass flow meter or volumetric flow meter installed to measure the flow of a CO2 stream that meets the requirements of paragraph (a)(1)(i) of this section shall base calculations in § 98.423 of this subpart on the installed mass flow or volumetric flow meters.

(iii) Reporters that do not have a mass flow meter or volumetric flow meter installed to measure the flow of the CO2 stream that meets the requirements of paragraph (a)(1)(i) of this section shall base calculations in § 98.423 of this subpart on the flow of gas transferred off site using a mass flow meter or a volumetric flow meter located at the point of off-site transfer.

(2) Reporters following the procedures in paragraph (b) of § 98.423 shall determine quantity in accordance with this paragraph.

(i) Reporters that supply CO2 in containers using weigh bills, scales, or load cells shall measure the mass of contents of each CO2 container to which the CO2 stream is delivered, sum the mass of contents supplied in all containers to which the CO2 stream is delivered during each quarter, sample the CO2 stream delivering CO2 to containers on a quarterly basis to determine the composition of the CO2 stream, and apply Equation PP-1.

(ii) Reporters that supply CO2 in containers using loaded container volumes shall measure the volume of contents of each CO2 container to which the CO2 stream is delivered, sum the volume of contents supplied in all containers to which the CO2 stream is delivered during each quarter, sample the CO2 stream on a quarterly basis to determine the composition of the CO2 stream, determine the density quarterly, and apply Equation PP-2.

(3) Importers or exporters that import or export CO2 in containers shall measure the mass in each CO2 container using weigh bills, scales, or load cells and sum the mass in all containers imported or exported during the reporting year.

(4) All flow meters, scales, and load cells used to measure quantities that are reported in § 98.423 of this subpart shall be operated and calibrated according to the following procedure:

(i) You shall use an appropriate standard method published by a consensus-based standards organization if such a method exists. Consensus-based standards organizations include, but are not limited to, the following: ASTM International, the American National Standards Institute (ANSI), the American Gas Association (AGA), the American Society of Mechanical Engineers (ASME), the American Petroleum Institute (API), and the North American Energy Standards Board (NAESB).

(ii) Where no appropriate standard method developed by a consensus-based standards organization exists, you shall follow industry standard practices.

(iii) You must ensure that any flow meter calibrations performed are NIST traceable.

(5) Reporters using Equation PP-2 of this subpart and measuring CO2 concentration as weight % CO2 shall determine the density of the CO2 stream on a quarterly basis in order to calculate the mass of the CO2 stream according to one of the following procedures:

(i) You may use a method published by a consensus-based standards organization. Consensus-based standards organizations include, but are not limited to, the following: ASTM International (100 Barr Harbor Drive, P.O. Box CB700, West Conshohocken, Pennsylvania 19428-B2959, (800) 262-1373, http://www.astm.org), the American National Standards Institute (ANSI, 1819 L Street, NW., 6th floor, Washington, DC 20036, (202) 293-8020, http://www.ansi.org), the American Gas Association (AGA, 400 North Capitol Street, NW., 4th Floor, Washington, DC 20001, (202) 824-7000, http://www.aga.org), the American Society of Mechanical Engineers (ASME, Three Park Avenue, New York, NY 10016-5990, (800) 843-2763, http://www.asme.org), the American Petroleum Institute (API, 1220 L Street, NW., Washington, DC 20005-4070, (202) 682-8000, http://www.api.org), and the North American Energy Standards Board (NAESB, 801 Travis Street, Suite 1675, Houston, TX 77002, (713) 356-0060, http://www.api.org). The method(s) used shall be documented in the Monitoring Plan required under § 98.3(g)(5).

(ii) You may follow an industry standard method.

(b) Determination of concentration. (1) Reporters using Equation PP-1 or PP-2 of this subpart shall sample the CO2 stream on a quarterly basis to determine the composition of the CO2 stream.

(2) Methods to measure the composition of the CO2 stream must conform to applicable chemical analytical standards. Acceptable methods include, but are not limited to, the U.S. Food and Drug Administration food-grade specifications for CO2 (see 21 CFR 184.1240) and ASTM standard E1747-95 (Reapproved 2005) Standard Guide for Purity of Carbon Dioxide Used in Supercritical Fluid Applications (ASTM International, 100 Barr Harbor Drive, P.O. Box CB700, West Conshohocken, Pennsylvania 19428-B2959, (800) 262-1373, http://www.astm.org).

(c) You shall convert the density of the CO2 stream(s) and all measured volumes of carbon dioxide to the following standard industry temperature and pressure conditions: Standard cubic meters at a temperature of 60 degrees Fahrenheit and at an absolute pressure of 1 atmosphere. If you apply the density value for CO2 at standard conditions, you must use 0.001868 metric tons per standard cubic meter.

(a) Whenever the quality assurance procedures in § 98.424(a)(1) of this subpart cannot be followed to measure quarterly mass flow or volumetric flow of CO2, the most appropriate of the following missing data procedures shall be followed:

(1) A quarterly CO2 mass flow or volumetric flow value that is missing may be substituted with a quarterly value measured during another quarter of the current reporting year.

(2) A quarterly CO2 mass flow or volumetric flow value that is missing may be substituted with a quarterly value measured during the same quarter from the past reporting year.

(3) If a mass or volumetric flow meter is installed to measure the CO2 stream, you may substitute data from a mass or volumetric flow meter measuring the CO2 stream transferred for any period during which the installed meter is inoperable.

(4) The mass or volumetric flow used for purposes of product tracking and billing according to the reporter's established procedures may be substituted for any period during which measurement equipment is inoperable.

(b) Whenever the quality assurance procedures in § 98.424(b) cannot be followed to determine concentration of the CO2 stream, the most appropriate of the following missing data procedures shall be followed:

(1) A quarterly concentration value that is missing may be substituted with a quarterly value measured during another quarter of the current reporting year.

(2) A quarterly concentration value that is missing may be substituted with a quarterly value measured during the same quarter from the previous reporting year.

(3) The concentration used for purposes of product tracking and billing according to the reporter's established procedures may be substituted for any quarterly value.

(c) Missing data on density of the CO2 stream shall be substituted with quarterly or annual average values from the previous calendar year.

(d) Whenever the quality assurance procedures in § 98.424(a)(2) of this subpart cannot be followed to measure quarterly quantity of CO2 in containers, the most appropriate of the following missing data procedures shall be followed:

(1) A quarterly quantity of CO2 in containers that is missing may be substituted with a quarterly value measured during another representative quarter of the current reporting year.

(2) A quarterly quantity of CO2 in containers that is missing may be substituted with a quarterly value measured during the same quarter from the past reporting year.

(3) The quarterly quantity of CO2 in containers recorded for purposes of product tracking and billing according to the reporter's established procedures may be substituted for any period during which measurement equipment is inoperable.

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) Geologic sequestration of carbon dioxide with enhanced oil recovery that is covered by subpart VV of this part.

(13) Research and development.

(14) 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 a facility that is subject to this part and transfer CO2 to any facilities that are subject to subpart RR or VV of this part, you must:

(1) Report the facility identification number associated with the annual GHG report for the facility that is the source of the captured CO2 stream;

(2) Report each facility identification number associated with the annual GHG reports for each subpart RR and subpart VV facility to which CO2 is transferred; and

(3) Report the annual quantity of CO2 in metric tons that is transferred to each subpart RR and subpart VV facility.

(i) If you capture a CO2 stream at a facility with a DAC process unit, report the annual quantity of on-site and off-site electricity and heat generated for each DAC process unit as specified in paragraphs (i)(1) through (3) of this section. The quantities specified in paragraphs (i)(1) through (3) of this section must be provided per energy source if known and must represent the electricity and heat used for the DAC process unit starting with air intake and ending with the compressed CO2 stream (i.e., the CO2 stream ready for supply for commercial applications or, if maintaining custody of the stream, sequestration or injection of the stream underground).

(1) Electricity excluding combined heat and power (CHP). If electricity is provided to a dedicated meter for the DAC process unit, report the annual quantity of electricity consumed, in megawatt hours (MWh), and the information in paragraph (i)(1)(i) or (ii) of this section.

(i) If the electricity is sourced from a grid connection, report the following information:

(A) State where the facility with the DAC process unit is located.

(B) County where the facility with the DAC process unit is located.

(C) Name of the electric utility company that supplied the electricity as shown on the last monthly bill issued by the utility company during the reporting period.

(D) Name of the electric utility company that delivered the electricity. In states with regulated electric utility markets, this will generally be the same utility reported under paragraph (i)(1)(i)(C) of this section, but in states with deregulated electric utility markets, this may be a different utility company.

(E) Annual quantity of electricity consumed in MWh, calculated as the sum of the total energy usage values specified in all billing statements received during the reporting year. Most customers will receive 12 monthly billing statements during the reporting year. Many utilities bill their customers per kilowatt-hour (kWh); usage values on bills that are based on kWh should be divided by 1,000 to report the usage in MWh as required under this paragraph (i)(1)(i)(E).

(ii) If electricity is sourced from on-site or through a contractual mechanism for dedicated off-site generation, for each applicable energy source specified in paragraphs (i)(1)(ii)(A) through (G) of this section, report the annual quantity of electricity consumed, in MWh. If the on-site electricity source is natural gas, oil, or coal, also indicate whether flue gas is also captured by the DAC process unit.

(A) Non-hydropower renewable sources including solar, wind, geothermal and tidal.

(B) Hydropower.

(C) Natural gas.

(D) Oil.

(E) Coal.

(F) Nuclear.

(G) Other.

(2) Heat excluding CHP. For each applicable energy source specified in paragraphs (i)(2)(i) through (vii) of this section, report the annual quantity of heat, steam, or other forms of thermal energy sourced from on-site or through a contractual mechanism for dedicated off-site generation, in megajoules (MJ). If the on-site heat source is natural gas, oil, or coal, also indicate whether flue gas is also captured by the DAC process unit.

(i) Solar.

(ii) Geothermal.

(iii) Natural gas.

(iv) Oil.

(v) Coal.

(vi) Nuclear.

(vii) Other.

(3) CHP—(i) Electricity from CHP. If electricity from CHP is sourced from on-site or through a contractual mechanism for dedicated off-site generation, for each applicable energy source specified in paragraphs (i)(3)(i)(A) through (G) of this section, report the annual quantity consumed, in MWh. If the on-site electricity source for CHP is natural gas, oil, or coal, also indicate whether flue gas is also captured by the DAC process unit.

(A) Non-hydropower renewable sources including solar, wind, geothermal and tidal.

(B) Hydropower.

(C) Natural gas.

(D) Oil.

(E) Coal.

(F) Nuclear.

(G) Other.

(ii) Heat from CHP. For each applicable energy source specified in paragraphs (i)(3)(ii)(A) through (G) of this section, report the quantity of heat, steam, or other forms of thermal energy from CHP sourced from on-site or through a contractual mechanism for dedicated off-site generation, in MJ. If the on-site heat source is natural gas, oil, or coal, also indicate whether flue gas is also captured by the DAC process unit.

(A) Solar.

(B) Geothermal.

(C) Natural gas.

(D) Oil.

(E) Coal.

(F) Nuclear.

(G) Other.

In addition to the records required by § 98.3(g) of subpart A of this part, you must retain the records specified in paragraphs (a) through (c) of this section, as applicable.

(a) The owner or operator of a facility containing production process units or DAC process units must retain quarterly records of captured or transferred CO2 streams and composition.

(b) The owner or operator of a CO2 production well facility must maintain quarterly records of the mass flow or volumetric flow of the extracted or transferred CO2 stream and concentration and density if volumetric flow meters are used.

(c) Importers or exporters of CO2 must retain annual records of the mass flow, volumetric flow, and mass of CO2 imported or exported.

(d) Facilities subject to § 98.426(h) must retain records of CO2 in metric tons that is transferred to each subpart RR facility.

All terms used in this subpart have the same meaning given in the Clean Air Act and subpart A of this part.