340-215-0105 Requirements for Stationary Sources and Electric Power System Facilities Regulated entities required to register and report to DEQ under OAR 340-215-0030(2) must: (1) Unless otherwise specified in this rule, calculate and report all GHG emissions for which there are quantification methodologies described in 40 C.F.R. part 98 subparts C through UU or in this division, using methodologies described in such rules. Such reports must include all data and information described in such rules. This division, however, describes the reporting applicability requirements and the applicability provisions of 40 C.F.R. part 98 subparts C through UU shall not be used. Such reports may exclude emissions from categorically insignificant activities. If categorically insignificant activities cannot be separated from other activities, entities may report aggregate emissions that include categorically insignificant activities. In addition: (a) Regulated entities that are in-state producers may exclude data and information described in 40 C.F.R. part 98 subpart MM and NN from an individual emissions data report described in OAR 340-215-0044(1)(a) but must comply with OAR 340-215-0110 and OAR 340-215-0115, as applicable; and (b) Regulated entities that are carbon dioxide suppliers must report data and information described in 40 C.F.R. part 98 subpart PP; (2) As applicable, separately report fuel types, quantities, and emissions from fuel combustion reported utilizing 40 C.F.R. part 98, subpart H - Cement Production, subpart W - Petroleum and Natural Gas Systems, and subpart AA - Pulp and Paper Manufacturing quantification methodology; (3) Provide supplemental documentation, including data inputs for equations to describe how emissions are calculated. Data inputs include but are not limited to fuel throughput, emission factors, and production volumes or product usage used to calculate emissions; (4) For stationary sources and electric power system facilities that include electricity generating units, cogeneration units, or both that meet the applicability requirements of section OAR 340-215-0030(2), follow the requirements of subparts C and D of 40 C.F.R. part 98, as applicable, in reporting emissions and other data from electricity generating and cogeneration. In addition, such regulated entities must report the following information: (a) Information for each facility as defined in 40 C.F.R. 98.6, including separately for each facility under the same air quality permit: name, address, and contact person and phone number; (b) If applicable, report facility identification numbers assigned by the U.S. Energy Information Administration, California Air Resources Board and Federal Energy Regulatory Commission’s Public Utility Regulatory Policies Act of 1978 (“PURPA”) Qualifying Facility program; (c) Report net and gross electricity generated in megawatt-hours; and (d) Regulated entities that own or operate a cogeneration unit must report the thermal energy in MMBtu generated by a combustion source that is used directly as part of a manufacturing, industrial or commercial process, or as part of as heating or cooling application, separately for the following categories: generated thermal energy provided to end users outside the stationary source facility boundary and generated thermal energy for on-site industrial applications not related to electricity generation; (5) An investor-owned utility that owns or operates electric power system facilities as defined in 40 C.F.R. part 98 subpart DD in Oregon must report emissions utilizing calculation methodologies in 40 C.F.R. part 98 subpart DD and must submit an emissions data report including all emissions from electric transmission and distribution equipment and servicing inventory physically located in Oregon for the previous year; (6) For in-state producers of goods containing fluorinated greenhouse gases in pre-charged equipment or closed-cell foams, report the mass of each fluorinated greenhouse gas in all goods produced in a year and comply with 40 C.F.R. part 98 subpart QQ in reporting emissions to DEQ as modified below: (a) Report total mass in metric tons of each fluorinated greenhouse gas contained within pre-charged equipment or closed cell foams; (b) For each type of pre-charged equipment with a unique combination of charge size and charge type, report the identity of the fluorinated greenhouse gas used as a refrigerant or electrical insulator, charge size, holding charge, where applicable and number produced; (c) For closed–cell foams the identity of the fluorinated greenhouse gas in the foam, the density of the fluorinated GHG in the foam (kilograms of fluorinated greenhouse gas per cubic feet), and the volume of foam produced (tons) for each type of closed–cell foam with a unique combination of F-GHG density and identity; (d) Calculate greenhouse gas emissions from foam blowing operations using the following equation. When the blowing agent is a blend of gases, emissions must be calculated separately for each constituent of the blowing agent used during the foam manufacturing process: FCO2e = ∑ {[(TFP × (ATi + ASi) × BAFi) + (FP × BAFi × MFLi )] × GWPi} × 0.907185 For the purposes of the calculation in this subsection (d), the following definitions apply: “FCO2e” means annual total mass of fluorinated greenhouse gas emissions of carbon dioxide equivalent (metric tons); “TFP” means total amount of foam produced (tons); “ATi” means average percent blowing agent, i, in trim (tons); “ASi” means average percent blowing agent, i, in scrap (tons); “BAFi” means percent of blowing agent, i, constituent in foam (tons); “FP” means finished product (tons); “MFLi” means mass fraction loss from off gassing curve for blowing agent, i, approved by DEQ (tons/year); “GWPi” means global warming potential for each constituent of the blowing agent found in table A-1 of 40 C.F.R. part 98; and “0.907185” is applied to convert tons to metric tons; and (e) Regulated entities that use fluorinated gasses described in table A-1 of 40 C.F.R. part 98 as blowing agents in foam blowing operations may request DEQ approval of alternate emissions calculation methods for this operation, process, or activity as described in OAR 340-215-0040(4). Regulated entities must receive written DEQ approval to use the petitioned emissions calculation methods prior to reporting; (7) Calculate and report emissions of biogenic CO2 that originate from biomass-derived fuels separately from other greenhouse gas emissions. Report and retain information described in OAR 340-215-0042(4) and OAR 340-215-0044(5), as applicable, and use the following procedures when calculating emissions from biomass-derived fuels that are intermixed with fossil fuels: (a) When calculating emissions from the combustion of municipal solid waste (MSW) or any other fuel for which the biomass fraction is not known, follow the procedures specified in 40 C.F.R. 98.33(e)(3) to specify a biomass fraction; (b) When calculating emissions from a biomass-derived gas, reported using book and claim accounting, and natural gas mixture calculate emissions based on contractual deliveries of the biomass-derived gas, with the remainder of emissions being from natural gas, calculated according to the applicable methodology in 40 C.F.R. part 98; and (c) When calculating emissions from a biogas and natural gas mixture using 40 C.F.R. 98.33(a)(4) or the carbon content method described in 40 C.F.R. 98.33(a)(3) or when calculating those emissions according to subpart D of 40 C.F.R. part 98, calculate biogas emissions using a carbon content method as described in 40 C.F.R. 98.33(a)(3), with the remainder of emissions being from natural gas; (8) When reporting hydrogen using book and claim accounting, report the energy, volume, and the total emissions that would have resulted from the full combustion or oxidation of the displaced gaseous fuel using the following procedures: (a) When reporting hydrogen that displaces a gaseous fuel that is combusted, calculate and report the equivalent energy and volume of the gaseous fuel. Report the emissions that would have resulted from the full combustion of that fuel using applicable methodology in 40 C.F.R. part 98; and (b) When reporting hydrogen that displaces a gaseous fuel or feedstock that is used in a non-combustion process, calculate and report the amount of fuel or feedstock that is displaced by the reported amount of hydrogen. A stationary source must receive prior written DEQ approval to use its calculation methods to determine the amount of displaced fuel or feedstock it reports. Report the emissions that would have resulted from the non-combustion use of the fuel that was displaced using applicable methodology in 40 C.F.R. part 98. (9) When reporting emissions from the combustion of natural gas, report the name(s) of the supplier(s) of natural gas to the facility, including information identifying the seller of natural gas, natural gas customer account, and the annual MMBtu delivered to each account according to billing statements (10 therms = 1 MMBtu); and (10) Report the air permit numbers and NAICS codes according to 40 C.F.R. 98.3(c)(10). Statutory/Other Authority: ORS 468A.050 Statutes/Other Implemented: ORS 468 & 468A History: DEQ 17-2023, amend filed 11/16/2023, effective 11/16/2023 DEQ 14-2020, adopt filed 05/07/2020, effective 05/07/2020