Emissions by plant and by region

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utility emissions

(2) For each affected unit in the long-term coal-fired steam generating subcategory, by January 1, 2032. The owner or operator of an affected EGU must demonstrate that they have commenced permitting actions by a date specified in the State plan. The owner or operator of an affected EGU can demonstrate compliance with this increment of progress by submitting sufficient evidence that the appropriate contracts have been awarded. (3) For the purposes of 40 CFR 70.2, with respect to greenhouse gas emissions from facilities regulated in the State plan, the “pollutant that is subject to any standard promulgated under section 111 of the Act” shall be considered to be the pollutant that otherwise is “subject to regulation” as defined in 40 CFR 70.2. An affected steam generating unit shall, for the purposes of this subpart, be referred to as an affected EGU. This subpart establishes emission guidelines and approval criteria for State plans that establish standards of performance limiting greenhouse gas (GHG) emissions from an affected steam generating unit.

(iii) Presumptively approvable standard of performance is an emission rate limit defined by an 88.4 percent reduction in annual emission rate (lb CO2/MWh-gross) from the unit-specific baseline. (4) An affected EGU’s standard of performance is permanent if the standard of performance must be met continuously unless it is replaced by another standard of performance in an approved State plan revision. (3) An affected EGU’s standard of performance is non-duplicative with respect to https://callmeconstruction.com/news/understanding-how-technology-is-affecting-modern-buildings/ a State plan if it is not already incorporated as an standard of performance in the State plan. (2) An affected EGU’s standard of performance is verifiable if adequate monitoring, recordkeeping and reporting requirements are in place to enable the State and the Administrator to independently evaluate, measure, and verify compliance with the standard of performance. (1) An affected EGU’s standard of performance is quantifiable if it can be reliably measured in a manner that can be replicated. (a) For each affected EGU, your State plan must include the standard of performance that applies for the affected EGU.

  • (j) EGUs that derive greater than 50 percent of the heat input from an industrial process that does not produce any electrical or mechanical output or useful thermal output that is used outside the affected EGU.
  • (2) The report must include, for each affected EGU, a comparison of the CO2 standard of performance in the State plan versus the actual CO2 emission performance achieved.
  • (3) The owner or operator must submit a final report to the EPA no later than 6 months following its committed closure date.
  • (a) If you are the owner or operator of an EGU that has committed to permanently cease operations by January 1, 2032, you must maintain records for and submit the reports listed in paragraphs (a)(1) through (3) of this section according to the electronic reporting requirements in paragraph (b) of this section.

In June 2025, EPA Administrator Lee Zeldin proposed a repeal of all greenhouse gas emissions standards for the power sector. These include plans for renewable energy power purchase agreements, but also on-site resiliency projects such as microgrids, combined heat and power, rooftop solar, energy storage, digitalization and building efficiency upgrades. The C&I sectors together account for close to 30 percent of greenhouse https://shipsbusiness.com/energy-efficiency-measures-ballast-water-management.html gas emissions in the U.S.

Subpart UUUUb—Emission Guidelines for Greenhouse Gas Emissions for Electric Utility Generating Units

If your company is required to report greenhouse gas emissions or chooses to analyze its carbon footprint, you may need information about natural gas delivered by Wisconsin Public Service. The emission rates apply to retail electric utility customers of WPS, except for customers of NatureWise, the WPS renewable energy program that is offered to all retail electric customers. The emission rates are supplied for customers to estimate their environmental footprint from electric energy supplied by WPS, such as Scope 2 (indirect) greenhouse gas emissions. The EPRI program manager said the bulk of emissions reductions to take place in the power sector were likely to happen even in the absence of utility emissions targets.

(5) A demonstration of how the application of the aggregate rate-based standard of performance will achieve equivalent or better emission reduction as would be achieved through the application of a rate-based standard of performance (lb CO2/MWh-gross) that would apply pursuant to paragraph (a)(1) of this section, and as determined in accordance with paragraphs (c) and (d) of this section. (3) The process for calculating the aggregate gross generation weighted average emission rate (lb CO2/MWh-gross) at the end of each compliance period, based on the reported emissions (lb CO2) and utilization (MWh-gross) of each of the affected EGUs that form the group. (2) Documentation of any assumptions underlying the calculation of the aggregate rate-based standard of performance (lb CO2/MWh-gross). (1) The presumptively approvable rate-based standard of performance (lb CO2/MWh-gross) that would apply under paragraph (a)(1) of this section, and as determined in accordance with paragraphs (c) and (d) of this section, to each of the affected EGUs that form the group. (2) A mass-based standard of performance in the form of an annual limit on allowable mass CO2 emissions for an individual affected EGU, provided the standard of performance meets the requirements of paragraph (g) of this section.

utility emissions

Brazil’s utility energy efficiency programs reduced electricity use by 9.2 terawatt-hours in 2023, supporting its goal of 20% renewable energy by 2030 South Korea’s utility sector reduced emissions by 12% from 2018 to 2023, supported by a 30% renewable energy target Brazilian utility emissions fell by 19% from 2004 to 2023, due to increased wind and solar capacity The IPCC’s AR6 report states that limiting utility emissions to 2.5 gigatons annually by 2030 requires a 45% reduction from 2010 levels France’s utility sector emitted 42 million metric tons of CO2 in 2023, down 35% from 1990 Australian utility emissions fell by 28% from 2000 to 2023, driven by replacing coal with wind and solar

  • Emission factors contained in Table 4.2 must be used for the quantification of GHG reductions occurring in calendar year 2025.
  • This report must explain the cause or causes of the deviation and describe all measures taken or to be taken by the owner or operator of the EGU to cure the reported deviation and to prevent such deviations in the future, including the timeframes in which the owner or operator intends to cure the deviation.
  • (2) Any permit(s) obtained for the installation of the identified controls or, where a required permit has not yet been issued, a copy of the permit application submitted to the permitting authority and a statement from the permit authority identifying its anticipated timeframe for issuance of such permit(s).
  • Heat recovery steam generating unit (HRSG) means a unit in which hot exhaust gases from the combustion turbine engine are routed in order to extract heat from the gases and generate useful output.
  • Emission factors contained in Table 3.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024.

Reported Greenhouse Gas Emissions

Heat recovery steam generating unit (HRSG) means a unit in which hot exhaust gases from the combustion turbine engine are routed in order to extract heat from the gases and generate useful output. (1) For stationary combustion turbines and IGCC, the gross electric or direct mechanical output from both the EGU (including, but not limited to, output from steam turbine(s), combustion turbine(s), and gas expander(s)) plus 100 percent of the useful thermal output. Compliance period means an annual (calendar year) period for an affected EGU to comply with a standard of performance. Combined heat and power unit or CHP unit, (also known as “cogeneration”) means an electric generating unit that uses a steam-generating unit or stationary combustion turbine to simultaneously produce both electric (or mechanical) and useful thermal output from the same primary energy source.

Electric power plant environmental

Gas-fired generation, which has dominated the overall U.S. electricity resource mix in the past decade, actually dropped by 4%, eliminating about 23 million metric tons. Coal-fired electricity generation increased 13% and raised its portion of CO2 emissions by 78 million metric tons, according to the EIA. U.S. greenhouse gas emissions, least in CO2 terms, have gradually declined over the past two decades.

utility emissions

Generation and thermal output

utility emissions

Overall, the U.S. total CO2 emissions were 4.9 billion metric tons in 2025, 2% higher than the 4.789 billion metric tons ignited into the American sky one year earlier, the EIA data shows. Electric power accounted for the largest increase in emissions of 58 million metric tons to 1.485 billion metric tons last year; that’s a 4% rise. Total U.S. C02 emissions from all economic and population sectors is nearly 5 billion metric tons produced in 2025, but that’s about 17% lower than the 6 billion metric tons calculated around 2007, according to the EIA. U.S. greenhouse gas emissions have decreased over two decades, but recent Energy Information Administration data shows a 2% rise in 2025, with electricity sector growth and coal dependency playing significant roles.

Emissions & Generation Resource Integrated Database eGRID US EPA

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utility emissions

When you enter energy data, the calculator converts these values into carbon dioxide-equivalent greenhouse gas emissions based on emission factors for energy consumption or electricity reductions. This calculator may be useful in communicating your greenhouse gas reduction strategy, reduction targets, or other initiatives aimed at reducing greenhouse gas emissions. The EU’s renewable energy target for 2030 (32%) was exceeded in 2023, with renewables contributing 42% of electricity 60% of EU utilities have integrated renewable energy into their grids, enabling a 25% increase in renewable penetration

(1) An aggregate rate-based standard of performance (lb CO2/MWh-gross) that applies for a group of affected EGUs that share the same owner or operator, as calculated on a gross generation weighted average basis, provided the standard of performance meets the requirements of paragraph (f) of this section. (A) All documentation required as part of this extension must be submitted by the owner or operator of the affected EGU to the State air pollution control agency no later than 6 months prior to the applicable compliance date for that affected EGU. This report must explain the cause or causes of the deviation and describe all measures taken or to be taken by the owner or operator of the EGU to cure the reported deviation and to prevent such deviations in the future, including the timeframes in which the owner or operator intends to cure the deviation. You must include in your State plan legally enforceable increments of progress as required elements for affected EGUs in the long-term coal-fired steam generating unit and medium-term coal-fired steam generating unit subcategories.

  • (1) The net electric or mechanical output from the affected facility, plus 100 percent of the useful thermal output measured relative to standard ambient temperature and pressure conditions that is not used to generate additional electric or mechanical output or to enhance the performance of the unit (e.g., steam delivered to an industrial process for a heating application).
  • Emission factors contained in Table 3.2 must be used for the quantification of GHG reductions occurring in calendar year 2025.
  • Thus, a million metric tons are roughly the same mass as 1 million small cars.
  • (1) An affected EGU’s standard of performance is quantifiable if it can be reliably measured in a manner that can be replicated.
  • (1) The presumptively approvable rate-based standard of performance (lb CO2/MWh-gross) that would apply to the affected EGU under paragraph (a)(1) of this section, and as determined in accordance with paragraphs (c) and (d) of this section.

Purchasing renewable energy is a common approach to addressing Scope 2 emissions. According to Xylem estimates, Scope 1 emissions account for 25% of water utility emissions. Reducing greenhouse gas emissions presents a rare opportunity to rethink what is possible through technology and data-driven decision-making.

  • Emission factors contained in Table 6.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024.
  • (iii) Presumptively approvable standard of performance is an annual emission rate limit of 1,600 lb CO2/MWh-gross.
  • If your company is required to report greenhouse gas emissions or chooses to analyze its carbon footprint, you may need information about natural gas delivered by Wisconsin Electric Gas Operations or Wisconsin Gas LLC.
  • (4) A demonstration of how the application of the mass CO2 limit for the affected EGU will achieve equivalent or better emission reduction as would be achieved through the application of a rate-based standard of performance (lb CO2/MWh-gross) that would apply pursuant to paragraph (a)(1) of this section, and as determined in accordance with paragraphs (c) and (d) of this section.
  • (iii) The State plan must provide that an existing coal-fired steam generating EGU operating past the date listed in the State plan pursuant to paragraph (a)(9)(ii) of this section is in violation of that State plan, except to the extent the existing coal-fired steam generating EGU has received an extension of its date for ceasing operation pursuant to the reliability assurance mechanism, described in paragraph (a)(13) of this section.

Reducing Emissions from Electric Power Production

utility emissions

An owner or operator must also include in the report the affected EGU’s calculated emission performance as a CO2 emission rate in units of the standard of performance. (c) Your State plan must require the owner or operator of an affected EGU covered by your State plan to include in a report submitted to you the information in paragraphs (c)(1) through (3) of this section. (ii) If there is no net electrical output, but there is mechanical or useful thermal output, either for a particular valid operating hour (for rate-based applications), or for a particular operating hour (for mass-based applications), the owner or operator of the affected EGU must still determine the net energy output for that hour. Further, the owner or operator of an affected EGU that is a combined heat and power facility must install, calibrate, maintain, and operate equipment to continuously measure and record on an hourly basis useful thermal output and, if applicable, mechanical output, which are used with gross electric output to determine gross energy output.

Learn more about how Oregon tracks greenhouse gas emissions at DEQ’s greenhouse gas inventory page. This data does not represent all of Oregon’s greenhouse gas emissions. These groups submit annual reports on their greenhouse gas emissions to DEQ.

Greenhouse Gas Emissions by Electricity End-Use

(2) For affected units in the medium-term coal-fired steam generating unit subcategory, this increment of progress applies to each affected EGU that adopts natural gas co-firing to meet the standard of performance and ensures timely completion of any pipeline infrastructure needed to transport natural gas to designated facilities. (1) For affected units in the long-term coal-fired steam generating unit subcategory, this increment of progress applies to each affected EGU that adopts CCS to meet the standard of performance and ensure timely completion of CCS-related pipeline infrastructure. (2) For steam generating units, the gross electric or mechanical output from the affected EGU(s) (including, but not limited to, output from steam turbine(s), combustion turbine(s), and gas expander(s)) minus any electricity used to power the feedwater pumps plus 100 percent of the useful thermal output; (c) Modified coal-fired steam generating units that are subject to subpart TTTTa of this part as a result of commencing modification after the subpart TTTTa applicability date;

utility emissions

Carbon dioxide emissions from the United States’ electric power sector rose by 4%, or 58 million metric tons, in 2025, due to growth in electricity generation and coal use, the U.S. If your company is required to report greenhouse gas emissions or chooses to analyze its carbon footprint, you may need information about natural gas delivered by Wisconsin Electric Gas Operations or Wisconsin Gas LLC. The emission rates apply to retail electric utility customers of We Energies, except for customers of Energy for Tomorrow, the We Energies Green-e certified renewable energy program that is offered to all retail electric customers. The emission rates are supplied for customers to estimate their environmental footprint from electric energy supplied by We Energies, such as Scope 2 (indirect) greenhouse gas emissions. Brickhouse said that while renewables make up 30% of Basin’s generation portfolio, meeting data center demand with renewable energy generation backed up by diesel is not ideal due to the “very high load factor” of data centers.

Generation and thermal output

utility emissions

(iv) Intermediate load oil-fired steam generating units, consisting of oil-fired steam generating units with an annual capacity factor greater than or equal to 8 percent and less than 45 percent. (iii) Base load oil-fired steam generating units, consisting of oil-fired steam generating units with an annual capacity factor greater than or equal to 45 percent. (ii) Medium-term coal-fired steam generating units, consisting of coal-fired steam generating units that have elected to commit to permanently cease operations by a date after December 31, 2031, and before January 1, 2039. (i) Long-term coal-fired steam generating units, consisting of coal-fired steam generating units that are not medium-term coal-fired steam generating units and do not plan to permanently cease operation before January 1, 2039. (1) Five years before any planned date to permanently cease operations or by the date upon which the State plan is submitted, whichever is later, the owner or operator of the EGU must submit an initial report to the EPA that includes the information in paragraphs (a)(1)(i) and (ii) of this section. (b) All State plan submittals, supporting materials that are part of a State plan submittal, any State plan revisions, and all State reports required to be submitted to the EPA by the State plan must be reported through the EPA’s State Plan Electronic Collection System (SPeCS).

Reported Greenhouse Gas Emissions

utility emissions

(1) The net electric or mechanical output from the affected facility, plus 100 percent of the useful thermal output measured relative to standard ambient temperature and pressure conditions that is not used to generate additional electric or mechanical output or to enhance the performance of the unit (e.g., steam delivered to an industrial process for a heating application). https://bandlybands.com/narkes-elektriska/ Mechanical output means the useful mechanical energy that is not used to operate the affected facility, generate electricity and/or thermal output, or to enhance the performance of the affected facility. Integrated gasification combined cycle facility or IGCC means a combined cycle facility that is designed to burn fuels containing 50 percent (by heat input) or more solid-derived fuel not meeting the definition of natural gas plus any integrated equipment that provides electricity or useful thermal output to either the affected facility or auxiliary equipment.

  • (iv) A requirement to document the hours an affected EGU operated under a system emergency and the enforceable emission limitation, whether the applicable standard of performance or the alternative emission limitation, under which that affected EGU operated during those hours.
  • But what the report mainly seems to demonstrate, he said, is that the bulk of emissions reductions to take place in the electric sector were likely to happen even in the absence of utility emissions targets.
  • (3) For the purposes of 40 CFR 70.2, with respect to greenhouse gas emissions from facilities regulated in the State plan, the “pollutant that is subject to any standard promulgated under section 111 of the Act” shall be considered to be the pollutant that otherwise is “subject to regulation” as defined in 40 CFR 70.2.
  • (iii) Base load oil-fired steam generating units, consisting of oil-fired steam generating units with an annual capacity factor greater than or equal to 45 percent.
  • The owner or operator of an affected EGU must demonstrate that they have commenced permitting actions by a date specified in the State plan.

(1) The report must include the emissions performance achieved by each affected EGU during the reporting period and identification of whether each affected EGU is in compliance with its standard of performance during the compliance period, as specified in the State plan. For each calendar year reporting period the report must be submitted by March 1 of the following year. (3) For each affected EGU the report must also include the applicable standard of performance and demonstration that it met the standard of performance.

Electric utility energy mix and emission rates

This page provides a summary of Oregon’s mandatory greenhouse gas reported data. For further discussion of GWPs and an estimate of greenhouse gas emissions using updated GWPs, see Annex 6 of the https://labverra.com/authors/dr.-neelesh-rao/ U.S. Thus, a million metric tons are roughly the same mass as 1 million small cars. A million metric tons equals about 2.2 billion pounds, or 1 trillion grams. Looking at greenhouse gas emissions by end-use sector can help us understand energy demand across sectors and changes in energy use over time.

Utility-Specific Emission Factors

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utility emissions

(A) For an extension of 6 months or less, the owner or operator of the eligible EGU requesting the extension must submit the information in paragraph (a)(13)(vi) to the applicable EPA Regional Administrator to review and approve or disapprove the extension request. (iv) The State plan must provide that any applicable standard of performance for an affected EGU must remain in place during the duration of an extension provided under this mechanism. (iv) A requirement to document the hours an affected EGU operated under a system emergency and the enforceable emission limitation, whether the applicable standard of performance or the alternative emission limitation, under which that affected EGU operated during those hours. (B) The owner or operator of the affected EGU must notify the relevant EPA Regional Administrator of their compliance date extension request at the time of the submission of the request. (D) Identify the circumstances that are entirely beyond the owner or operator’s control and that necessitate additional time to install the identified controls. (2) Any permit(s) obtained for the installation of the identified controls or, where a required permit has not yet been issued, a copy of the permit application submitted to the permitting authority and a statement from the permit authority identifying its anticipated timeframe for issuance of such permit(s).

Emission factors contained in Table 5.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024. Emission factors contained in Table 4.3 must be used for the quantification of GHG reductions occurring in calendar year 2027. Emission factors contained in Table 4.3 must be used for the quantification of GHG reductions occurring in calendar year 2026. Emission factors contained in Table 4.2 must be used for the quantification of GHG reductions occurring in calendar year 2025. Emission factors contained in Table 4.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024.

The owner or operator must use the following procedures to calculate gross energy output, as appropriate for the type of affected EGU(s). (5) For rate-based standards, the owner or operator of an affected EGU (or group of affected units that share a monitored common stack) must install, calibrate, maintain, and operate a https://repairtoday7.com/xiaomi-14-ultra-the-ultimate-smartphone-for-photography-enthusiasts.html sufficient number of watt meters to continuously measure and record on an hourly basis gross electric output. (vi) The owner or operator of an affected EGU may determine site-specific carbon-based F-factors (Fc) using Equation F-7b in section 3.3.6 of appendix F to 40 CFR part 75 and may use these Fc values in the emissions calculations instead of using the default Fc values in the Equation G-4 nomenclature.

(j) EGUs that derive greater than 50 percent of the heat input from an industrial process that does not produce any electrical or mechanical output or useful thermal output that is used outside the affected EGU. EPA will review and, if appropriate, revise these emission guidelines as they apply to coal-fired steam generating affected EGUs by January 1, 2041. (2) The calculation of the mass CO2 budget contribution for each participating affected EGU, determined by multiplying the assumed utilization level (MWh-gross) of the affected EGU by its presumptively approvable rate-based standard of performance (lb CO2/MWh-gross), including the underlying data used for the calculation and documentation of any assumptions underlying this calculation.

Step 1 – Enter and convert data

(iii) Presumptively approvable standard of performance is an annual emission rate limit of 130 lb CO2/MMBtu. (iii) Presumptively approvable standard of performance is an annual emission rate limit of 170 lb CO2/MMBtu. (iii) Presumptively approvable standard of performance is an annual emission rate limit of 1,600 lb CO2/MWh-gross. (iii) Presumptively approvable standard of performance is an annual emission rate limit of 1,400 lb CO2/MWh-gross. (iii) Presumptively approvable standard of performance is an emission rate limit defined by a 16 percent reduction in annual emission rate (lb CO2/MWh-gross) from the unit-specific baseline.

utility emissions

But what the report mainly seems to demonstrate, he said, is that the bulk of emissions reductions to take place in the electric sector were likely to happen even in the absence of utility emissions targets. The report also did not include public power providers, and there’s still a fair number of U.S. utilities that haven’t set renewable energy goals, Young said. This emission factor is currently reported as “not estimated” in Canada’s National Inventory Report. Emission factors contained in Table 6.4 must be used for the quantification of GHG reductions occurring in calendar year 2027. Emission factors contained in Table 6.3 must be used for the quantification of GHG reductions occurring in calendar year 2026. Emission factors contained in Table 6.2 must be used for the quantification of GHG reductions occurring in calendar year 2025.

§ 60.5715b What is the review and approval process for my State plan?

Less than 1% of greenhouse gas emissions from the sector come from sulfur hexafluoride (SF6), an insulating chemical used in electricity transmission and distribution equipment. Carbon dioxide (CO2) makes up the vast majority of greenhouse gas emissions from the sector, but smaller amounts of methane (CH4) and nitrous oxide (N2O) are also emitted. Steam generating unit means any furnace, boiler, or other device used for combusting fuel and producing steam (nuclear steam generators are not included) plus any integrated equipment that provides electricity or useful thermal output to the affected facility or auxiliary equipment. A stationary combustion turbine that burns any solid fuel directly is considered a steam generating https://scriptmafia.org/tutorials/576944-iso-50001-energy-management-master-energy-management-system.html unit.

  • (4) Measures to implement and enforce the annual aggregate rate-based standard of performance, including the basis for determining owner or operator compliance with the aggregate standard of performance and provisions to address any changes to owners or operators in the course of implementation.
  • If your company is required to report greenhouse gas emissions or chooses to analyze its carbon footprint, you may need information about natural gas delivered by Wisconsin Public Service.
  • Simply put, there is not enough renewable energy for all industries to eliminate their Scope 2 emissions.
  • The emission rates apply to retail electric utility customers of WPS, except for customers of NatureWise, the WPS renewable energy program that is offered to all retail electric customers.
  • (vii) Intermediate load natural gas-fired steam generating units, consisting of natural gas-fired steam generating units with an annual capacity factor greater than or equal to 8 percent and less than 45 percent.
  • Emission factors contained in Table 1.3 must be used for the quantification of GHG reductions occurring in calendar year 2026.

utility emissions

(B) For steam generating units that meet the definition of https://uofa.ru/en/ob-utverzhdenii-instrukcii-po-tehnicheskoi-ekspluatacii-zdanii/ natural gas- or oil-fired, and that either retain the capability to fire coal after May 9, 2024, that fired any coal during the 5-year period prior to that date, or that will fire any coal after that date and before January 1, 2030, you must include a requirement to remove the capability to fire coal before January 1, 2030. German utility emissions fell to 340 million metric tons in 2023, the lowest level since 1970 U.S. utility renewable energy projects avoided 560 million metric tons of CO2 in 2023, equivalent to planting 15 billion trees Simply put, there is not enough renewable energy for all industries to eliminate their Scope 2 emissions.

(viii) The State plan must provide that extensions will only be granted for the period of time that is substantiated by the reliability need and the submitted analysis and documentation, and shall not exceed 12 months in total. For requests for extensions longer than 6 months, this application must be submitted to the EPA Regional Administrator no less than 45 days prior to the date for ceasing operation listed in the State plan, but no earlier than 12 months prior to that date. (vii) The State plan must require that to apply for an extension longer than 6 months but up to 12 months, described in paragraph (a)(13)(v)(B) of this section, the owner or operator of an eligible EGU must submit a complete written application that includes the information listed in (a)(13)(vi)(A) through (E) of this section, except that the period of time under (a)(13)(vi)(A) would be 12 months.

utility emissions

§ 60.5775b What standards of performance must I include in my State plan?

(3) The owner or operator must submit a final report to the EPA no later than 6 months following its committed closure date. (a) If you are the owner or operator of an EGU that has committed to permanently cease operations by January 1, 2032, you must maintain records for and submit the reports listed in paragraphs (a)(1) through (3) of this section according to the electronic reporting requirements in paragraph (b) of this section. (e) You must provide the EPA with non-editable and editable copies of any submitted revision to existing approved federally enforceable State plan components.