National Public Utilities Council Tracking Utility Net Zero Progress

Emission factors contained in Table 2.2 must be used for the quantification of GHG reductions occurring in calendar year 2025. Emission factors contained in Table 2.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024. Emission factors contained in Table 1.4 must https://labverra.com/articles/opaque-solar-panels-innovations-implications/ be used for the quantification of GHG reductions occurring in calendar year 2027. Emission factors contained in Table 1.3 must be used for the quantification of GHG reductions occurring in calendar year 2026.

(A) Identify each affected unit for which the owner or operator is seeking the compliance extension; (i) A demonstration that the owner or operator of the affected EGU cannot meet its compliance date due to circumstances beyond the owner or operator’s control and that the owner or operator has met all relevant increments of progress and otherwise taken all steps reasonably possible to install the controls necessary for compliance by the specified compliance date up to the point of the delay. Such provisions may allow an owner or operator of an affected EGU to request an extension of no longer than one year from the specified compliance date and may only allow the owner or operator to receive an extension once. (iii) The State plan must provide that an existing coal-fired steam generating EGU operating past the date listed in the State https://www.mindsetterz.com/an-in-depth-examination-of-fusion-lithium-pylontech-and-victron-energy-solutions/ 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. (ii) You must include a list of the coal-fired steam generating EGUs that are existing sources at the time of State plan submission and that plan to permanently cease operation before January 1, 2032, and the calendar dates by which they have committed to cease operating.

Emission factors contained in Table 6.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024. Emission factors contained in Table 5.4 must be used for the quantification of GHG reductions occurring in calendar year 2027. Emission factors contained in Table 5.3 must be used for the quantification of GHG reductions occurring in calendar year 2026. Emission factors contained in Table 5.2 must be used for the quantification of GHG reductions occurring in calendar year 2025.

• (2) Documentation of any assumptions underlying the calculation of the aggregate rate-based standard of performance (lb CO2/MWh-gross).
• (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.
• (e) You must provide the EPA with non-editable and editable copies of any submitted revision to existing approved federally enforceable State plan components.
• (1) For each affected unit in the long-term coal-fired steam generating unit subcategory, initiation of on-site construction or installation of emission control equipment or process change required to achieve 90 percent carbon capture on an annual basis.
• Emission factors contained in Table 5.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024.

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

Emission factors contained in Table 3.3 must be used for the quantification of GHG reductions occurring in calendar year 2027. Emission factors contained in Table 3.3 must be used for the quantification of GHG reductions occurring in calendar year 2026. Emission factors contained in Table 3.2 must be used for the quantification of GHG reductions occurring in calendar year 2025. Emission factors contained in Table 3.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024. Emission factors contained in Table 2.4 must be used for the quantification of GHG reductions occurring in calendar year 2027. Emission factors contained in Table 2.3 must be used for the quantification of GHG reductions occurring in calendar year 2026.

Reported Greenhouse Gas Emissions

The editable copy of any such submitted State plan revision must indicate the changes made at the State level, if any, to the existing approved federally enforceable State plan components, using a mechanism such as redline/strikethrough. Following initial State plan approval, States must provide the EPA with an editable copy of any submitted revision to existing approved federally enforceable State plan components, including State plan backstop measures. In addition to the non-editable version all State plan components designated as federally enforceable must also be submitted in an editable version. (8) Submission of additional data as necessary to update the information submitted under paragraph (a) of this section or in previous progress reports. (4) Enforcement actions initiated against affected EGUs during the reporting period, under any standard of performance or compliance schedule of the State plan. (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.

If an owner or operator of an affected EGU chooses this option, the hourly gross or net electric output for the common stack must be the sum of the hourly gross or net electric output of the individual affected EGUs and the operating time must be expressed as “stack operating hours” (as defined in 40 CFR 72.2). (6) In accordance with § 60.13(g), if two or more affected EGUs implementing the continuous emissions monitoring provisions in paragraph (a)(3) of this section share a common exhaust gas stack and are subject to the same emissions standard, the owner or operator may monitor the hourly CO2 mass emissions at the common stack in lieu of monitoring each EGU separately. To convert each hourly gross or net energy output value reported under 40 CFR part 75 to MWh, multiply by the corresponding EGU or stack operating time. (iii) For rate-based applications, if there is no (i.e., zero) gross electrical, mechanical, or useful thermal output for a particular valid operating hour, that hour must be used in the compliance determination.

This is equivalent to greenhouse gas emissions from:

Combined cycle unit means a stationary combustion turbine from which the heat from the turbine exhaust gases is recovered by a heat recovery steam generating unit to generate additional electricity. https://forestwildwood.com/articles/grand-teton-teepee-lodge-guide/ (7) In any circumstance, the report must be submitted electronically as soon as possible after the outage is resolved. (iv) The date by which you propose to report, or if you have already met the reporting requirement at the time of the notification, the date you reported. (d) Any records required to be maintained by this subpart that are submitted electronically via the EPA’s CEDRI may be maintained in electronic format. (b) Beginning November 12, 2024, if you are the owner or operator of an EGU that has committed to permanently cease operations by January 1, 2032, you must submit all the information required in paragraph (a) of this section in a Permanent Cessation of Operation report in PDF format following the procedures specified in paragraph (c) of this section.

Renewable Energy Adoption

(v) You must include in your State plan a requirement that the owner or operator of each affected EGU shall report to the State regulatory agency any deviation from any federally enforceable State plan reporting milestone within 30 business days after the owner or operator of the affected EGU knew or should have known of the event. (iii) No later than six months from the date the affected EGU permanently ceases operations (either the date used to determine the applicable subcategory under these emission guidelines or the date used to invoke RULOF based on remaining useful life), the owner or operator of the affected EGU must submit a Final Milestone Status Report. (iv) You must include in your State plan a requirement that the owner or operator of each affected EGU shall report to the State regulatory agency any deviation from any federally enforceable State plan increment of progress within 30 business days after the owner or operator of the affected EGU knew or should have known of the event.

Trump declares emergency, moves to block some foreign-made equipment from grid

Emission factors contained in Table 1.2 must be used for the quantification of GHG reductions occurring in calendar year 2025. Emission factors contained in Table 1.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024. Total energy-related carbon dioxide emissions increased by 2%, or about 115 million metric tons, over the same period, compared with 2024.