Utility-Specific Emission Factors

(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.

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.

(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.

§ 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.