Chapter PSC 111

PSC 111.25(2) (2) Data submission. Each electricity provider, except operators of wholesale merchant plants, shall calculate electric power supply for the 7-year period encompassing the SEA and submit the results to the commission. Any part of a capacity purchase without reserves, as defined in s. PSC 111.23 (1) (a), that is intended to compensate for transmission losses associated with delivery of that purchase, shall be excluded from the calculation of electricity power supply. All miscellaneous supply factors that decrease supply resources shall be deducted from electric power supply. All miscellaneous supply factors that increase supply resources shall be added to electric power supply.

PSC 111.25 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00; CR 03-086: am. (2) Register September 2005 No. 597, eff. 10-1-05.

subch. IV of ch. PSC 111 Subchapter IV — Economic, Environmental, and Conservation Data

PSC 111.31 PSC 111.31 Economic data. Each electricity provider, except self-providers and operators of wholesale merchant plants, shall submit all of the following economic data:

PSC 111.31(1) (1) Average energy production cost. The electricity provider’s average energy production cost for each type of generating unit, including nuclear, coal-fired, gas simple-cycle, gas combined-cycle, diesel and renewable units. The electricity provider shall specify the expected range of energy production cost by unit type for each year in a 3-year period encompassing the SEA and one succeeding calendar year.

PSC 111.31(2) (2) System dispatch cost. Upon commission request, for those days when the market energy price exceeded $250 per megawatt-hour measured exclusive of capital costs or when the market price exceeded $2,000 per megawatt-hour measured inclusive of capital costs, the electricity provider’s hourly historical system dispatch costs, computed using available electric generating capacity and those capacity purchases or sales relevant at the time.

PSC 111.31 Note Note: This information is needed to determine, as required by s. 196.491 (2) (a) 12. and 13., Stats., if competition is contributing to the provision of sufficient capacity and energy at a reasonable price.

PSC 111.31 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00; CR 03-086: am. (1) Register September 2005 No. 597, eff. 10-1-05.

PSC 111.33 PSC 111.33 Pollutant data. Each electricity provider shall submit, for the 7-year period encompassing the SEA, the annual average level of emissions identified in s. PSC 111.21 (1) (a) 6., per kWh of output.

PSC 111.33 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00; CR 03-086: am. Register September 2005 No. 597, eff. 10-1-05.

PSC 111.35 PSC 111.35 Energy conservation data. Any electricity provider, except self-providers and operators of wholesale merchant plants, that provides rate-based energy efficiency programs to Wisconsin customers directly or by contracting, shall provide all of the following energy conservation activity data and information for the 7-year period encompassing the SEA:

PSC 111.35(1) (1) Spending. Dollars spent on energy conservation activity affecting any Wisconsin customer.

PSC 111.35(2) (2) Energy and demand savings. Energy savings in kWh and demand savings in kW, excluding direct load control and interruptible load impacts specified in s. PSC 111.11 (2) (a) 2. and 3., reported for any Wisconsin customer.

PSC 111.35(3) (3) Energy conservation program descriptions. A comprehensive description of all planned activities to discourage inefficient and excessive power use.

PSC 111.35 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00; CR 03-086: am. (intro.) Register September 2005 No. 597, eff. 10-1-05.

subch. V of ch. PSC 111 Subchapter V — Transmission System Operation Data

PSC 111.41 PSC 111.41 Transmission system reservations data from electricity providers. For each capacity resource reported under s. PSC 111.21, delivery of which requires transmission system reservations, and for each capacity purchase reported under s. PSC 111.11 or 111.23, the electricity provider shall submit information on the transmission arrangements to be used to deliver the capacity, including all of the following:

PSC 111.41(1) (1) Service provider. The provider of transmission service.

PSC 111.41(2) (2) Period and type of service. The period and type of each transmission reservation, and any other service attributes defined by the provider of transmission service.

PSC 111.41(3) (3) Dates. The starting and ending dates of service.

PSC 111.41(4) (4) Path. The transmission path, if point-to-point service is being used.

PSC 111.41(5) (5) Status of request. The status of the request for transmission service.

PSC 111.41(6) (6) Size of reservation. The size of the transmission service reservation, in MW.

PSC 111.41(7) (7) Losses. Amount of incremental losses associated with transmission service, as determined by the transmission provider.

PSC 111.41 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00.

PSC 111.43 PSC 111.43 Data from transmission providers. Each transmission provider shall submit all of the following data, except that if the data have been previously filed with the commission, the transmission provider may identify the applicable filing instead of providing duplicate data:

PSC 111.43(1) (1) New high-voltage transmission lines. A complete description of each high-voltage transmission line that the transmission provider intends to own in whole or in part, on which construction is planned to commence within 7 years, including all of the following:

PSC 111.43(1)(a) (a) Endpoints of the line.

PSC 111.43(1)(b) (b) Proposed corridors.

PSC 111.43(1)(c) (c) Nominal operating voltage.

PSC 111.43(1)(d) (d) Nominal voltage of construction class.

PSC 111.43(1)(e) (e) Needed substation modifications.

PSC 111.43(1)(f) (f) Estimated cost.

PSC 111.43(2) (2) Plans for preserving transmission adequacy.

PSC 111.43(2)(a) (a) In this subsection, “long-term” study excludes all of the following:

PSC 111.43(2)(a)1. 1. Routine, commercial transfer capability and operations studies.

PSC 111.43(2)(a)2. 2. Customer-specific transmission studies.

PSC 111.43(2)(b) (b) The results and assumptions of each long-term study undertaken by transmission providers, jointly or individually, within the past 2 years or subsequent to the data filing for the last SEA, that examines future transmission transfer capabilities across boundaries of reliability council regions, subregions, or control areas or across the borders of Wisconsin. The results and assumptions of each long-term study about the effect of transmission system reinforcement on transfer capability shall be included in the data submitted under this paragraph.

PSC 111.43(2)(c) (c) A complete FERC Form 715 for each of the most recent 2 years available, and any documents or data cited on Form 715 that are not published by the Wisconsin commission.

PSC 111.43(2)(d) (d) The results and assumptions of each long-term, local load serving study the transmission provider used to establish the need for the high-voltage transmission lines described in sub. (1), including all discussions of project need and alternatives that may be part of the study.

PSC 111.43(3) (3) Power flow cases.

PSC 111.43(3)(a) (a) For each of the 7 years encompassing the SEA, the most recent power flow base case undertaken by the reliability council in which the transmission provider is located, for each of the following conditions:

PSC 111.43(3)(a)1. 1. Summer peak.

PSC 111.43(3)(a)2. 2. Winter peak.

PSC 111.43(3)(a)3. 3. Off-peak.

PSC 111.43(3)(b) (b) The base cases in par. (a) need only be submitted if the commission requests that they be filed.

PSC 111.43(4) (4) Use of the transmission system. If the transmission provider charges a tariffed amount for use of its transmission system, monthly data, for the 7-year period encompassing the SEA, on total transfer capability, available transfer capability and confirmed reservations for the use of the transmission system. Total transfer capability and available transfer capability shall be calculated in accordance with the provider’s obligations, under 18 CFR Part 37, to calculate these values. Reservation data under this subsection shall concern only those reservations that are firm and of monthly duration or longer. Data shall include any transmission margins applied in the calculation of available transfer capability and any other use of the transmission system relevant to the calculation of monthly available transfer capability, including use by the transmission provider to meet existing commitments.

PSC 111.43 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00; CR 03-086: am. (1) (intro.), (3) (a) (intro.) and (4) Register September 2005 No. 597, eff. 10-1-05.

subch. VI of ch. PSC 111 Subchapter VI — CPCN Applications

PSC 111.51 PSC 111.51 CPCN applications for facilities – general.

PSC 111.51(1) (1) Commencement of construction. Construction on a facility may not commence until the commission issues a CPCN for the facility.

PSC 111.51(2) (2) Actions before filing a CPCN application. Before filing an engineering plan for a large electric generating facility or a detailed project plan for a high-voltage transmission line, as defined in s. 196.491 (3) (b), Stats., the applicant shall do all of the following:

PSC 111.51(2)(a) (a) Notify the department and the commission of its intent to apply for a CPCN.

PSC 111.51(2)(b) (b) Consult with commission staff, in cooperation with staff from the department, on the scope of the proposed project, the alternatives that must be considered in the application, and additional information that the commission may require as part of the CPCN application.

PSC 111.51(3) (3) Copies of the application. The applicant shall file 10 copies of its CPCN application. The applicant shall promptly provide additional copies as may be requested by the commission.

PSC 111.51(4) (4) Completeness determination and distribution of application.

PSC 111.51(4)(a) (a) The commission shall notify an applicant of whether its CPCN application is complete within 30 days of its filing. If the commission does not notify an applicant within 30 days then the application shall be considered complete. An applicant may supplement and refile an incomplete CPCN application.

PSC 111.51(4)(b) (b)

PSC 111.51(4)(b)1. 1. Within 10 days after a CPCN application has been filed, the commission shall send an electronic copy of the application to the clerk of each municipality and town in which the proposed facility is to be located and to the main public library in each county in which the proposed facility is to be located. A statement shall be included on the initial page of the electronic document explaining that this is an initial application, that it is likely to be changed, and that updates may be obtained from the applicant that filed the application or the commission’s website (psc.wi.gov).

PSC 111.51(4)(b)2. 2. As soon as is practicable, but no more than 30 days after the commission has determined that a CPCN application is complete, the commission shall send an electronic copy of the complete application to the clerk of each municipality and town in which the proposed facility is to be located and to the main public library in each county in which the proposed facility is to be located.

PSC 111.51(4)(b)3. 3. The commission may fulfill subds. 1. and 2. by directing the applicant to send copies of the complete application to the locations identified in those subdivisions.

PSC 111.51 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00; CR 07-044: am. (2) (intro.) and (b), cr. (4) Register May 2008 No. 629, eff. 6-1-08; CR 13-101: am. (4) (b) 2. Register June 2014 No. 702, eff. 7-1-14.

PSC 111.53 PSC 111.53 CPCN applications for large electric generating facilities.

PSC 111.53(1) (1) Contents of a CPCN application. Except as provided in sub. (2), a CPCN application for a large electric generating facility is not complete until the applicant has filed all of the following information with the commission:

PSC 111.53(1)(a) (a) The operating characteristics of the proposed facility, including all of the following:

PSC 111.53(1)(a)1. 1. The number of generating units to be included in the facility.

PSC 111.53(1)(a)2. 2. A description of each generating unit, including type, size, and fuel.

PSC 111.53(1)(a)3. 3. The expected hours of operation and lifetime of the facility.

PSC 111.53(1)(a)4. 4. The names and addresses of owners and investors and the percent of ownership.

PSC 111.53(1)(a)5. 5. The fuel source and availability. If the facility uses fossil fuel, the fuel’s heating value and chemical analysis, the type of transportation to be used, and the approximate capacity of on-site storage shall be provided.

PSC 111.53(1)(a)6. 6. The facility’s estimated capacity factors, for each generating unit, and the basis for the estimates.

PSC 111.53(1)(a)7. 7. The estimated rate of discharge of pollutants for appropriate time intervals, as related to applicable regulatory standards.

PSC 111.53(1)(a)8. 8. The heat rates over the range of operating capacity for each generating unit.

PSC 111.53(1)(b) (b) The need for the proposed facility in terms of demand and energy.

PSC 111.53(1)(c) (c) The economic aspects of the proposed facility, including all of the following:

PSC 111.53(1)(c)1. 1. The estimated capital cost of the generating facility and all related facilities, broken down by major plant accounts. All cost escalation factors used in the estimate shall be identified.

PSC 111.53(1)(c)2. 2. The projected unit fuel cost, in cents per million Btu, both for the first year of operation and levelized in nominal terms over the life of the unit or facility. All cost escalation factors used in the estimate shall be identified.

PSC 111.53(1)(c)3. 3. The estimated annual production cost, calculated as operating, maintenance and fuel costs for the first year of operation and levelized in nominal terms over the life of the facility. All cost escalation factors used and other significant supporting data shall be included.

PSC 111.53(1)(c)4. 4. The estimated annual total cost, calculated as capital and production costs for the first year of operation, in mills per net kWh generated, and levelized in nominal terms over the life of the facility. All cost escalation factors used and other significant supporting data shall be included.

PSC 111.53(1)(c)5. 5. The estimated useful life of facility, based on depreciation rates established by the commission.

PSC 111.53(1)(d) (d) The alternative sources of supply considered, including information about all of the following alternatives:

PSC 111.53(1)(d)1. 1. Energy conservation and efficiency.

PSC 111.53(1)(d)2. 2. Any alternative whose energy source has a higher priority ranking under s. 1.12 (4) (b) to (d), Stats., than the fuel proposed to used for the facility.

PSC 111.53(1)(d)3. 3. For any facility that will use a combustible energy resource but not provide cogeneration, an explanation regarding why cogeneration is not feasible.

PSC 111.53(1)(d)4. 4. Purchased power.

PSC 111.53(1)(e) (e) A description of the alternatives considered, a description of the siting process, and a list of the factors considered in choosing and ranking the alternatives.

PSC 111.53(1)(em) (em) Information demonstrating how brownfields, as defined in s. 16.287 (1) (a), Stats., and interpreted by the commission, were considered as site alternatives.

PSC 111.53(1)(f) (f) Except as provided in sub. (2) (b), site-related information for each of two proposed power plant sites, including all of the following:

PSC 111.53(1)(f)1. 1. The regulatory approvals required for construction and operation of the facility.