Chapter PSC 111

PSC 111.05(1) (1) Printed and electronic format. Except for the data required under s. PSC 111.35 (3), data required under subch. II, III or IV shall be in printed, tabular form and in electronic spreadsheet format. Data required under s. PSC 111.35 (3) shall be in printed, tabular form. Data required under subch. V shall be in printed, tabular form, unless specifically exempted, and in electronic spreadsheet format. If the commission provides tabular reporting or electronic format specifications, data filings shall comply with these specifications. All data filings shall be up to date and fully documented. All data filings shall indicate and provide the source of the data.

PSC 111.05(2) (2) Joint filings.

PSC 111.05(2)(a) (a) Any electricity provider may file the data required under subch. II, III, IV or V jointly, combining its information with that of other electricity providers. Any transmission provider may file the data required under subch. V jointly, combining its information with that of other transmission providers. Except as provided in par. (b), information in joint filings may not be aggregated in a manner that obscures provider-specific data.

PSC 111.05(2)(b) (b) A wholesale electricity supplier may file data that is required under subch. II, III, IV or V on behalf of one or more municipal electric utilities or cooperatives.

PSC 111.05(3) (3) Multi-state electricity and transmission providers.

PSC 111.05(3)(a) (a) Except as provided in par. (b), electricity and transmission providers with multi-state operations may, if Wisconsin-specific information is not available, file prorated data based on an allocation of Wisconsin demand to total company system demand.

PSC 111.05(3)(b) (b) Electricity and transmission providers with multi-state operations shall provide Wisconsin-specific information for all of the following:

PSC 111.05(3)(b)1. 1. Conservation activities, as required under s. PSC 111.35.

PSC 111.05(3)(b)2. 2. Forecasts of Wisconsin peak demand, as required under s. PSC 111.13.

PSC 111.05(3)(b)3. 3. Transmission and generation facilities located in Wisconsin or used specifically for Wisconsin purposes, as required under s. PSC 111.21 or 111.43.

PSC 111.05 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00.

PSC 111.07 PSC 111.07 Supplemental data requests for SEA; waivers. Electricity providers or transmission providers shall provide additional information, as the commission may request to prepare its SEA. The commission may also waive data filing requirements under this chapter to avoid undue hardship if preparation of the SEA can still be accomplished in a timely manner.

PSC 111.07 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00.

PSC 111.09 PSC 111.09 Confidentiality. The commission shall consider information submitted under this chapter to be confidential, if the provider shows that the information is competitive under s. 196.14, Stats., a trade secret under s. 19.36 (5) or 134.90, Stats., or is otherwise exempt from public records laws under subch. II of ch. 19, Stats.

PSC 111.09 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00.

subch. II of ch. PSC 111 Subchapter II — Assessment of Electric Demand

PSC 111.11 PSC 111.11 Electric demand data.

PSC 111.11(1) (1) Definitions. In this section:

PSC 111.11(1)(a) (a) “Capacity purchase including reserves” means a purchase of firm electric generating capacity that has actually occurred or that is subject to an existing contract, including options to purchase or contracts subject to contingencies, and that includes all of the following terms:

PSC 111.11(1)(a)1. 1. A firm transmission path from source to destination.

PSC 111.11(1)(a)2. 2. The seller has responsibility for reserves.

PSC 111.11(1)(a)3. 3. The seller is obliged to supply across peak conditions with no unilateral curtailment option.

PSC 111.11(1)(a)4. 4. The seller will count the sale as an additional demand obligation.

PSC 111.11(1)(b) (b) “Capacity sale including reserves” means a sale of firm electric generating capacity that has actually occurred or that is subject to an existing contract, including options to sell or contracts subject to contingencies, and that includes the terms specified in par. (a) 2. to 4.

PSC 111.11(2) (2) Factors affecting electric demand.

PSC 111.11(2)(a) (a) Each electricity provider, except operators of wholesale merchant plants, shall submit all of the following data:

PSC 111.11(2)(a)1. 1. Monthly peak demand data for the 7-year period encompassing the SEA, including responsibility for power losses. Any loss responsibility associated with the delivery of purchased capacity shall be separately identified.

PSC 111.11(2)(a)2. 2. The reduction in the summer and winter peak demand, for any of the years encompassing the SEA, due to direct load control programs that allow system operators to manage customer loads.

PSC 111.11(2)(a)3. 3. The reduction in the summer and winter peak demand, for any of the years encompassing the SEA, due to the interruption of customer load by tariff or contract.

PSC 111.11(2)(a)4. 4. The effect on summer and winter peak demand, for any of the years encompassing the SEA, due to each capacity sale including reserves that affects peak demand.

PSC 111.11(2)(a)5. 5. The effect on summer and winter peak demand, for any of the years encompassing the SEA, due to each capacity purchase including reserves that affects peak demand. Any part of a purchase intended to compensate for transmission losses associated with delivery of the purchase shall be separately identified. For each out-of-state capacity purchase including reserves cited under this paragraph, the buyer shall demonstrate that the seller is treating its sale with the same priority as the electrical demand that the seller is legally obligated to serve.

PSC 111.11(2)(a)6. 6. The effect on summer and winter peak demand, for any of the years encompassing the SEA, due to any arrangements other than those specified in subds. 1. to 5., that also affect peak demand in Wisconsin.

PSC 111.11(2)(b) (b) An electricity provider may aggregate information for individual arrangements less than 10 MW in its data filing under par. (a) 1., 2., 3., 4., 5. or 6.

PSC 111.11 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00; CR 03-086: am. (2) (a) 1. to 6. Register September 2005 No. 597, eff. 10-1-05.

PSC 111.13 PSC 111.13 Calculation of adjusted electric demand.

PSC 111.13(1) (1) Definition. In this section, “adjusted electric demand” means peak demand including responsibility for power losses, less the effect of direct load control, interruptible load, or capacity purchases including reserves as defined in s. PSC 111.11 (1) (a), plus the effect of capacity sales including reserves as defined in s. PSC 111.11 (1) (b).

PSC 111.13(2) (2) Data submission. Each electricity provider, except operators of wholesale merchant plants, shall calculate adjusted electric demand for the 7-year period encompassing the SEA and submit the results to the commission. Any transmission loss responsibility associated with delivery of a particular capacity purchase including reserves, as defined in s. PSC 111.11 (1) (a), shall be separately identified. All miscellaneous demand factors that decrease peak demand shall be deductions when calculating adjusted electric demand. All miscellaneous demand factors that increase peak demand shall be additions when calculating adjusted electric demand.

PSC 111.13 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. III of ch. PSC 111 Subchapter III — Assessment of Electric Power Supply

PSC 111.21 PSC 111.21 Capacity data.

PSC 111.21(1) (1) Data about generating facilities. Each electricity provider shall submit all of the following data for any generation in the state or generation used to supply an ultimate end user in the state:

PSC 111.21(1)(a) (a) A complete current inventory of its installed electric generating capacity, including all of the following:

PSC 111.21(1)(a)1. 1. The name and location of each facility.

PSC 111.21(1)(a)2. 2. The type of load of the facility, including peaking, intermediate, or base load.

PSC 111.21(1)(a)3. 3. The type of fuel used.

PSC 111.21(1)(a)4. 4. The summer and winter net rated capacity.

PSC 111.21(1)(a)5. 5. The operational status of the facility, as of the filing date.

PSC 111.21(1)(a)6. 6. Emissions of particulates, ash, SO2, NOx, CO2, N2O and Hg, per kWh of output.

PSC 111.21(1)(b) (b) Summer and winter peak data on aggregate net rated capacity as of the filing date.

PSC 111.21(1)(c) (c) A complete identification and description of each unit’s net rated capacity that the electricity provider intends to retire during the 7-year period encompassing the SEA, including the month and year of expected retirement.

PSC 111.21(1)(d) (d) A complete identification and description of each generating addition the electricity provider proposes to commence constructing during the 7-year period encompassing the SEA, including all of the following:

PSC 111.21(1)(d)1. 1. The in-service date.

PSC 111.21(1)(d)2. 2. The location of the facility.

PSC 111.21(1)(d)3. 3. The type of load of the facility, including peaking, intermediate, or base load.

PSC 111.21(1)(d)4. 4. The type of fuel used.

PSC 111.21(1)(d)5. 5. The summer and winter net rated capacity.

PSC 111.21(1)(d)6. 6. Expected levels of emissions identified in par. (a) 6., per kWh of output.

PSC 111.21(1)(e) (e) A complete identification and description of each expected capacity change at existing generating units during the 7-year period encompassing the SEA, including all of the following:

PSC 111.21(1)(e)1. 1. The in-service date.

PSC 111.21(1)(e)2. 2. The location of the facilities.

PSC 111.21(1)(e)3. 3. The function of the upgrade, improvement, or downgrade.

PSC 111.21(1)(e)4. 4. The change in summer and winter net rated capacity.

PSC 111.21(1)(e)5. 5. Expected changes in emissions identified in par. (a) 6., per kWh of output.

PSC 111.21(1)(f) (f) A complete identification and description of each supply factor that is not covered by pars. (a) to (e), but also affects electric power supply during peak demand in Wisconsin for the 7-year period encompassing the SEA.

PSC 111.21(2) (2) Aggregating data on small generation facilities. An electricity provider may aggregate information for individual generating facility less than 10 MW in its data filing under sub. (1) (a), (b), (c), (d), (e) or (f).

PSC 111.21 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00; CR 03-086: am. (1) (c), (d) (intro.), (e) (intro.) and (f) Register September 2005 No. 597, eff. 10-1-05.

PSC 111.23 PSC 111.23 Capacity purchase and sale data affecting electric power supply.

PSC 111.23(1) (1) Definitions. In this section:

PSC 111.23(1)(a) (a) “Capacity purchase without reserves” means a purchase of electric generating capacity that has actually occurred or that is subject to an existing contract, including options to purchase or contracts subject to contingencies, and that includes all of the following terms:

PSC 111.23(1)(a)1. 1. A firm transmission path from source to destination.

PSC 111.23(1)(a)2. 2. The buyer has responsibility for reserves.

PSC 111.23(1)(a)3. 3. The seller is obliged to supply across peak conditions with no unilateral curtailment option, except for particular contingencies that are specified in the contract.

PSC 111.23(1)(a)4. 4. The seller will count the sale as an available capacity reduction.

PSC 111.23(1)(b) (b) “Capacity sale without reserves” means a sale of electric generating capacity that has actually occurred or that is subject to an existing contract, including options to sell or contracts subject to contingencies, and that includes the terms specified in par. (a) 2. to 4.

PSC 111.23(2) (2) Capacity purchases or sales without reserves. Each electricity provider, except operators of wholesale merchant plants, shall submit for the 7-year period encompassing the SEA, summer and winter peak data listing all of the following data:

PSC 111.23(2)(a) (a) The amount and type of each capacity purchase without reserves in Wisconsin, in net MW, including an identification of each of the following:

PSC 111.23(2)(a)1. 1. Whether the purchase is on a system or unit basis.

PSC 111.23(2)(a)2. 2. How much of the purchase, if any, is intended to compensate for transmission losses associated with delivery of the purchase.

PSC 111.23(2)(b) (b) The amount and type of each capacity sale without reserves, in net MW, including an identification of whether the sale is on a system or unit basis.

PSC 111.23 History History: Cr. Register, June, 2000, No. 534, eff. 7-1-00; CR 03-086: am. (2) (intro.) Register September 2005 No. 597, eff. 10-1-05.

PSC 111.25 PSC 111.25 Calculation of electric power supply.

PSC 111.25(1) (1) Definition. In this section, “electric power supply” means aggregate generating capacity plus capacity additions, capacity upgrades or improvements at existing units, and capacity purchases without reserves as defined in s. PSC 111.23 (1) (a), less unit retirements, capacity downgrades at existing units, and capacity sales without reserves as defined in s. PSC 111.23 (1) (b).

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.