PSC 116.02(1) (1) For any month or longer period of time, a utility shall calculate fuel cost as the net of the costs and credits for all of the following during the time period:

PSC 116.02(1)(a) (a) Fuel.

PSC 116.02(1)(b) (b) Energy market purchase.

PSC 116.02(1)(c) (c) Energy market sale.

PSC 116.02(1)(d) (d) Voluntary curtailable load program, including any payment made to a retail customer under a tariff authorized under s. 196.192 (2) (bm) 1., Stats.

PSC 116.02(1)(e) (e) Direct load control program. In this paragraph, “direct load control program” means an event-based, payment-to-customers program under which a utility pays a firm customer to reduce its electric demand when system constraints threaten reliable service. The cost of a direct load control program includes all associated costs except any associated equipment cost or standard monthly credit.

PSC 116.02(1)(f) (f) Any tools to manage fuel cost price risk implemented under a risk management plan approved by the commission and included in the fuel cost plan.

PSC 116.02(1)(g) (g) Renewable resource credits.

PSC 116.02(1)(h) (h) Emission allowances, including allowances for sulfur dioxide and carbon dioxide.

PSC 116.02(1)(i) (i) The cost of chemicals used to control emissions.

PSC 116.02(2) (2) 

PSC 116.02(2)(a) (a) If a utility uses a transmission organization to transact an energy market purchase, the utility shall calculate the cost of associated transmission service for that purchase as the sum of the cost of all of the following:

PSC 116.02(2)(a)1. 1. Financial transmission rights or similar related instruments transacted under a risk management plan approved by the commission.

PSC 116.02(2)(a)2. 2. Ancillary services included in a fuel cost plan.

PSC 116.02(2)(a)3. 3. Other transmission organization energy market charges and credits included in an approved fuel cost plan.

PSC 116.02(2)(b) (b) The cost of associated transmission service does not include charges for network transmission service.

PSC 116.02 History History: CR 08-070: cr. Register February 2011 No. 662, eff. 3-1-11; correction in (1) (d) made under s. 13.92 (4) (b) 7., Stats., Register March 2021 No. 783.

PSC 116.03 PSC 116.03 Fuel cost plan.

PSC 116.03(1) (1) Annually, a utility shall file a proposed fuel cost plan as part of an application to open or reopen a general rate case proceeding or, if the utility does not file a general rate case, the utility shall file a proposed fuel cost plan as part of a proceeding limited in scope to fuel cost. A utility shall file a proposed fuel cost plan no more than 360 days or less than 150 days before the beginning of the plan year.

PSC 116.03(2) (2) A utility shall include in a proposed fuel cost plan the following information for the plan year:

PSC 116.03(2)(a) (a) A forecast of the average annual fuel cost.

PSC 116.03(2)(b) (b) A forecast of the annual fuel cost by fuel type.

PSC 116.03(2)(c) (c) A forecast of the annual native system requirement. In a utility’s reopened general rate case proceeding or in a proceeding limited in scope to fuel cost, the applicable annual native system requirement is the same as the commission-approved forecast in the utility’s most recently approved general rate case proceeding.

PSC 116.03(2)(d) (d) Detailed input of the economic dispatch model used to forecast fuel cost.

PSC 116.03(2)(e) (e) Detailed output of the economic dispatch model used to forecast fuel cost.

PSC 116.03(2)(f) (f) All inputs and allocators used to calculate the forecast of the annual average fuel cost and the forecast of the annual native system requirement.

PSC 116.03(2)(g) (g) Associated transmission service purchased or sold.

PSC 116.03(2)(h) (h) Any other information requested by the commission.

PSC 116.03(3) (3) After hearing the commission shall approve a fuel cost plan, with any modifications or conditions the commission considers appropriate. The commission shall establish a utility’s rates in accordance with the approved fuel cost plan, subject to reconciliation under s. PSC 116.07.