Oklahoma Administrative Code › Title 165 - Corporation Commission › Chapter 35 - Electric Utility Rules › Subchapter 41 - Demand Programs › Section 165:35-41-4 - Demand portfolio submission and implementation

Current through Vol. 41, No. 20, July 1, 2024
(a) All electric utilities under rate
				regulation of the Commission having more than 10,000 meters in the state of
				Oklahoma shall propose, at least once every three years, and be responsible for
				the administration and implementation of a Demand Portfolio of Demand Programs
				within their service territories. Such proposals shall be made by filing an
				application with the Commission on or before July 1 prior to the year the
				programs will be effective. The application shall describe the Demand Portfolio
				and contain the following information:
(1) A
				description of the intent of the Demand Portfolio as a whole;
(2) A description of the intent of each
				Demand Program;
(3) A description
				and quantification of the target market of each Demand Program, differentiated
				by customer sectors;
(4) A base
				line describing the state of the market that each Demand Program is intended to
				address, taking into account applicable building energy codes and appliance and
				equipment energy standards;
(5) A
				description of the barriers to investment in energy efficiency and demand
				response in the absence of each Demand Program and the ways each program Demand
				Program will reduce or eliminate these barriers;
(6) A description of research and public
				input that contributed to the development of the content of each Demand
				Program;
(7) A report of the
				cost-effectiveness of each Demand Program and the Demand Portfolio, including
				program and measure-level supporting data which shall include, but not be
				limited to, cost-effectiveness screening assumptions of gross and net energy
				and demand savings, coincident demand factors, energy allocation factors for
				seasonal and for peak, off-peak and shoulder periods, non-electric resource
				benefits, non-resource benefits, participation and/or measure unit numbers,
				inducement levels, measure cost, and other non-inducement program
				costs;
(8) A detailed description
				of the derivation of the energy, generation, and transmission and distribution
				avoided costs, retail cost projections, reserve margins, discount rates, and
				average and peak line loss assumptions used in the cost-effectiveness
				calculations.
(9) A description of
				how each Demand Program is expected to change over its course to reflect
				expected changes in market penetration, technology, and other market
				information, as well as lessons learned;
(10) A plan for evaluation, measurement, and
				verification of performance and results of the demand portfolio and each
				program, including a plan for the use of deemed savings, if applicable, or the
				use of statistical sampling, if applicable, or the use of metering, where
				appropriate; provided that costs associated with the EM&V plan shall not
				exceed five percent (5%) of the total three-year Demand Portfolio
				budget;
(11) A plan for evaluation
				of the market effects of each Demand Program or applicable group of
				programs;
(12) A plan for
				evaluation of administration and implementation of each Demand Program or
				applicable group of programs;
(13)
				A plan for ending a Demand Program, if applicable;
(14) A process for amending a Demand
				Program;
(15) An annual budget for
				each Demand Program, providing detail for program costs, and differentiating
				evaluation, measurement, and verification costs from other program
				costs;
(16) A report on how the
				Demand Portfolio is expected to affect rates, sales, average bills and total
				revenue requirement for each customer sector;
(17) A report on how the Demand Portfolio
				meets savings goals that may be in place at the time of filing;
(18) An estimate of expected savings in peak
				demand, energy use, and capacity, with location information about the source of
				savings if savings are not expected to be evenly distributed throughout the
				utility system;
(19) Detailed
				explanation of the utility's request for recovery of prudently incurred program
				costs, recoupment and calculation of lost net revenue, and additional
				incentives the utility proposes it requires to make the programs workable;
				and
(20) Identification of the
				Demand Portfolio administrator, including name, job title, business postal
				address, business electronic mail address, and business telephone
				number.