Oklahoma Administrative Code › Title 165 - Corporation Commission › Chapter 45 - Gas Service Utilities › Subchapter 23 - Demand Programs › Section 165:45-23-4 - Demand portfolio submission and implementation

Current through Vol. 41, No. 20, July 1, 2024
(a) All natural gas utilities under rate
				regulation of the Commission having more than 25,000 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 May 1 of 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 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 in the absence
				of each Demand Program and the ways each 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 savings,
				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
				will meet savings goals that may be in place at the time of filing and or that
				are otherwise proposed in the filing;
(18) An estimate of the expected savings in
				natural gas usage, with location information about the source of savings, if
				savings are not expected to be evenly distributed throughout the utility
				system;
(19) A detailed explanation
				of the utility's request for recovery of prudently incurred program costs,
				recoupment of lost net revenue, and any additional incentives the utility
				proposes it requires to make the programs workable;
(20) Identification of the Demand Portfolio
				administrator, including name, job title, business postal address, business
				electronic mail address, and business telephone number; and