Oklahoma Administrative Code › Title 165 - Corporation Commission › Chapter 35 - Electric Utility Rules › Subchapter 41 - Demand Programs › Section 165:35-41-7 - Reporting

Current through Vol. 41, No. 20, July 1, 2024
(a) Each utility
				shall submit an annual report by July 1 of each year on the performance of the
				Demand Portfolio for the preceding program year and cumulative program
				performance which shall include the information enumerated in this
				section.
(b) The annual report
				shall be submitted with any true-up mechanism for cost recovery in order for
				the Public Utility Division to evaluate and review cost recovery, lost revenue
				and incentive calculations proposed to be recovered from consumers.
(c) Energy efficiency program results and
				demand response program results will be reported separately.
(d) The report shall contain a Demand
				Portfolio summary reflecting the scale of each Demand Program as a part of the
				Demand Portfolio and will include the following:
(1) Name of Demand Program listed by customer
				category;
(2) The date each Demand
				Program was started or the date each Demand Program was revised;
(3) The number of participating customers per
				Demand Program;
(4) By Demand
				Program, approved projected energy and demand savings;
(5) Gross energy and demand savings and
				performance of each Demand Program;
(6) Verified energy and demand savings by
				Demand Program and methods used to verify these savings;
(7) For education programs, measurements of
				outreach efforts, including pre-program and post program results. Copies of
				evaluations, surveys, focus group results, and other measurement techniques
				used to gauge effectiveness of education efforts;
(8) Levelized cost per kWh for the Demand
				Portfolio, Demand Program, and levelized cost per kWh by customer sector
				including all assumptions used to make the calculation;
(9) Demand Portfolio funding as a percent of
				total annual electricity revenue ;
(10) Demand Portfolio energy savings as a
				percent of total annual energy sales;
(11) The projected program costs.
(A) These costs should be separated into the
				following categories to allow review of spending:
(i) Administrative costs;
(ii) Inducements: direct payments and other
				inducements;
(iii) Education and
				marketing costs;
(iv) Program
				delivery costs;
(v) EM&V costs.
(B) Workpapers to allow
				review and reconciliation of accounting information:
(i) Utilities shall provide workpapers with
				working formulas, calculations, and linkages to support all costs;
(ii) General Ledger: a copy of, or access to,
				the general ledger and subledgers; and
(iii) Comparative Trial Balances: a schedule
				of, or access to, comparative trial balances detailed by account for the test
				year and the first preceding year.
(12) The actual program costs.
(A) These costs should be separated into the
				following categories to allow review of spending:
(i) Administrative costs;
(ii) Inducements: direct payments and other
				inducements;
(iii) Education and
				marketing costs;
(iv) Program
				delivery costs; and
(v) EM&V
				costs.
(B) Workpapers
				to allow review and reconciliation of accounting information.
(i) Utilities shall provide workpapers with
				working formulas, calculations, and linkages to support all costs;
(ii) General Ledger: a copy of, or access to,
				the general ledger and subledgers; and
(iii) Comparative Trial Balances: a schedule
				of, or access to, comparative trial balances detailed by account for the test
				year and the first preceding year;
(13) Projected lost revenues;
(14) Actual calculated lost net revenues,
				including workpapers and working spreadsheets (formulas, calculations,
				linkages, and assumptions) in sufficient detail to allow review of adjustments
				to verify energy and demand savings;
(15) Projected incentives, including project
				cost effectiveness tests;
(16)
				Actual calculated incentives, including workpapers and working spreadsheets
				(formulas, calculations, linkages, and assumptions) for updated cost
				effectiveness tests, in sufficient detail to allow review of cost effectiveness
				calculations;
(17) The utility's
				annual growth in metered energy and peak demand for the previous three (3)
				years, with a calculation of the average growth rate over that entire period by
				customer class or major customer class segments;
(18) The most current information available
				comparing the base line and milestones to be achieved under market
				transformation programs with actual conditions in the market;
(19) The amount of reduced emissions and
				water consumption experienced by the utility, including all assumptions and
				calculations details, during the Demand Program period for the current program
				year;
(20) By Demand Program, a
				summary of spending including the following:
(a) Administrative costs;
(b) Inducements: direct payments and other
				inducements;
(c) Education and
				marketing costs;
(d) Program
				delivery costs; and
(e) EM&V
				costs;
(21) A statement
				of any funds that were committed but not spent during the year, by program,
				with an explanation for non-spending;
(22) A detailed description of each Demand
				Program reflecting the scale of the program as a part of the Demand portfolio
				that includes the following:
(A) Number of
				customers served by each Demand Program or program category;
(B) Program or program category
				expenditures;
(C) Verified energy
				and peak demand savings achieved by the Demand Program or program category,
				when available; and
(D) A
				description of proposed changes in the Demand Program plans;
(23) A list of research and
				development activities included in the Demand Portfolio, their status, and a
				report on the connection between each activity and effective Demand
				Programs;
(24) Identification of
				Demand Program implementers, including names, job titles, business postal
				addresses, business electronic mail addresses, and business telephone
				numbers;
(25) The number of
				customers eligible for High-Volume Electricity User opt out, their aggregate
				load as a percentage of total energy sales, the number of such customers that
				have opted out, and the percentage of total energy sales that they comprise.
				The number of municipal or state customers that have opted out and the
				aggregated load this represents as percentage of total energy sales;
				and
(26) Identification of
				instances in new construction or renovation when a natural gas main served a
				location so a gas furnace or water heater could have been installed but the
				customer installed an electric device and an electric utility inducement was
				provided.