SECTION 165:35-41-7. Reporting

(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 andsubledgers; 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.

(d)   After receiving the report, the Commission:

(1)   May schedule a hearing about the performance of the programs, the outlook for the future, and other relevant issues and may consider requests from parties for a hearing; and

(2)   Will endeavor to act on the report within ninety (90) days by accepting the report, rejecting the report, or opening an investigation to inquire further into the report.

(e)   The Commission may direct the utility to make brief quarterly or monthly reports including measurements of key metrics and news of any unexpected developments in program administration, delivery or planning.

[Source: Added at 26 Ok Reg 1849, eff 6-25-09; Amended at 31 Ok Reg 1057, eff 1-1-16]