Current through Vol. 41, No. 13, March 15, 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.
(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.