Assignment of Proceeding

Dian M. Grueneich is the assigned Commissioner and Jessica T. Hecht and Darwin E. Farrar are the assigned Administrative Law Judges in this phase of this proceeding.

Findings of Fact

1. Load impact estimates are necessary for analysis of the cost-effectiveness of demand response programs, and for long-term resource planning.

2. Load impact protocols improve consistency and accuracy in the calculation of demand response load impact estimates.

3. The requirement for each utility to file its complete demand response load impact report is impractical and overly burdensome.

4. A reduced filing requirement, under which each utility will file summary materials, will meet the Commission's need for information within the formal record of this or a successor demand response proceeding.

5. Requiring the utilities to make the entire report available to the service list of this or a successor proceeding will allow interested parties access to the detailed information required in the load impact protocols without overburdening either the utilities or the Commission's Docket Office with the preparation or storage of large volumes of printed material.

Conclusions of Law

1. The Commission requires load impact information on demand response programs for long-term resource planning and other purposes.

2. It is reasonable to reduce the filing requirements associated with the annual reports on demand response load impacts reports in order to avoid unnecessary and burdensome requirements.

3. It is reasonable to retain the requirements for service of the load impact reports in order to ensure that the Commission and interested parties have access to detailed information related to load reduction associated with demand response activities.

ORDER

IT IS ORDERED that:

1. The Petition for Modification of Ordering Paragraph 4 in
Decision 08-04-050 is granted in part. Ordering Paragraph 4 is modified to read as follows:

"4. Southern California Edison Company (SCE), San Diego Gas & Electric Company (SDG&E), and Pacific Gas and Electric Company (PG&E) shall perform annual studies of their demand response activities using the adopted protocols. SCE, SDG&E, and PG&E shall each file and serve the executive summaries of its report, along with summary tables of each demand response activity, as described in Appendix 1 to this decision, annually on April 1 of each year in this or a successor proceeding. SCE, SDG&E, and PG&E shall each also transmit its complete report, including all tables required in
Protocol 26, to the Commission's Energy Division and serve the report and all tables on the most recent service list for this, or a successor proceeding. If this and all successor proceedings are closed, the filing requirements will no longer apply, but the service requirements shall continue to apply. The information contained in the annual reports consistent with Protocol 26 and the related summary tables may be used in other Commission proceedings, as appropriate."

2. Attachment A to Decision 08-04-050 is modified to incorporate
Appendix 1, describing the summary materials to be filed annually.

This order is effective today.

Dated April 8, 2010, at San Francisco, California.

MICHAEL R. PEEVEY

President

DIAN M. GRUENEICH

JOHN A. BOHN

TIMOTHY ALAN SIMON

NANCY E. RYAN

Commissioners

Appendix 1

Southern California Edison Company, San Diego Gas & Electric Company, and Pacific Gas and Electric Company (collectively, the Utilities) shall prepare the following executive summary and summary tables described below as a part of their annual load impact reports, and shall file this summary information in R.07-01-041 or its successor proceeding, as long as such a proceeding is open.

Executive Summary Requirement

Consistent with D.08-04-050, Attachment A, Protocol 26 under item 4, the utilities shall prepare Executive Summaries of their load impact reports. These executive summaries shall include an overview of the evaluation findings and the study's recommendation for changes to the demand response resource. In addition, it should also describe briefly the methodology, the enrollment forecast and the inputs and assumptions used for calculating the ex post and the ex ante load impact estimates. The utilities should also report the regression model specification³ for each demand response program.

The Executive Summary shall also contain an explanation of how the Monthly System Peak Load Day under the "1-in-2 Weather Conditions" and the "1-in-10 Weather Conditions" were derived and disclose the temperature or Weather Year used for those conditions. It shall also disclose the assumption used for ex ante "portfolio basis" load impacts.

Summary Table Requirement

The Summary Tables to be filed along with the Executive Summary of each utility's load impact reports shall include the aggregate average ex ante load impacts for each Monthly System Peak Load Day under a 1-in-2 Weather Condition and a 1-in-10 Weather Condition for the next 10 years. The average impact shall be based on the hours from 2 p.m.-6 p.m. or other peak hours consistent with the average hours used in calculations in the current Resource Adequacy proceeding, R.09-10-032,⁴ or a successor Resource Adequacy proceeding.

Each utility's summary tables shall include two sets of ex ante load impact estimated tables for each Demand Response resource program: "program-specific" load impact estimates that would occur if events are called only under that program; and "portfolio basis" load impact estimates that would be attributed to that program if simultaneous events were called under all programs. All utility demand response programs must appear in the Summary Table, and shall be divided into five categories:⁵ Emergency Programs, Price Responsive Programs, Demand Response Aggregator Managed Programs, Demand Response Enabled Programs, and Non-Event Based Resource(s). The list in the Summary Table need not be identical to those contained in the utility's demand response monthly reports. The demand response programs for which summary tables shall be provided include, but are not limited to, the following:

PG&E	SCE	SDG&E
BIP	BIP - 30-Minute Option	BIP
	BIP - 15-Minute Option	OBMC
Optional Binding Mandatory Curtailment Program	OBMC	SLRP
Smart AC - Residential	SDP-Based: Resid.	Summer Saver
Smart AC - Commercial	SDP-Based: Comm.	DBP - Day Of
AMP	SDP-Enhanced: Resid.	DBP - Day Ahead
DWR	SDP-Enhanced: Comm.	CBP - Day Of
	AP-I	CBP - Day Ahead
DBP - Day Of	DBP - Day Of	CPP-D
DBP - Day Ahead	DBP - Day Ahead	CPP-V
	CBP - Day Of	CPP-Emergency
CBP - Day Of	CBP - Day Ahead	PLP
CBP - Day Ahead	CPP-VCD	PTR with Enabling Technology
Smart Rate - Commercial	CPP-GCCD	PTR without Enabling Technology
Smart Rate - Residential	CPP-Default
Peak Day Pricing/CPP	DR Contracts
Permanent Load Shift	RTP
Peak Choice: Best Effort Day Ahead (1 & 2 Days)	SLRP
Peak Choice: Best Effort Day-Of (30 min. & 4.5 hrs)	PTR with Enabling Technology
Peak Choice: Committed Day Ahead (1 & 2 Day)	PTR without Enabling Technology
Peak Choice: Committed Day-Of (30 min. & 4.5 hrs)
SLRP
PTR with Enabling Technology
PTR without Enabling Technology
TOU

The template used for the Summary Table shall be the following:

DR Programs

Jan.

Feb.

Mar.

Apr.

May.

Jun.

Jul.

Aug.

Sept.

Oct.

Nov.

Dec.

:

:

Sub. Total, Emergency Prog.

:

:

Sub. Total, Price Responsive Prog.

:

:

Sub. Total, DR Aggregator Managed Prog.

:

:

Sub. Total, DR Enabled Prog.

:

:

Sub. Total, Non Event Based Resource

GRAND TOTAL, ALL DR PROGRAMS

(END OF APPENDIX 1)

³ Coefficients for individual customers are unnecessary.

⁴ Proposal to change average hours from 4 p.m.-9 p.m. for January - March and
November - December; and 1 p.m.-6 p.m. for April -October.

⁵ Decision 09-08-027 at 210.