7. Required Elements and Format of Long-Term Plans

Each of the three resource plans (high-, medium-, and low-load) should be documented in detail. This section provides an outline of what is expected for this documentation. In preparing this documentation, only the base case (medium load level) should be described at this level of detail for both the service area and load pocket variants of deliverability requirements. The high- and low-load resource plans need not be documented in this full detail. Instead an abbreviated summary of the differences between the load pocket variant relative to the service area variant is acceptable.

7.1. Documentation of Assumptions

For demand-side aspects of each scenario, each resource plan should describe in detail, for each of the following elements, the methodology and assumptions used for the following demand-side elements:

· Energy efficiency program impacts. Describe committed versus uncommitted annual energy and peak impacts.

· Demand Response programs and tariffs. Describe which programs are net from the demand forecast, and the annual peak impact by program.

· Self -generation/distributed generation

· Other loss of load

Each of the three resource plans should also document assumptions regarding supply resources, both existing and generic, and market conditions:

· The availability and operating characteristics of existing utility-owned generation

· Energy available from utility-owned or -controlled hydro units

· Energy from QF contracts, cost of energy from fixed-price QF contracts

· Energy, dependable capacity from existing and future RPS contracts; cost of energy from same

· Costs of and revenue from market sales and purchases of electricity ($/MWh)

· Natural gas prices, and thus

· Costs of energy from QF contracts whose price is indexed to a gas price

· Costs of energy from dispatchable DWR and other existing bilateral contracts whose price is indexed to a gas price.

· The operating characteristics (if necessary) and costs of generic and other new resources³ expected to meet utility needs going forward. These resources can be physical or contractual and include, but are not limited to those providing:

· baseload energy on a year-round basis

· load-following service on a year-round basis (e.g., 6x16 energy contracts)

· load-following service during high load periods (e.g., 6x16 energy contracts for Q3)

· peaking energy (e.g., 5x8) or capacity for Q3

The following data products should be submitted for each of the three resource plan scenarios. A description of each of these appears at the end of this attachment:

· Monthly capacity resource accounting tables (CRATs).

· Monthly energy balance tables.

· Hourly loads and resource utilization for the planning period.

7.2. Monthly Capacity-Resource Accounting Tables

These should be provided in an Excel spreadsheet and contain entries for each of the following:

Demand

Net Peak Demand

Total retail load (=)

Direct access (-)

Departed load (-)

Uncommitted DSM (-)

Other uncommitted programs (identify) (-)

Demand response/interruptible-curtailable programs & tariffs (-)

UFE (+)

Losses (+)

Total net peak demand

Supply

Utility-owned Generation

Thermal

Unit A⁴

Unit B

...

Total Utility-owned thermal

Hydro

Total hydro⁵

Derate for adverse conditions⁶

Total derated hydro

Total Utility-owned generation

Supply-side distributed generation (if any)

Projected supply-side DG

QF Contracts

Expiring prior to 1/1/06, assumed renewed for 5 years⁷

Expiring after 1/1/06

Total QF

DWR Contracts

Contract A

Contract B

.....

Total DWR Contracts

RPS Contracts

Existing (signed under interim procurement)

Projected

Total RPS Contracts

Other Existing Bilateral Contracts

Contract A

Contract B

...

Total Existing Bilateral Contracts

Necessary Additional Resources^{8 9}

Baseload energy resource A (describe)

.....

Shoulder/peaking energy resource A (describe)

.....

(Super) peaking capacity resource A (describe)

.....

Total additional resources

Total Capacity

7.3. Monthly Energy Balance Tables

The monthly energy balance tables should follow the format of the capacity-resource account table, with the following modifications:

1. QF energy should be divided into renewable and non-renewable components. The renewable component, if necessary, should be sub-divided into "RPS-eligible" and RPS-ineligible." The non-renewable component should be divided into "Expiring/renewed" and "Expiring after 1/1/06" as in the CRAT.

2. DWR Contracts should be divided into "must-take" and "dispatchable" components.

3. Market sales and market purchases should be indicated.

4. Any energy purchases specifically tied to a transmission system upgrade should be specifically identified.

7.4. Hourly Load and Resource Utilization

Entries on the demand side should include:

· Utility Load with losses & UFE, net of departed load

· Direct Access with losses

· Demand Response/Interruptible curtailable reductions to load

Hourly generation should be specified for

· Utility-owned thermal plants

· Utility-owned or controlled hydro (aggregate)

· QFs (aggregate)

· DWR contracts

· must-take energy (aggregate)

· energy from dispatchable contracts (aggregate)

· RPS contracts

· existing contracts (aggregate)

· generic (projected) contracts (aggregate)

· Other (existing) bilateral contracts (individually)

· Other new resources (individually)

· Market sales/purchases

While the utilities are not being asked to submit detailed data for the scenarios that involve the remaining load forecasts (95% growth, high CCA, etc.), they should submit the hourly loads that make up each of the forecasts for which resource plans have been requested. These should be submitted in Excel format and contain the following entries:

· Utility Load with losses & UFE, net of departed load

· Direct Access with losses

· Total (A-B)

7.5. Data for Transmission System Upgrades

For any transmission system upgrades the following items should be documented:

_ Description of the upgrade, including terminus interconnections and general nature of the route

_ Purpose of line (facilitating generation inter-connection, accessing economic imports, or reduction of local market power)

_ Transfer capability using the range of conventional transmission planning load flow conditions

_ Expected impacts on transfer capability of other components of the transmission system

_ Ballpark estimate of the investment and annual operating costs for the upgrade

_ Current status of the planning and desired on-line date

_ If the project is a significant element in the resource scenario, explain how it functions as part of a balance portfolio

7.6. Data for Cost, Market Price, Natural Gas and Cost Sensitivities

D.04-01-050 asks the utilities to consider gas prices and market prices for electricity at the 95^th percentile of expected future prices. In addition to providing estimates of the resulting increase in cost of meeting load under these assumptions, the utilities should provide the gas prices and market prices that correspond to the 95^th percentile. The utilities should submit a simple comparison of these price series to the base case assumptions. For gas prices, these should include monthly average prices. For the market price for electricity, these should include monthly prices and be divided into peak and non-peak periods.

D.04-01-050 asks the utilities to provide estimates of the total costs of the scenarios, both at the expected level and at the 95^th percentile of expected cost levels. We ask that the utilities calculate those costs in terms of Present Value of Revenue Requirement for each of the three Long-Term Plan scenarios and for each of the reported resource strategies for those Plans.

7.7. Overview of Scenarios and Documentation Requirements

Respondents are required to analyze and document a large number of scenarios. The following table identifies these scenarios and the nature of the documentation appropriate to each.

Analyses and Documentation for Load Forecasts and Resource Plans

Analytic Cases	Variant 1	Variant 2
a. Load Forecast Cases	Slow Planning Reserve Margin Phase-In (SPP)	Fast PlanningReserve Margin Phase-In (FPP)
IEPR Case	Analysis: complete load forecast and SPP reserves Reporting: See Section 2.3	Analysis: complete load forecast and FPP reserves Reporting: See Section 2.3
Alt Base Case	Analysis: complete load forecast and SPP reserves Reporting: See Section 2.3	Analysis: complete load forecast and FPP reserves Reporting: See Section 2.3
95th% Case	Analysis: complete load forecast and SPP reserves Reporting: See Section 2.3	Analysis: complete load forecast and FPP reserves Reporting: See Section 2.3
CCA Case	Analysis: complete load forecast and SPP reserves Reporting: See Section 2.3	Analysis: complete load forecast and FPP reserves Reporting: See Section 2.3
16 Core/Non-Core Cases	Analysis: 16 complete load forecast and each of their SPP reserves Reporting: See Section 2.3	Analysis: 16 complete load forecasts and each of their FPP reserves Reporting: See Section 2.3
Other IOU Defined Cases	Analysis: complete load forecast and SPP reserves for each IOU-defined case Reporting: See Section 2.3	Analysis: complete load forecast and FPP reserves for each IOU-defined case Reporting: See Section 2.3

b. Resource Plan Cases	Service Area Deliverability	Load Pocket Deliverability
Medium-load	Analysis: Complete resource plan with two variations: (1) DWR contracts fully deliverable and (2) DWR contracts based on utility's assessment of actual deliverability Reporting: Full detail	Analysis: Complete resource plan Reporting: Full detail
Low-load	Analysis: Complete resource plan Reporting: Abbreviated relative to ML/SAD	Analysis: Complete resource plan Reporting: Abbreviated relative to ML/LPD
High-load	Analysis: Complete resource plan Reporting: Abbreviated relative to ML/SAD	Analysis: Complete resource plan Reporting: Abbreviated relative to ML/LPD

(END OF APPENDIX A)

APPENDIX B

PROCEDURAL GROUND RULES FOR HEARINGS

Exhibit Format

See Rule 70 of the Rules of Practice and Procedure. Parties often fail to provide a blank space two inches high by four inches wide to accommodate the ALJ's exhibit stamp. If necessary, add a cover sheet to the front of the exhibit. The common practice of pre-printing the docket number, a blank line for the exhibit number, and witness names(s) is acceptable, but it is not a substitute for the required two by four inch blank space to accommodate the exhibit stamp.

Exhibits should be bound on the left side or upper left-hand corner. Rubber bands and paper clips are not acceptable.

Excerpts from lengthy documents should include the title page and, if necessary for context, the table of contents of the document.

While Rule 2 permits a type size of no smaller than 10 points in filed documents, parties are asked to use a type face of no smaller than 12 points wherever practicable.

Exhibit Copies

See Rule 71. The original and one copy of each exhibit shall be furnished to the presiding officer and a copy of each shall be furnished to the reporter and to each party. The copy furnished to the presiding officer may be the mailed copy. Except for exhibits that are served prior to the hearing, parties are responsible for having sufficient copies available in the hearing room for each party in attendance.

Cross-Examination Exhibits

Allowing witnesses time to review new or unfamiliar documents wastes hearing time. The general rule is that a party who intends to introduce an

exhibit in the course of cross-examination should provide a copy to the witness and the witness' counsel before the witness takes the stand on the day the exhibit is to be introduced. Documents in excess of two pages should be provided the day before. Generally, parties need not provide advance copies of documents to be used for impeachment or to obtain the witness' spontaneous reaction (although this practice is not encouraged).

Corrections

Generally, corrections to an exhibit should be made in advance and not orally from the witness stand. Corrections should be made in a timely manner by providing new exhibit pages on which corrections appear. The original text to be deleted should be lined out with the substitute or added text shown above or inserted. Each correction page should be marked with the word "revised" and the revision date.

Hearing Hours

Hearings will generally run from 9:00 a.m. to 12:00 p.m., with two morning breaks and from 1:30 p.m. to 3:30 p.m., with one afternoon break. Upon request, and assuming that hearings appear to be on schedule, hearings may run from 9:00 a.m. to 1:00 p.m., on Fridays.

Cross-Examination Time

Parties are placed on notice that it may be necessary to limit and allocate cross-examination time as well as time for redirect and re-cross-examination.

Rebuttal Testimony

Prepared rebuttal testimony should include appropriate references to the testimony being rebutted. It is inappropriate, and a potential grounds for

striking, for any party to hold back direct presentations for introduction in rebuttal testimony.

Court Reporters

Common courtesy should always be extended to the reporters. Counsel should wait for witnesses to finish their answers, and witnesses should likewise wait for the whole question to be asked before answering. Counsel shall refrain from simultaneous arguments on motions and objections. Conversations at the counsel table or in the audience can be distracting to the reporter and other participants. Such distractions should be avoided.

(END OF APPENDIX B)

CERTIFICATE OF SERVICE

I certify that I have by mail, and by electronic mail to the parties to which an electronic mail address has been provided, this day served a true copy of the original attached Assigned Commissioner's Ruling and Scoping Memo on all parties of record in this proceeding or their attorneys of record.

Dated June 4, 2004, at San Francisco, California.

/s/ FANNIE SID

Fannie Sid

NOTICE

Parties should notify the Process Office, Public Utilities Commission, 505 Van Ness Avenue, Room 2000, San Francisco, CA 94102, of any change of address to insure that they continue to receive documents. You must indicate the proceeding number on the service list on which your name appears.

* * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * *

The Commission's policy is to schedule hearings (meetings, workshops, etc.) in locations that are accessible to people with disabilities. To verify that a particular location is accessible, call: Calendar Clerk (415) 703-1203.

If specialized accommodations for the disabled are needed, e.g., sign language interpreters, those making the arrangements must call the Public Advisor at (415) 703-2074 or TTY# 1-866-836-7825 or (415) 703-5282 at least three working days in advance of the event.

³ This includes specific, known resources upon which the utility relies in the scenario, e.g., Palomar, if assumed in a scenario submitted by SDG&E.

⁴ Capacity should be reduced for planned maintenance if scheduled, but not for forced outages. Derates for planned maintenance should be noted/explained in a comment in the appropriate cell.

⁵ Capacity should be based on output that can be sustained for four hours during super-peak hours for three consecutive days under normal hydro conditions.

⁶ Adjustment given adverse (1-in-10 year) hydro conditions.

⁷ If resource plan assumes that any or all of the non-renewable QF contracts expiring prior to 1/1/06 are not renewed or are renewed for a period of less than five years, details should be provided in a note/comment in the spreadsheet.

⁸ The descriptions will depend upon the degree of specificity in the resource plan. For baseload energy resources, this can be a utility-owned generation resource such as a combined cycle, a 7x24 PPA, etc. Shoulder/peaking energy resources include utility -owned generation resources designed to cycle or meet (super) peak needs or 6x16 to 5x8 PPAs. (Super) peaking capacity resources are capacity contracts for 6x16 or less.

⁹ Any contractual arrangements specifically tied to a proposed transmission system upgrade should be specifically identified.