The Electric ESP Handbook - Pacific Gas and Electric Company

The Electric ESP Handbook
A GUIDE TO PACIFIC GAS &ELECTRIC COMPANY’S DIRECT ACCESS
PROCEDURES FOR ELECTRIC ENERGY SERVICE PROVIDERS
Pacific Gas and Electric Company - ESP Services
February 25, 2009

TABLE OF CONTENTS
PREFACE ............................................................................................................................................................................... 1
ABOUT THIS GUIDE............................................................................................................................................................... 1
Overview........................................................................................................................................................................... 1
Disclaimer and Warning .................................................................................................................................................. 1
Summary of Chapters and Contents ................................................................................................................................. 2
Chapter Organization....................................................................................................................................................... 2
Overview .......................................................................................................................................................................................... 2
Prerequisites ..................................................................................................................................................................................... 3
Checklist of Key Steps ..................................................................................................................................................................... 3
The [Chapter Topic] Process Illustrated ........................................................................................................................................... 3
Procedures ........................................................................................................................................................................................ 3
CHAPTER 1 ........................................................................................................................................................................... 1
ELECTRIC ESP DIRECT ACCESS PRELIMINARY PROCEDURES................................................................................................ 1
Overview........................................................................................................................................................................... 1
Prerequisites..................................................................................................................................................................... 1
Checklist of key steps........................................................................................................................................................ 2
Electric ESP Direct Access Preliminary Procedures Illustrated...................................................................................... 3
Procedures........................................................................................................................................................................ 4
1. Electric ESP obtains required documentation for Direct Access (DA) signup with PG&E ........................................................ 4
ESP Service Agreement ............................................................................................................................................................... 6
About Section 22, Billing Options ............................................................................................................................................... 6
About Section 23, Metering and Meter Reading Options ............................................................................................................ 7
Energy Service Provider Information Form ................................................................................................................................. 7
ESP Credit Application and Financial Statements ....................................................................................................................... 8
ESP creditworthiness requirements.............................................................................................................................................. 9
Credit evaluation parameters........................................................................................................................................................ 9
Primary credit requirements......................................................................................................................................................... 9
Alternate credit requirements....................................................................................................................................................... 9
Direct access consolidated billing options worksheet ................................................................................................................ 11
Instructions for completing the Direct Access Consolidated Billing Options Worksheet.......................................................... 12
Required format for the PG&E bill detail page included on Consolidated Electric ESP bills ................................................... 13
EDI Trading Partner Agreement ................................................................................................................................................ 13
Main Agreement ........................................................................................................................................................................ 13
Appendix.................................................................................................................................................................................... 14
EDI Setup Form ......................................................................................................................................................................... 16
Meter Data Management Agent (MDMA) qualification/approval............................................................................................. 17
2. Electric ESP submits completed DA startup documentation to ESP Services........................................................................... 17
3. ESP Services Representative contacts Electric ESP upon receipt of DA startup documents .................................................... 17
4. PG&E reviews all submitted DA startup documentation .......................................................................................................... 17
DA startup Documentation Review Timeline ............................................................................................................................ 18
ESP Service Agreement Processing ........................................................................................................................................... 18
ESP Credit Application processing ............................................................................................................................................ 18
Credit Acceptance ...................................................................................................................................................................... 19
Credit Denial.............................................................................................................................................................................. 19
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Direct Access Consolidated Billing Options Worksheet............................................................................................................ 19
EDI Trading Partner Agreement processing .............................................................................................................................. 19
EDI Setup Form ......................................................................................................................................................................... 19
MDMA Application and Checklist ............................................................................................................................................ 19
5. ESP Services Representative informs the Electric ESP of the type of DA participation for which it is eligible....................... 19
Information Websites...................................................................................................................................................... 21
CHAPTER 2 ......................................................................................................................................................................... 23
DIRECT ACCESS SETUP........................................................................................................................................................ 23
Overview......................................................................................................................................................................... 23
Prerequisites................................................................................................................................................................... 23
Checklist of key steps...................................................................................................................................................... 24
Direct Access Setup Illustrated....................................................................................................................................... 24
Procedures...................................................................................................................................................................... 24
Electronic data exchange synopsis ................................................................................................................................................. 25
1. Prepare systems setup for electronic data exchange .................................................................................................................. 25
2. Review electronic transfer procedures and rules as designated by PG&E for DES and EDI (if applicable)............................. 25
Data transfer specifics: How DES is used to exchange DA information ................................................................................... 26
DES implementation....................................................................................................................................................................... 26
Key DES contacts ...................................................................................................................................................................... 26
DES Web site............................................................................................................................................................................. 27
EDI data transfer............................................................................................................................................................ 27
EDI contacts ................................................................................................................................................................................... 28
For more information ................................................................................................................................................................. 28
EDI Direct Access transaction sets................................................................................................................................................. 28
Transaction set 810 - Billing ...................................................................................................................................................... 28
Transaction set 814 - Direct Access Service Request (DASR) .................................................................................................. 28
Transaction set 820 - Payment and Remittance Order ............................................................................................................... 29
867 - Meter Usage...................................................................................................................................................................... 29
997 - Functional Acknowledgment ............................................................................................................................................ 29
Test the viability and accuracy of data transferred to PG&E using DES ....................................................................................... 29
CHAPTER 3 ......................................................................................................................................................................... 31
PROCESSING DIRECT ACCESS SERVICE REQUESTS (DASRS) .............................................................................................. 31
Overview......................................................................................................................................................................... 31
Definition of Terms ........................................................................................................................................................................ 31
Prerequisites................................................................................................................................................................... 32
Checklist of key steps...................................................................................................................................................... 33
Processing DASRs Illustrated ........................................................................................................................................ 33
Procedures...................................................................................................................................................................... 35
1. Electric ESP obtains customer authorization to submit a DASR on its behalf .......................................................................... 35
2. Electric ESP obtains customer CTC Agreement, if required..................................................................................................... 35
3. Electric ESP evaluates customer DA elections and obtains customer information required to complete DASR ...................... 35
5. Electric ESP submits DASR to PG&E through DES................................................................................................................. 36
6. PG&E processes DASR............................................................................................................................................................. 36
Electronic Validation ................................................................................................................................................................. 37
DASR Validation ....................................................................................................................................................................... 37
Account Validation .................................................................................................................................................................... 37
7. PG&E sends a confirmation, rejection, or pending notification to Electric ESP....................................................................... 38
Acceptance notices..................................................................................................................................................................... 38
Rejection DASR......................................................................................................................................................................... 39
Additional DASR procedures performed by PG&E ....................................................................................................................... 39
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DASR for “New” Premises ........................................................................................................................................................ 39
Additional setup transaction procedures .................................................................................................................................... 39
Additional transaction procedures for newly established PG&E account numbers ................................................................... 40
Additional Shut Off (S/O) and Shut-off Non-Payment (SONP) transaction procedures............................................................ 41
Additional Cancellation transaction procedures......................................................................................................................... 41
Additional Customer Account Data Change transaction procedures ......................................................................................... 41
Additional procedures for Initial Customer Historical Usage Information ................................................................................ 41
Seamless Move .......................................................................................................................................................................... 42
Seamless Move Procedures ............................................................................................................................................................ 42
Canceling a Seamless Move ........................................................................................................................................................... 43
Limits to a Seamless Move Option................................................................................................................................................. 43
CHAPTER 4 ......................................................................................................................................................................... 45
DA ELECTRONIC DATA EXCHANGE CONTINGENCY PLANS................................................................................................. 45
Overview......................................................................................................................................................................... 45
Behind the scenes look at the DASR process ................................................................................................................................. 45
DASR Server Communication Illustrated ...................................................................................................................................... 46
Risks............................................................................................................................................................................................... 46
Event Scenario Back-up Plans ....................................................................................................................................... 46
Electric ESP unable to communicate with DES ............................................................................................................................. 47
Situation ..................................................................................................................................................................................... 47
Back-up Plan.............................................................................................................................................................................. 47
Failure of PG&E equipment (DASR Interface & CIS)................................................................................................................... 48
Situation ..................................................................................................................................................................................... 48
Back-up Plan.............................................................................................................................................................................. 48
CHAPTER 5 ......................................................................................................................................................................... 49
METERING........................................................................................................................................................................... 49
Overview......................................................................................................................................................................... 49
Metering Services........................................................................................................................................................................... 49
Meter Service Provider Responsibilities .................................................................................................................................... 50
Meter Installation Standards....................................................................................................................................................... 50
Effective Direct Access Date ..................................................................................................................................................... 50
Meter Maintenance .................................................................................................................................................................... 50
Meter Equipment Specifications ................................................................................................................................................ 50
Obtaining Meter Equipment Information for Existing Customer Accounts ................................................................................... 51
Web Site Test............................................................................................................................................................................. 51
Selection of the Meter Installer .................................................................................................................................................. 51
Scheduling Meter Removal and Installations - PG&E as Meter Installer .................................................................................. 51
Meters Supplied by PG&E......................................................................................................................................................... 52
Meters Supplied by Electric ESP ............................................................................................................................................... 52
DA Ready Meter ........................................................................................................................................................................ 52
Phone Service Notification - PG&E as Meter Installer.............................................................................................................. 52
Completed Meter Installs ........................................................................................................................................................... 53
Re-scheduling Meter Installations.............................................................................................................................................. 53
Scheduling Meter Removals and Installations - Electric ESP as Meter Installer............................................................................ 53
Meter Installation/Removal Notification *................................................................................................................................. 54
Return of PG&E Meters............................................................................................................................................................. 54
Service Upgrades............................................................................................................................................................................ 54
Return to Bundled Service from Direct Access and Meter Ownership .......................................................................................... 54
Electric ESP Inquiries..................................................................................................................................................................... 56
Wired Phone Line Requirements ............................................................................................................................................... 57
Wireless Phone Installation Requirements................................................................................................................................. 58
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Responsibility - Phone Service Account Payment.......................................................................................................................... 59
Responsibility - Phone Service Operability and Maintenance........................................................................................................ 59
Retention of Rights......................................................................................................................................................................... 60
Meter Data Management Agent (MDMA) Requirements ............................................................................................... 60
MDMA Approval Process and Requirements ................................................................................................................................ 60
Application and Checklist .......................................................................................................................................................... 61
Written Requirements ................................................................................................................................................................ 61
Server Acceptance Test.............................................................................................................................................................. 61
Back-up Reading Process........................................................................................................................................................... 62
Data Format................................................................................................................................................................................ 62
Security and Confidentiality ...................................................................................................................................................... 62
Help Desk................................................................................................................................................................................... 62
Validating and Editing Data ........................................................................................................................................................... 63
Interval Data............................................................................................................................................................................... 63
Estimating Data .............................................................................................................................................................................. 64
Interval Data Estimation Rules .................................................................................................................................................. 64
Accuracy and Timeliness of Usage Data........................................................................................................................................ 64
Interval Data............................................................................................................................................................................... 65
Monthly Data ............................................................................................................................................................................. 65
Data retention period ...................................................................................................................................................................... 65
Electronic exchange of metering data............................................................................................................................................. 65
Interval and Time-Of-Use (TOU) data....................................................................................................................................... 66
Meter Reading ................................................................................................................................................................................ 67
Meter reading data obligations................................................................................................................................................... 67
PG&E meter reading.................................................................................................................................................................. 67
Electric ESP meter reading ........................................................................................................................................................ 68
Metered Usage Rates...................................................................................................................................................... 68
Life Support Customers and Medical Baseline Quantities ............................................................................................................. 68
CHAPTER 6 ......................................................................................................................................................................... 71
DASR PROCESSES FOR METERING DATA ADJUSTMENTS AND CHANGES............................................................................ 71
Overview......................................................................................................................................................................... 71
DA Account Commodity Status Changes........................................................................................................................ 72
DA Account Commodity Shut-Offs ............................................................................................................................................... 72
Process ....................................................................................................................................................................................... 72
Matrix of PG&E-initiated Records Related to Shut-offs by Meter Type ................................................................................... 72
Example ..................................................................................................................................................................................... 74
Meter Change ................................................................................................................................................................................. 75
Matrix of PG&E-initiated Records Related to Meter Change.................................................................................................... 75
Example ..................................................................................................................................................................................... 78
New Meter Sets Which are not Concurrent with Old Meter Removals...................................................................................... 78
Meter Configuration Data .......................................................................................................................................................... 79
Usage Adjustments ......................................................................................................................................................... 79
Usage Adjustments to Monthly Meter Data Due to Additional Validation Checking of Data when PG&E is the MDMA ...... 80
Matrix of PG&E-initiated Records Related to Usage Adjustments............................................................................................ 80
Example ..................................................................................................................................................................................... 82
Stand Alone Rebate transactions (reversal only adjustment) ..................................................................................................... 83
CHAPTER 7 ......................................................................................................................................................................... 85
ELECTRIC ESP ACCOUNT BILLING ...................................................................................................................................... 85
Overview......................................................................................................................................................................... 85
Bill Components and Billing Options............................................................................................................................. 85
Summary of bill components.......................................................................................................................................................... 85
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About the California Energy Commission Tax .............................................................................................................................. 86
Billing options ................................................................................................................................................................................ 87
Consolidated UDC billing.......................................................................................................................................................... 87
Consolidated ESP billing ........................................................................................................................................................... 87
Partial Consolidated ESP Billing ............................................................................................................................................... 87
Full Consolidated ESP Billing ................................................................................................................................................... 87
Separate billing .......................................................................................................................................................................... 88
Read and Bill Serial Dates.............................................................................................................................................................. 88
Consolidated UDC Billing.............................................................................................................................................. 88
Pricing options................................................................................................................................................................................ 89
Flat ($/month) ............................................................................................................................................................................ 90
Single-tiered ($/kWh)................................................................................................................................................................. 90
Double-Tiered ($/kWh, Electric ESP designates tiers) .............................................................................................................. 90
Time-of-Use - TOU ($/kWh, based on PG&E’s tiers) ............................................................................................................... 90
Custom pricing........................................................................................................................................................................... 91
Submitting Rate-ready data to PG&E ........................................................................................................................................ 91
Deadlines for the submission of rate-ready data ........................................................................................................................ 91
Bill format ...................................................................................................................................................................................... 91
Bill preparation and processing ...................................................................................................................................................... 91
Bill Printing and Delivery .............................................................................................................................................................. 92
Reports generated by PG&E........................................................................................................................................................... 92
Utility User Tax Application .......................................................................................................................................................... 92
How PG&E calculates Electric ESP payments............................................................................................................................... 93
When PG&E pays the Electric ESP ........................................................................................................................................... 91
I. PG&E payments to Electric ESP and supporting reports: ..................................................................................................... 91
II. When PG&E makes payment to Electric ESP....................................................................................................................... 91
III. Reserve against collections .................................................................................................................................................. 93
Payments from Electric ESP to PG&E....................................................................................................................................... 93
Consolidated ESP Billing ............................................................................................................................................... 93
Bill format requirements ............................................................................................................................................................ 93
Calculation of charges owed to PG&E....................................................................................................................................... 94
Payment Processing ................................................................................................................................................................... 94
Electronic Data Interchange (EDI)............................................................................................................................................. 94
Separate Billing Procedures........................................................................................................................................... 94
CHAPTER 8 ......................................................................................................................................................................... 95
CUSTOMER INFORMATION RELEASES .................................................................................................................................. 95
Overview......................................................................................................................................................................... 95
Confidential Customer Information Release .................................................................................................................. 95
GLOSSARY .......................................................................................................................................................................... 97
DIRECT ACCESS TERMS....................................................................................................................................................... 97
APPENDIX A ..................................................................................................................................................................... 103
SERVICE TERRITORY CITY CODES..................................................................................................................................... 103
APPENDIX B...................................................................................................................................................................... 121
SERVICE CITY ZIP CODES.................................................................................................................................................. 121
APPENDIX C ..................................................................................................................................................................... 135
DA APPROVED METERS .................................................................................................................................................... 135
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P REFACE
ABOUT THIS GUIDE
Overview
The ESP (Energy Service Provider) Services organization within PG&E, a group dedicated to providing
information and guidance to ESPs, has compiled information in this document which will assist ESPs
with preparing to do business under Direct Access (DA). This information reflects the latest California
Public Utilities Commission (CPUC) decisions on DA. Please note that content of this document is
subject to change over time as the CPUC issues further decisions relevant to DA.
Disclaimer and Warning
PG&E has provided these guidelines for informational purposes only.
In the event of any conflict between the guidelines contained within this handbook and the DA tariffs and
Energy Service Provider Service Agreement approved by the CPUC, the tariff and the Energy Service
Provider Service Agreement shall control.
The procedures adopted for other California utilities may differ from those of PG&E.
Note that the DA Suspension Decision (D.) 02-03-055, dated March 21, 2002, issued by the California
Public Utilities Commission, may have an impact on the qualification of customers for participation in
DA.
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Summary of Chapters and Contents
• Chapter 1: Electric ESP Direct Access Preliminary Procedures - discusses the preliminary
documentation which needs to be signed and sent to PG&E prior to the submission of Direct Access
Service Requests (DASRs).
• Chapter 2: Direct Access Setup - covers information about electronic information exchange setup
requirements under DA.
• Chapter 3: Processing Direct Access Service Requests (DASRs) - discusses how Electric ESPs
electronically communicate service requests related to DA to PG&E.
• Chapter 4: DA Electronic Data Exchange Contingency Plans - discusses contingency plans for
the handling of DASRs should one or more elements of electronic DASR processing fail.
• Chapter 5: Metering - covers DA interval metering issues including the prioritization and
forecasting of installation requests; phone service quality and billing requirements; and customer
service for Electric ESPs.
• Chapter 6: DASR Processes for Metering Data Adjustments and Changes - provides Electric
ESPs with information on PG&E DASR processes related to metering data adjustments and DA
account commodity status changes.
• Chapter 7: Electric ESP Account Billing - contains information on the billing options which
Electric ESPs can offer to their DA customers.
• Chapter 8: Customer Information Releases - details the types of customer information which
Electric ESPs can obtain from PG&E.
Chapter Organization
Overview
Chapters 1 through 3, which describe sequential, step-by-step procedures, follow a consistent
organizational format as described below.
This section, which provides an overview of the chapter topic material and related processes, emphasizes
the most important concepts within the chapter.
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Prerequisites
Checklist of Key Steps
The prerequisites to the procedures covered in the chapter are detailed, ensuring that the Electric ESP is
ready for the steps to follow.
Key process steps are briefly described within a checklist format which identifies critical elements.
The [Chapter Topic] Process Illustrated
Procedures
Visuals are an effective way to convey process information. When appropriate conceptual-level flow
diagrams have been included to illustrate main process steps.
This section provides a detailed discussion of items identified within the Checklist of Key Steps.
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C HAPTER 1
ELECTRIC ESP DIRECT ACCESS
PRELIMINARY PROCEDURES
Overview
Prerequisites
This chapter focuses primarily on the types of documents which Electric ESPs will need to submit prior
to participation in Direct Access (DA). The chapter also discusses the timing involved with reviewing
and processing the documentation submitted by Electric ESPs.
Prior to starting DA preliminary procedures, an Electric ESP must register with the CPUC if it intends to
serve “Small Customers.” Small Customers are defined per revised Rule 1 as customers on demandmetered
schedules (A-10 and E-19V), with less than 50kW maximum billing demand per meter for at
least nine (9) billing periods during the most recent twelve (12) month period or any customer on a nondemand
metered schedule (A-1 and A-6).
Detailed information regarding registering with the CPUC can be obtained by visiting the CPUC Web
site (see Information Websites at the end of Chapter 1 in this handbook).

Checklist of key steps
# STEP
1. Electric ESP obtains required documentation for Direct Access (DA) signup with
PG&E
2. Electric ESP submits completed DA startup documentation to ESP Services
3. ESP Services Representative contacts Electric ESP upon receipt of DA startup
documentation
4. PG&E reviews all submitted DA forms and documentation
5. ESP Services Representative informs the Electric ESP of the type of DA
participation for which it is eligible
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Electric ESP Direct Access Preliminary Procedures
Illustrated
ESP obtains required
documentation for Direct Access
(DA) signup with PG&E
ESP submits completed DA startup
documentation to ESP Relations
ESP Relations Representative
contacts ESP upon receipt of DA
startup documentation
PG&E reviews and executes
ESP Service Agreement and
conducts a quick review of the
ESP Credit Application
Does ESP plan to offer
Consolidated ESP billing?
No
ESP is eligible to participate in DA
and offer Separate billing.
Yes
PG&E reviews startup
documentation required for
Consolidated ESP billing
PG&E processes
Direct Access
Consolidated Billing
Options Worksheet
PG&E processes
EDI Trading
Partner Agreement
PG&E processes
EDI Setup Form
PG&E evaluates
ESP Credit
Application
Is ESP's credit
approved?
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Yes
PG&E informs ESP
that it can offer
ESP-Consolidated
billing option.
Activation pending
ESP's fulfillment of
EDI systems
requirements
No
PG&E informs
ESP that it
cannot offer
Consolidated
ESP billing

Procedures
This section provides a detailed discussion of the process steps outlined within the Checklist of Key
Steps.
1. Electric ESP obtains required documentation for Direct Access (DA) signup
with PG&E
Electric ESPs interested in participating in DA with PG&E will need to complete and execute the forms
indicated in the DA Forms Table below. Information on filling out the DA forms is provided in the
sections following the DA Forms Table.
DA startup forms can either be downloaded from the “DA Documents” link on the ESP Resource Center
website (see Information Websites at the end of Chapter 1 in this handbook) or obtained from PG&E’s
ESP Services.
Electric ESPs may also contact ESP Services via the ESP Services hotline at 415-973-1666, should they
have any questions regarding the DA forms.
DA FORMS TABLE
# DOCUMENT DESCRIPTION WHEN REQUIRED
1. Energy Service
Provider Service
Agreement (the “ESP
Service Agreement”)
2. Energy Service
Provider information
3. ESP Credit Application
and Electric ESP’s
financial statements
This document specifies the roles and
responsibilities of both the Electric ESP
and PG&E with respect to DA business
transactions and interactions which
transpire between the two parties. Note
that the content of the ESP Service
Agreement may be amended from time to
time at the direction of the CPUC.
Document which asks for detailed
information about the Electric ESP which
is not included within the ESP Service
Agreement.
PG&E uses the Electric ESP’s Credit
Application and financial statements to
evaluate the credit worthiness of the
Electric ESP.
Always
Always
Always
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# DOCUMENT DESCRIPTION WHEN REQUIRED
4. Direct Access
Consolidated Billing
Options Worksheet
5. EDI Trading Partner
Agreement
This form specifies the services and other
information related to the selection of
billing options. The form also serves as
an authorization for PG&E to commence
preparations which are necessary to
establish the billing options selected by
the Electric ESP.
The primary purpose of the agreement is
to establish the binding nature of financial
charge and payment data which is
transmitted electronically between the
Electric ESP and PG&E. The agreement
also specifies that data be exchanged in
accordance with the American National
Standards Institute (ANSI) Business
Interchange Standards, which is currently
ANSI X12.
6. EDI Setup Form This form specifies EDI systems details
relevant to the electronic transmission of
financial charge and payment data.
7. MDMA Approval
Application and
Checklist
Forms required to apply for approval as an
MDMA.
If the Electric ESP plans
to offer Consolidated ESP
and/or Consolidated UDC
billing
If the Electric ESP plans
to offer the Consolidated
ESP billing option
If the Electric ESP plans
to offer the Consolidated
ESP billing option
If the Electric ESP plans
to provide MDMA
services.
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ESP SERVICE AGREEMENT
The following exhibit shows the first page of the ESP Service Agreement.
1.1 - ESP SERVICE AGREEMENT (PAGE 1 OF 16)
ABOUT SECTION 22, BILLING OPTIONS
The Electric ESP’s selection of the Consolidated ESP billing option is contingent upon meeting DA tariff
creditworthiness requirements and EDI requirements. EDI requirements include submission of the EDI
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Trading Partner Agreement and EDI Setup Form as well as satisfactory systems capability for EDI
transaction exchange.
Creditworthiness requirements are discussed in the subsequent section, ESP Credit Application and
Financial Statements.
EDI testing procedures and detail on EDI protocol are covered within Chapter 2: Direct Access Setup.
ABOUT SECTION 23, METERING AND METER READING OPTIONS
If the Electric ESP has indicated that it will be offering all or some metering and meter reading services
to its customers, it will need to meet the established requirements for the types of services it plans to
offer. Electric ESPs should consult Chapter 5: Metering of this handbook for a synopsis of guidelines.
Failure to meet established Meter Service Provider (MSP) or Meter Data Management Agent (MDMA)
requirements prior to submitting Direct Access Service Requests (DASRs) can result in delayed DASR
processing or rejection.
ENERGY SERVICE PROVIDER INFORMATION FORM
This form addresses additional information about the Electric ESP which is not specified within the ESP
Service Agreement. Types of information include the Electric ESP’s emergency contact telephone
numbers, business hours, time zone, additional key functional contacts, etc. PG&E’s ESP Services group
in turn uses this information to better tailor the customer services it provides to Electric ESPs.
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ESP CREDIT APPLICATION AND FINANCIAL STATEMENTS
The following shows the first page of the ESP Credit Application.
1.2 - ESP CREDIT APPLICATION (PAGE 1 OF 2)
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All Electric ESPs interested in participating in DA with PG&E must complete the ESP Credit
Application and submit a set of financial statements pursuant to the specifications of the ESP Credit
Application.
ESP CREDITWORTHINESS REQUIREMENTS
Electric ESPs planning to offer Consolidated ESP billing to end-use customers must meet DA tariff
creditworthiness requirements. Electric ESPs who plan to offer either UDC Consolidated or Separate
billing to end-use customers may also be subject to creditworthiness requirements. In some cases, PG&E
will require Separate billing for Electric ESPs who fail to meet creditworthiness requirements.
Additionally, PG&E may require advance payment of authorized service fees for Electric ESPs who offer
either UDC Consolidated or Separate billing.
CREDIT EVALUATION PARAMETERS
Electric ESPs who satisfy primary or alternate creditworthiness requirements as described below may
offer Consolidated ESP billing to end-use customers. The parameters for credit evaluations and security
deposits are summarized below. Electric ESPs should consult PG&E’s DA Rule 22, Section N for
comprehensive details regarding credit evaluation provisions.
PRIMARY CREDIT REQUIREMENTS
PG&E will consider an Electric ESP creditworthy if it has obtained a credit rating of either:
• Baa2 or higher from Moody’s
• BBB or higher from Standard & Poor’s, Fitch, or Duff & Phelps
The credit evaluation may be conducted by an outside credit analysis agency, as determined by PG&E.
ALTERNATE CREDIT REQUIREMENTS
Electric ESPs may provide credit security in lieu of satisfying the unsecured credit requirements outlined
above. The amount of the security required to establish credit will be twice the estimated maximum
monthly bill for PG&E charges.
With PG&E’s approval, credit security may be in the form of any of the following:
1. Cash deposit
2. Letter of credit
3. Surety bond
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4. Guarantee, with the guarantor having a credit rating of
• Baa2 or higher from Moody’s
• BBB or higher from Standard & Poor’s, Fitch, or Duff & Phelps
Electric ESPs can download PG&E’s Guarantee document from the ESP Resource Center website (see
Information Websites at the end of Chapter 1 in this handbook) or can be obtained by calling the ESP
Services hotline at 415-973-1666.
The following exhibit is an example of the first page of PG&E’s Corporate Guarantee document.
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1.3 – CORPORATE GUARANTEE (PAGE 1 OF 4)
DIRECT ACCESS CONSOLIDATED BILLING OPTIONS WORKSHEET
The following shows the first page of the Direct Access Consolidated Billing Options Worksheet.
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1.4 - DIRECT ACCESS CONSOLIDATED BILLING OPTIONS WORKSHEET (PAGE 1 OF 2)
INSTRUCTIONS FOR COMPLETING THE DIRECT ACCESS CONSOLIDATED BILLING
OPTIONS WORKSHEET
Specifications made by the Electric ESP on this worksheet will determine the bill format that is generated
for Consolidated ESP and Consolidated UDC invoices to end-use customers.
1. Electric ESPs will need to mark the checkbox(es) for the consolidated billing option(s) that
it plans to provide.
2. For each consolidated billing option section, the Electric ESP indicates the additional
options that it would like PG&E to provide.
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3. As some services are exclusive of others, the Electric ESP should only select one option
where indicated.
REQUIRED FORMAT FOR THE PG&E BILL DETAIL PAGE INCLUDED ON CONSOLIDATED
ELECTRIC ESP BILLS
Electric ESPs who plan to offer the Consolidated ESP billing option should be aware of PG&E’s
requirements for the format of the PG&E bill detail page. Detailed information and examples of PG&E’s
bill format requirements are addressed within Chapter 7: Billing, under the section heading Consolidated
UDC Billing.
EDI TRADING PARTNER AGREEMENT
The following shows the first page of the EDI Trading Partner Agreement.
The EDI Trading Partner Agreement consists of the main agreement text and an Appendix to the
agreement. The Electric ESP will need to complete sections within both the EDI Trading Partner
Agreement and the Appendix to the agreement as indicated below.
MAIN AGREEMENT
In section 5.0 under Trade Partner, the ESP corporate representative signs on the signature line and
provides their printed name, title, and date on the appropriate lines.
The following shows the first page of the EDI Trading Partner Agreement.
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1.5 - ELECTRONIC DATA INTERCHANGE (EDI) TRADING PARTNER AGREEMENT (PAGE 1 OF 7)
APPENDIX
The following shows the first page of the Appendix to the EDI Trading Partner Agreement. The
Appendix is a part of the EDI Trading Partner Agreement document.
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1.6 - APPENDIX TO THE EDI TRADING PARTNER AGREEMENT
1. Under the Documents section, list any electronic transactions which will be performed. For
Consolidated ESP billing, these transactions will include 810 (invoice), 820 (send and remit
payment), and 997 (acknowledgment). Since the 810, 820, and 997 transactions are currently the
most common, they have been included on the Appendix.
2. Under the Third Party Service Providers section, specify the Electric ESP’s legal, business name,
address, and telephone number.
3. Under the Security Procedures section, describe any security procedures with respect to the
transmission of documents.
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4. Under the Existing Agreements section, the Electric ESP will need to list any special conditions and
agreements which may impact how the exchange of Consolidated ESP billing information must be
handled.
EDI SETUP FORM
The following shows the EDI Setup Form.
1.7 - EDI SETUP FORM
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In order to initiate EDI setup with PG&E, the Electric ESP will need to complete the EDI Setup Form,
indicating EDI contacts, Value Added Network (VAN), version, supported transaction sets, value added
service bank, bank transit routing number, bank account number, etc.
METER DATA MANAGEMENT AGENT (MDMA) QUALIFICATION/APPROVAL
Electric ESPs who wish to provide MDMA services or use the services of an MDMA other than PG&E
will need to have their prospective MDMA complete and submit the PG&E’s Application for MDMA
Approval and MDMA Approval Checklist to ESP Services by fax (415-973-8494) or mail (see next
section). The application and checklist are available through the “DA Documents” link on the ESP
Resource Center website (see Information Websites at the end of Chapter 1 in this handbook). The name
of the document is “MDMA Qualification Instructions”. For detailed information on the MDMA
approval process, see the section Meter Data Management Agent (MDMA) Requirements in Chapter 5:
Metering.
2. Electric ESP submits completed DA startup documentation to ESP Services
Electric ESPs will need to submit two (2) sets of completed and executed DA forms, with original
signatures, as well as one set of financial statements, to PG&E at the following address:
ESP Services
Yolanda Lerma
Pacific Gas and Electric Company
77 Beale Street
P.O. Box 770000
M/C B19C
San Francisco, CA 94177
3. ESP Services Representative contacts Electric ESP upon receipt of DA
startup documents
ESP Services reviews every set of DA startup documentation received from Electric ESPs to ensure that
all information required for the level of service that the Electric ESP intends to offer to its end-use
customers has been provided. An ESP Services Representative will contact the Electric ESP upon receipt
of the DA startup documentation package to discuss the next steps related to DA participation, such as
the submission of DASRs, or to request additional information from the Electric ESP.
4. PG&E reviews all submitted DA startup documentation
The sections below describe PG&E’s role in reviewing the DA forms and documents, which the Electric
ESP has submitted. The first section provides a process timeline and is followed by sections describing
how PG&E handles each type of DA document.
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DA STARTUP DOCUMENTATION REVIEW TIMELINE
The timeline below illustrates the amount of time that an Electric ESP should expect for the review of
DA documents submitted to PG&E. Under normal conditions, PG&E will ensure that document
processing takes place within the time allowances indicated below. Electric ESPs should use the timeline
to assist with the planning of their DA roll-out.
Day 1 on the timeline represents the day that ESP Services receives the DA documentation package from
the Electric ESP. Timely processing of the ESP Service Agreement, ESP Credit Application, and EDI
forms is contingent upon PG&E receiving all completed required documents from the Electric ESP.
ESP SERVICE AGREEMENT PROCESSING
1. Under normal conditions, PG&E will execute the ESP Service Agreement within two business days
of receipt.
2. PG&E will forward one of the fully executed ESP Service Agreement documents to the Electric ESP
at the address indicated within Section 13.1 of the agreement.
ESP CREDIT APPLICATION PROCESSING
1. Upon receipt of the Electric ESP’s credit application and financial statements, PG&E’s Credit Risk
Management Unit (CRMU) will review the application and other required financial information (i.e.
Moody’s, D&B, audited financial statements) to determine the credit worthiness of the Electric ESP
in accordance with the provisions under PG&E’s DA Rule 22.
If the CRMU has the completed ESP Credit Application, financial statements, and any other
documentation necessary to conduct its credit evaluation of the Electric ESP, the process normally
will be completed within ten (10) business days.
2. The CRMU will advise the Electric ESP and PG&E’s ESP Services regarding the outcome of the
Electric ESP’s credit evaluation (i.e. if the Electric ESP’s credit rating is sufficient, or if PG&E will
require additional security).
3. Once ESP Services has been informed that the Electric ESP’s credit has been either approved or
denied, it will reflect the appropriate information in PG&E’s ESP database, which is used to validate
the DASRs PG&E receives from the Electric ESP.
4. The original credit documents (for example, credit application, financial statements, surety bond,
letter of credit or guarantee), will be maintained in a file at PG&E’s CRMU.
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CREDIT ACCEPTANCE
If the Electric ESP’s credit is approved, the Electric ESP will be eligible to offer Consolidated ESP
billing to end-use customers.
CREDIT DENIAL
If the credit requirements outlined above are not met, the Electric ESP will not be eligible to offer
Consolidated ESP billing to end-use customers until credit is established. PG&E will automatically
establish Separate billing for the Electric ESP, unless the Electric ESP requests Consolidated UDC
billing.
DIRECT ACCESS CONSOLIDATED BILLING OPTIONS WORKSHEET
PG&E will process the Direct Access Consolidated Billing Options Worksheet internally upon receipt.
EDI TRADING PARTNER AGREEMENT PROCESSING
1. PG&E will normally execute the EDI Trading Partner Agreement within two business days of
receipt.
2. PG&E will forward one of the fully executed EDI Trading Partner Agreement documents to the
Electric ESP at the address provided.
EDI SETUP FORM
PG&E will process the EDI Setup Form internally upon receipt.
MDMA APPLICATION AND CHECKLIST
PG&E will process the Application for MDMA Approval and MDMA Approval Checklist within ten
(10) days of receipt.
5. ESP Services Representative informs the Electric ESP of the type of DA
participation for which it is eligible
An ESP Services Representative will inform the Electric ESP of the type of DA participation for which it
is currently eligible. If the Electric ESP correctly completed and executed the ESP Service Agreement, it
should be able to participate in DA and offer Separate billing to its end-use customers.
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The Electric ESP will be eligible to offer Consolidated ESP billing to its customers if it has obtained
credit approval, has submitted a completed Consolidated Billing Options Worksheet, and has submitted
the EDI Trading Partner Agreement and EDI Setup Form. However, the Electric ESP will not be able to
activate Consolidated ESP billing until it has fulfilled the applicable systems requirements for EDI,
which are discussed in Chapter 3: Direct Access Setup.
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Information Websites
Electric ESPs may wish to add the following sites as “favorite” links on their web browsers for easy
access to information about PG&E’s Direct Access program.
NAME ADDRESS
PG&E Corporation WWW.PGE.COM
Electric ESP (Electric
Energy Service Provider)
Resource Center
Gas ESP (Gas Energy
Service Provider) Resource
Center
WWW.PGE.COM/ESP
WWW.PGE.COM/CTA
EDI WWW.PGE.COM/EDI
Web Tariff Book WWW.PGE.COM/TARIFFS
DES MADS.PGE.COM
CPUC WWW.CPUC.CA.GOV
California Independent
Systems Operator (CAISO)
WWW.CAISO.COM
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C HAPTER 2
DIRECT ACCESS SETUP
Overview
Prerequisites
Prior to offering DA to end-use customers through submission of a Direct Access Service Request
(DASR), the Electric ESP must satisfy certain requirements with respect to electronic data exchange and
metering. For instance, the Electric ESP must both establish a systems infrastructure which is capable of
handling the transmission of information in a format acceptable to PG&E and also have the capability to
exchange information with PG&E over the Internet.
Prior to obtaining proceeding with DA setup, the Electric ESP must fulfill the following:
• Register with the CPUC if it intends to serve Small Customers.
• Complete, execute, and submit the ESP Service Agreement and ESP Credit Application.
(See Chapter 1)
• Complete, execute, and submit the Consolidated Billing Options Worksheet if planning to
offer consolidated billing options. Complete, execute, and submit the EDI Trading Partner
Agreement and EDI Setup Form if planning to offer Consolidated ESP billing. If
applicable documents are not submitted, PG&E will default billing option selection to
Separate billing. (See Chapter 1)
• Obtain credit approval from PG&E if planning to offer Consolidated ESP billing. If credit
is not approved, PG&E will default billing option to Separate billing. (See Chapter 1)

Checklist of key steps
# STEP
1. Prepare systems setup for electronic data exchange
2. Review electronic transfer procedures and rules as designated by PG&E for DES
and EDI (if applicable)
3. Review electronic transfer procedures and rules as designated by PG&E for DES
and EDI (if applicable)
Direct Access Setup Illustrated
Procedures
Prepare systems
setup for
electronic data
exchange
Review electronic
transfer procedures
and rules as
designated by PG&E
for DES and EDI (if
applicable
Review electronic
transfer procedures
and rules as
designated by PG&E
for DES and EDI (if
applicable
This section provides a detailed discussion of the process steps outlined within the Checklist of Key
Steps.
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Electronic data exchange synopsis
Participation in DA will require that Electric ESPs are capable of exchanging service account information
electronically with PG&E. Currently all DA information is transmitted using data transfer protocol,
which allows Electric ESPs to submit administrative DA transactions (i.e. DA setup, DA service
termination, meter usage, billing service options, customer service account changes, etc.) to PG&E
through the Internet. Data exchange between PG&E and the ESP is accomplished when the ESP
retrieves response data from a data directory that has been established for them. Data entry and Internet
connectivity will be facilitated by the Data Exchange Service (DES), which Electric ESPs can easily
install locally on their systems.
Additionally, the transmission of financial information (i.e. Electric ESP/PG&E charges and payments)
will be required via Electronic Data Interchange (EDI) protocol will also be required for Electric ESPs
who plan to offer the Consolidated ESP billing option to end-use customers.
1. Prepare systems setup for electronic data exchange
The first step involved with electronic data transfer is to establish a systems environment which can
support the processing requirements related to DASRs and Consolidated ESP billing transactions. The
following requirements summarized below are further elaborated upon in Sections C and D of Rule 22:
1. An Electric ESP will be required to meet electronic data exchange requirements as specified
by PG&E. To commence the process for establishing this requirement, the Electric ESP
must contact PG&E.
2. PG&E may allow alternative arrangements to electronic data exchange at its discretion for
certain transactions.
3. An Electric ESP must have the capability to exchange data with PG&E via the Internet.
4. The Electric ESP must have the capability to communicate to and from Metering and Data
Management Agent (MDMA) servers for the sharing of meter reading and usage data.
5. The Electric ESP must have the capability to perform Electronic Data Interchange (EDI) if
it will be offering ESP or UDC Consolidated billing options.
6. To commence the process for establishing EDI, the Electric ESP must contact PG&E and
shall be required to enter into a trading partner agreement in the form by completing and
submitting the EDI Trading Partner Agreement to PG&E.
2. Review electronic transfer procedures and rules as designated by PG&E for
DES and EDI (if applicable).
Electric ESPs who participate in DA with PG&E will need to conform to specific electronic transfer
procedures and rules as discussed below.
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DATA TRANSFER SPECIFICS: HOW DES IS USED TO EXCHANGE DA INFORMATION
DES was developed specifically to transmit gas and electricity utility metering, billing, and
administrative information contained within DASRs between Electric ESPs, UDCs, Metering Agents
(MA), and Billing Agents (BA).
Information is transmitted between the Electric ESP and PG&E through DES over the Internet (World
Wide Web). All DASRs that the Electric ESP submits through DES are transmitted to a data repository
external to PG&E’s firewall called the “QUE” and are automatically time stamped upon arrival. The
time stamp determines the priority of the DASR. These DASRs are then forwarded in order of priority to
a server inside PG&E’s firewall called the PG&E DASR Interface (“DASR Interface”), where they are
further processed by priority within PG&E’s Customer Information System (CIS).
DASRs that PG&E transmits to the Electric ESP are initially placed in the DASR Interface and then
forwarded to the QUE, from which the Electric ESP can download or view the DASRs.
The diagram below depicts the information channels used when DASRs are submitted.
ESP
ESP
ESP
DES implementation
Que
PG&E DASR
Interface
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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Fire
Wall
2.1: DASR SUBMITTAL INFORMATION FLOW CHANNELS
KEY DES CONTACTS
CIS
CS05 Switching Logic
Questions regarding DES protocol or systems implementation requirements related to DES should be
directed to:

CONTACT CONTACT INFO
LYNN MCELHATTON, USER ACCESS CONTROL
AND DES ADMINISTRATOR
DES WEB SITE
PHONE: (415) 973-8080
EMAIL: LDMJ@PGE.COM
Electric ESPs can also consult the DES Internet site at for information about using DES to transmit EDI
data. The exhibit below provides an example of the DES index page.
2.2: DES WEBSITE
EDI data transfer
NOTE: The demos provided serve as tutorials for using DES. As indicated, documentation is
also available through the site and includes the information topics listed below.
Electronic Data Interchange, (EDI) is the exchange of business data in a standardized format between
business computer systems. EDI represents a fundamental change in the way companies transact
business. It replaces paper-intensive functions with efficient electronic transactions and eliminates the
need for printing and mailing business information. By using standard formats and languages, the
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EDI contacts
computerized data can be electronically transmitted between two companies and interpreted
automatically.
The process of sending data via EDI requires a series of steps on the part of the sending and receiving
partners (known as Trading Partners). Once the foundation of your EDI message is defined, most of these
steps will be either automated or procedures will be developed.
Pacific Gas and Electric Company presently utilizes Value Added Networks (VAN's) for EDI Outbound
810 billing transactions. We also have the ability to utilize EDI over Internet connectivity for EDI
Outbound 810 billing transactions to Energy Service Providers.
The EDI contacts below can provide valuable guidance and advice. EDI Direct Access transaction sets
are summarized below the contact table.
Questions regarding EDI protocol or systems implementation requirements related to DES should be
directed to:
CONTACT FUNCTIONAL AREA CONTACT INFO
TOM ELDER
SENIOR PROJECT MANAGER
FOR MORE INFORMATION
BILLING PHONE: (415) 973-5119
For additional, detailed information on the EDI process, visit the EDI Web site.
EDI Direct Access transaction sets
TRANSACTION SET 810 - BILLING
EMAIL: TXE6@pge.com
The 810 Transaction Set is used to provide established PG&E billing data in an electronic format to its
customers. The billing data provided electronically reflects the same information that appears on a
traditional paper bill and is consistent with national standards for EDI.
TRANSACTION SET 814 - DIRECT ACCESS SERVICE REQUEST (DASR)
The 814 Transaction Set or DASR is sent between the Utility and Energy Service Providers (ESPs) for
purposes such as connecting a customer (i.e. Connect Request), updating a significant customer event
(i.e. Update Request/Notification), or disconnecting a customer (i.e. Disconnect Request).
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NOTE: that an Electric ESP that exchanges 814 EDI data with PG&E must also be able to
receive 867 EDI. The 867 is used to pass the required 12 months of usage history for the
customer to the Electric ESP.
TRANSACTION SET 820 - PAYMENT AND REMITTANCE ORDER
The 820 Transaction Set is used to make a payment and send a remittance advice. This transaction set can
be an order to a financial institution to make a payment to a payee. It can also be a remittance advice
identifying the detail needed to perform cash application to the payee's accounts receivable system.
PG&E's application requires that the 820 go through a financial institution.
867 - METER USAGE
The 867 Transaction Set is used to transfer meter usage data. Where the Electric ESP is the MDMA the
867 will be sent to PG&E as in inbound file. Where PG&E is the MDMA the 867 will be sent as an
outbound file to the Electric ESP. Refer to the implementation checklists below for both the 867 inbound
and outbound requirements.
997 - FUNCTIONAL ACKNOWLEDGMENT
The “Draft Standard for Trial Use” contains the format and establishes the data contents of the Functional
Acknowledgment Transaction Set (997),. Transaction Set 997 can be used to define the control structures
for a set of acknowledgments to indicate the results of the syntactical analysis of the electronically
encoded documents. The encoded documents are the transaction sets, which are grouped in functional
groups, used in defining transactions for business data interchange. This standard does not cover the
semantic meaning of the information encoded in the transaction sets.
Test the viability and accuracy of data transferred to PG&E using DES
PG&E requires each Electric ESP to conduct electronic data transfer testing. Therefore, the Electric ESP
will need to develop a viable test plan with respect to testing the transfer of DA information to PG&E via
DES. Testing requirements, testing implementation framework, and required downloadable programs are
available to Electric ESPs on the DES Web site.
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C HAPTER 3
PROCESSING DIRECT ACCESS
SERVICE REQUESTS (DASRS)
Overview
Definition of Terms
This chapter discusses the processing cycle associated with Direct Access Service Requests (DASRs) and
the establishment of Electric ESP services to include: DA enrollment, cancellation of DASRs, DA
service termination, and DA account maintenance. The chapter also describes how DASRs are
prioritized for processing once received by PG&E and when DA service will commence after a setup
DASR has been accepted.
Direct Access Service Requests (DASRs) are the electronic records used to initiate, update and cancel
Direct Access service options between Electric ESPs and end-use customers. Electric ESPs are
authorized by end-use customers to submit DASRs for service accounts that desire to switch to DA,
change Electric ESPs, cancel DA, etc. An approved DASR will become a part of the ESP Service
Agreement and will be used to define the services that PG&E will be providing to the customer.
Customers with more than one account with PG&E at the same premises may choose DA or full service
for each separate account. However, a customer may not partition the load at a single meter or on a
single account with multiple meters.
In order to establish DA service for end-use customers, Electric ESPs must submit DASRs, which
provide detailed information about the service requirements for a given customer. An end-use customer
may not directly submit a DASR to PG&E unless that customer has agreed to act as an Electric ESP on
its own behalf. The Electric ESP must submit all DASR information electronically through DES using
the protocol discussed previously within the Electronic Data Exchange section of Chapter 2: Direct
Access Setup.

Prerequisites
TRANSACTION # COMMUNICATION
FLOW
1 (ELECTRIC ESP TO
UDC)
2 (ELECTRIC ESP TO
UDC)
3 (UDC TO ELECTRIC
ESP)
4 (UDC TO ELECTRIC
ESP)
5 (UDC TO ELECTRIC
ESP)
6 (ELECTRIC ESP TO
UDC)
7 (UDC TO ELECTRIC
ESP)
8 (ELECTRIC ESP TO
UDC) OR (UDC TO
SP)
3.1 - FLOW OF DASR TRANSACTION INFORMATION
DESCRIPTION OF TRANSACTION
setup/establish direct access with customer
discontinue direct access with customer
acknowledge success of direct access request
acknowledge failure of direct access request
acknowledge actual switch of service provider
acknowledge receipt of switch notification
notify of shutoff or turn-on of service
account maintenance (i.e., customer rate schedule
change)
Prior to obtaining customer information and submitting DASRs, the Electric ESP must fulfill the
following:
• Register with the CPUC if it intends to serve small customers.
• Complete, execute, and submit the ESP Service Agreement and ESP Credit Application (See
Chapter 1: Electric ESP Direct Access Preliminary Procedures).
• Complete, execute, and submit the Consolidated Billing Options Worksheet if planning to offer
consolidated billing options.
• Complete, execute, and submit the EDI Trading Partner Agreement and EDI Setup Form if
planning to offer Consolidated ESP billing. (See Chapter 1: Electric ESP Direct Access
Preliminary Procedures).
• Obtain credit approval from PG&E if planning to offer Consolidated ESP billing. If credit is not
approved, PG&E will default billing option to Separate billing. (See Chapter 1)
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• Prepare information systems setup for electronic data exchange. (See Chapter 2)
• Confirm the viability and accuracy of information transferred to PG&E by performing data
exchange testing in accordance with PG&E requirements. (See Chapter 2)
• Meet the requirements of CPUC Code Section 365(b)(2) (renewable supplier status) if the
DASR indicates that the Customer and Electric ESP claim the status afforded by that code
section. DASRs in which the Electric ESP and the Customer claim the status afforded by
Section 365(b)(2) will be given priority in the processing of the DASR in the event of backlog.
Additionally, Electric ESP customers who wish to obtain DA services are subject to the following
requirements and conditions:
Checklist of key steps
# STEP
• A customer must have a service account number assigned by PG&E before the customer
may authorize an Electric ESP to submit a DASR on its behalf. If the customer is new to
the service territory or is moving to a different physical location within the service territory,
the customer must first establish an account with PG&E and receive an account number.
This account number will be used for the submission of the initial DASRs.
1. Electric ESP obtains customer authorization to submit a DASR on their behalf.
2. Electric ESP obtains Customer CTC Agreement, if required.
3. Electric ESP determines DASR transaction and obtains customer information
required to complete DASR.
4. Electric ESP completes DASR information.
5. Electric ESP submits DASR to PG&E through DES.
6. PG&E processes DASR.
7. PG&E sends a confirmation, rejection, or pending notification to Electric ESP within
two business days.
Processing DASRs Illustrated
The diagram below depicts the primary procedures related to processing DASRs.
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ESP obtains
customer
authorization to
submit a DASR
ESP obtains
customer CTC
agreement, if
required
ESP evaluates
customer DA
elections and obtains
appropriate data
ESP completes
DASR
ESP submits DASR
through DES
PG&E evaluates
DASR
Accept DASR
Yes
PG&E sends
acceptance notice to
ESP & customer
performs DASR
transaction
No-reject
No-pending
PG&E sends rejection
notice to ESP & customer
PG&E sends pending
notice to ESP & customer
No
ESP resolves DASR
issues
Pending for
more than 11
days?
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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Yes

Procedures
This section provides a detailed discussion of the process steps outlined within the Checklist of Key
Steps.
1. Electric ESP obtains customer authorization to submit a DASR on its behalf
An Electric ESP must receive authorization from the end-use customer in order to submit a DASR on its
behalf. The customer can authorize any of the available DASR transactions such as DA setup, DA
termination, and switch of Electric ESP.
2. Electric ESP obtains customer CTC Agreement, if required
As a condition of receiving DA service, DA customers will be responsible for paying for all Competition
Transition Charges (CTC) and other non-bypassable charges authorized by the CPUC for the UDC to
recover from customers in accordance with state law. DA customers are required to confirm this
responsibility in writing provided to the Electric ESP, unless the customer is exempt from the
requirement to provide such a confirmation in writing pursuant to Public Utilities Code Section 370.
Where the customer disputes its obligations to pay CTC for a particular account, the customer may
condition its agreement on resolution of the dispute, provided that the customer has formally requested
the CPUC to grant such relief. However, the existence of such a dispute does not relieve the customer
from the obligation of paying CTC while the dispute is pending. PG&E will continue to bill the customer
(either directly or indirectly through its Electric ESP, depending on the billing option selected) for such
charges. The customer must pay all charges, but may pay any amounts in disputes in accordance with
Rule 10, pending resolution of the dispute.
3. Electric ESP evaluates customer DA elections and obtains customer
information required to complete DASR
Electric ESPs can designate different types of transactions on a given DASR. The table below lists the
transactions, which the Electric ESP can initiate on behalf of an end-use customer. The table also
identifies key customer information that the Electric ESP will need to obtain depending on the type of
transaction. In addition to the customer information outlined below, there are additional field
requirements for each of the transactions. These requirements are available through the DES Web site at
(see Information Websites at the end of Chapter 1 in this handbook).
The designations correspond to those specified in the DASR transaction descriptions.
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TRANSACTION # DESCRIPTION OF
TRANSACTION
1 SETUP/ESTABLISH DIRECT
ACCESS WITH CUSTOMER
2 DISCONTINUE DIRECT
ACCESS WITH CUSTOMER
6 ACKNOWLEDGE RECEIPT
OF SWITCH NOTIFICATION
10 ACCOUNT MAINTENANCE
(I.E., CUSTOMER RATE
SCHEDULE CHANGE)
11 ACCOUNT UPDATE (I.E.
METERING
RELATIONSHIPS, BILLING
OPTIONS)
REQUIRED CUSTOMER INFORMATION
5. Electric ESP submits DASR to PG&E through DES
• Customer Name
• Service Account Address and current service Zip
• UDC Customer Account Number
• Service Relationship Provided
• Provider (Electric ESP, UTC)
• Commodity (i.e. electric, gas)
• Billing Option (i.e. UDC-consolidated,
Consolidated ESP, dual)
• Renewable Energy Provider Requested
• Life Support Customer status*
• UDC Customer Account Number
• Service Relationship Energy Provided (i.e.
electric, gas)
• Customer Name
• Service Account Address and current service Zip
• Provide information contained in the
acknowledgment of actual switch of service
provider
• UDC Customer Account Number
• Service Relationship Energy Provided (i.e.
electric, gas)
• Customer Name
• Service Account Address
• Account information the customer wants to
change
• Same as #10, Account Maintenance, above
Upon entering the required DASR transaction information, the Electric ESP submits the DASR file
through DES by typing the following command at the DOS prompt:
6. PG&E processes DASR
NOTE: Successful implementation of the data exchange test procedure outlined with the
previous chapter required the Electric ESP to install the put.exe and get.exe files locally. If
put.exe and get.exe are not currently installed on the Electric ESP’s local workstation, the
Electric ESP will need to install these programs. Again the files and downloading instructions
are available through the DES Web site.
The illustration below represents the timing associated with processing a DASR.
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Day 0 Day 2
Day 7
PG&E sends
acknowledgment
to ESP that they
have received the
DASR
3.1 - DASR PROCESSING TIMELINE
ELECTRONIC VALIDATION
Does PG&E
accept the DASR
No
PG&E sends
DASR
acceptance
confirmation
to ESP &
customer
PG&E
notifies ESP
& customer
of error
pending
status or
rejected
DASR
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 37
Yes
PG&E will provide, along
with the confirmation
notice, information
regarding when the DA
customer will begin
receiving ESP services,
unless a meter is required
PG&E will confirm or reject
DASRs in error pending
status
All DASRs undergo both transaction level validation, as described in DASR Validation and customer
account validation, as described in the Account Validation section below. All validation rules are
covered within the DES Web site (see Information Websites at the end of Chapter 1 in this handbook).
DASR VALIDATION
PG&E will electronically validate DASRs for accuracy and completeness. DASRs failing the basic
accuracy validation will be rejected back to the Sending ESP. PG&E will communicate the reasons for
rejecting a DASR in the Comments field of the DASR. PG&E will submit a confirmation, rejection or
pending DASR to the Electric ESP within seven (7) business days of receipt.
ACCOUNT VALIDATION
Following successful accuracy validation, PG&E will attempt to electronically match the Receiver
Customer Identifier field of the DASR to PG&E’s computer information system. PG&E’s customer
account number, which is currently printed on the customer’s energy statement, along with the Service
ID, which is printed on the “Details” page of the bill, are the best data available for the Receiver
Customer Identifier field. However, due to the instability of the customer Service ID, PG&E has
developed a unique non-changing customer-commodity-location specific number called the External
Day 18

Reference ID or “XREF ID.” 1 Once the XREF ID has been assigned to a DA commodity account, it will
not change throughout the life of the account unless DA is cancelled. Essentially, the XREF ID provides
a way to readily identify DA commodity accounts and to reference the history of the commodity even if
the customer switches to different ESPs. PG&E will communicate the customer’s “XREF ID” (rather
than “Service ID”) to the Electric ESP in the acceptance confirmation DASR. The Connect DASR will
validate on the Service ID or XREF ID. The customer’s PG&E XREF ID is intended for use in all future
transactions related to this customer’s service location and commodity. The PG&E account number or
XREF ID is a requirement of all transactions.
When a customer’s commodity account (i.e. electric or gas) undergoes its first DASR transaction, the
current Service ID will be used to populate the XREF ID field and a new Service ID will be assigned to
the commodity account. The Service ID replaces the “account number” on the current DASR form and is
also represented on the “Detail” pages of the customer’s bill.
In the event system validation fails to match the Receiver Customer Identifier supplied in the DASR, or
the account/commodity status is other than open, the DASR will be rejected using the standard DASR
acknowledgment process.
Various PG&E programs and services require additional manual account preparation for certain Direct
Access requests. For this reason, successful DASRs may contain a “memo” status informing the Electric
ESP of additional manual preparation. These DASRs will, however, be accepted by PG&E and a DA
effective date, if applicable, will be established and communicated to the Electric ESP in the
confirmation DASR. The most common reasons for memo status will likely relate to metering
installation and setup issues.
7. PG&E sends a confirmation, rejection, or pending notification to Electric
ESP
Depending upon the results of the validation process, PG&E will electronically send a DASR acceptance
confirmation, rejection, or pending notification to the Electric ESP. A notice will also be sent to the
customer.
ACCEPTANCE NOTICES
An acceptance notice confirms that the DASR has been submitted successfully. If the DASR represented
a DA setup transaction and meter installation is not pending for the service account, a notice
acknowledging the actual switch of service provider and designating when the DA customer will begin
Electric ESP service will also be sent to the Electric ESP and to the customer.
1 Use of the “GEN ID” has been discontinued and replaced by the “XREF ID.”
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REJECTION DASR
A rejection notice provides specific information on why a given DASR was rejected.
The table below provides information on error codes that are generated as a result of a rejected DASR.
[Insert Gary’s Error Code Matrix]
Additional DASR procedures performed by PG&E
Based upon the requested services designated by the Electric ESP, PG&E may be required to perform
additional DASR procedures in order to complete the processing of the DASR transactions as described
below.
DASR FOR “NEW” PREMISES
Although the current DA suspension rule does not allow new accounts to be eligible for DA, there are
certain circumstances under which a DASR can be submitted for premise that may be considered “new”.
DA eligibility, in general, is restricted to the following circumstances:
a) Service Panel Upgrades
b) Bankruptcies
c) Assignment of Contract to a new ESP
d) Mergers/Acquisitions/Corporate Reorganizations
When applicable the ESP should contact ESP Services in advance to coordinate the submission of
DASRs.
ADDITIONAL SETUP TRANSACTION PROCEDURES
Billing and Billing Calculation Options. Electric ESPs will state their billing preference in
each DASR. Three billing options are allowed with DA including: 1) UDC (UDC-consolidated
bill for both ESP and UDC charges), 2) SP (Consolidated ESP bill for both ESP and UDC
charges), or 3) DUAL (UDC bills for UDC charges and Electric ESP bills for ESP charges).
PG&E will communicate the enrolled billing option in the confirmation transaction to the
Electric ESP. An example of an invalid billing option is a DASR requesting Consolidated ESP
billing by an Electric ESP that is not authorized to perform Consolidated ESP billing. Once the
account has been prepared for the requested billing option, PG&E will issue a new confirmation
DASR to the Electric ESP informing them of the billing option change and effective date.
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Various PG&E programs require manual account preparation for consolidated billing. PG&E
will determine which accounts require manual follow-up and will default those accounts to
Separate billing pending account preparation for consolidated billing. Customer account billing
options which may require manual preparation include:
Balanced Payment Plan (BPP). PG&E’s Balanced Payment Plan (BPP) provides customers
with levelized monthly bills. However, due to the various billing options offered with DA,
PG&E will not be able to offer BPP to DA accounts. Therefore, if a DASR is received and the
account is enrolled in BPP, PG&E will remove the account from BPP and send the customer a
bill for the account’s outstanding balance. This operation will not hinder the account from
becoming a DA account.
Automatic Payment Service (APS). PG&E’s Automatic Payment Service (APS) provides
customers the ability to pay their UDC bill through an automatic debit of their personal bank
account. For those accounts that will be served under the Consolidated ESP billing option, APS
must first be removed from the account before Consolidated ESP billing can be put into effect.
PG&E will flag the account for removal from APS. Following account preparation, PG&E will
place the account on Consolidated ESP billing and issue a confirmation DASR, informing the
Electric ESP of the billing option change and effective date.
Electronic Data Interchange (EDI). EDI provides the customer with the ability to pay their
UDC bill using an EDI interface. EDI is treated similar to APS. DASRs requesting the
Consolidated ESP billing option will require EDI to be removed from the account. PG&E will
follow-up to confirm the customer’s next EDI bank payment clears the account balance.
Following account preparation, PG&E will place the account on Consolidated ESP billing and
issue a new DASR confirmation to the Electric ESP of the billing option change and effective
date.
Balance Due. The Electric ESP must advise its customers that all past due balances owed for
bundled utility service must be paid prior to the start of Consolidated ESP billing service. PG&E
may pursue collection of the balance owing for bundled service from the customer in
accordance with its applicable rules, including if appropriate, termination of the customer’s
service.
Rate Schedule Application. DASRs requesting the UDC-consolidated billing option must
include a valid Electric ESP Rate Name (SP Rate Schedule). Electric ESPs may submit account
maintenance DASR transactions to request a change to the SP Rate plan assigned to the account.
ADDITIONAL TRANSACTION PROCEDURES FOR NEWLY ESTABLISHED PG&E ACCOUNT
NUMBERS
Turn On (T/O). A UDC service turn-on (T/O) order is initiated when a customer establishes a
new account with PG&E. Customers must receive an account number from PG&E prior to an
Electric ESP submittal of a DASR for the customer at the new location. The DASR must be
submitted with a UDC account number containing at least nine (9) characters. This partial
account number will alert PG&E to search for a T/O request, allowing the new account to have
DA service on the requested service date.
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ADDITIONAL SHUT OFF (S/O) AND SHUT-OFF NON-PAYMENT (SONP) TRANSACTION
PROCEDURES
Shut-Offs initiated by the DA customer. In the event that a customer contacts PG&E to close
its utility service account, PG&E will notify both the servicing and pending Electric ESP with a
termination DASR. PG&E will notify the current Electric ESP by electronic mail in the event of
a shut-off for non-payment.
ADDITIONAL CANCELLATION TRANSACTION PROCEDURES
Cancellation of pending DA service may be requested by the pending Electric ESP. The
pending Electric ESP can cancel a scheduled switch by submitting a DASR transaction, at least
three business days before the scheduled switch date. The request to cancel will be effective
immediately. The existing service provider (ESP or UDC) will remain in effect.
Termination of current DA service may be requested by the current Electric ESP. The
current Electric ESP may terminate service with a customer at any time. The request to
terminate service will be effective according to normal DA switching logic. The switch date
will be the next scheduled meter read date, which occurs fifteen (15) or more days after the
DASR has been received in the DASR Interface. Once the switch occurs, the customer would
remain a full-service customer with PG&E for at least one billing cycle before it could establish
DA service with another Electric ESP. If the current ESP has pending relationships, the
UPDATE DASR will recalculate the earliest possible start date for all relationships.
ADDITIONAL CUSTOMER ACCOUNT DATA CHANGE TRANSACTION PROCEDURES
PG&E will modify its customer account information upon direct customer request only, therefore,
DASRs received by Electric ESPs communicating customer data changes will not be accepted and will
reject back to the initiating Electric ESP.
Electric ESPs may however, request their customer’s account information record from PG&E using the
Customer Information Release Form. Upon request by the current or pending Electric ESP, PG&E will
respond with a standard DASR Customer Account Information record. In the future, PG&E may
implement automatic notification of customer data changes to the Electric ESP.
ADDITIONAL PROCEDURES FOR INITIAL CUSTOMER HISTORICAL USAGE INFORMATION
Upon DASR confirmation, up to 12 months of customer historical usage information will be released
automatically to the pending Electric ESP if PG&E is acting as the energy provider.
NOTE: Historical usage information may be incomplete for some gas and electric services
where a meter change has taken place. In these instances, the ESP will be provided with
supplemental usage history via email.
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SEAMLESS MOVE
Direct access customers who move within the service territory can maintain electric DA service with
their electric ESP. It is not necessary to begin with bundled service at the new location.
Seamless Move Procedures
While gathering the necessary information to move the customer’s distribution service, the company’s
call center determines whether the customer wants to continue to use the same Electric ESP. If “yes”, the
company notifies the customer’s Electric ESP by e-mail. The company sends the e-mails once per day in
a batch by noon, Pacific time. The Electric ESP must designate one person (one e-mail address) to
receive the e-mails.
The e-mail to the customer’s Electric ESP includes:
• Customer name
• Old service address
• New service address (including ZIP code)
• Old Service ID
• New Service ID
• New meter number (if required for DASR acceptance)
• XREF ID
• Requested turn-on date
• Billing address (if different than the service address)
• Type of move (“new”, “rescheduled”, or “cancel”)
It may also contain, if available:
• Rate class
• New telephone number
• Old Electric ESP customer account number
The Electric ESP may use the data contained in the e-mail to submit a DASR to PG&E for service at the
new location. This DASR must contain a “new customer” designation.
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If the DASR was submitted at least three business days before the requested turn-on date, the customer
will receive Direct Access service from that date. If the DASR was submitted less than three business
days before the requested turn-on date, the customer will receive direct access service as of the next
meter read date.
The Electric ESP is responsible for communicating with the customer about their new service start dates
in order to help the customer understand the process. In general, the seamless move procedures involves
the steps indicated below:
Canceling a Seamless Move
• Customer contacts their ESP to stop service at the current location and to start service at the
new one
• The ESP contacts ESP Services about their customer’s seamless move.
• The ESP is sent a Pending service disconnect DASR (SVC DISCONNECT) containing the
future stop date.
• The ESP will then receive an acknowledgement DASR (ACK) for the new location, which
will contain the new XREF ID and actual stop date information.
• The ESP’s customer identifier will remain unchanged.
If the customer calls back to cancel the move, PG&E will either send a cancellation DASR to the Electric
ESP if the ESP had already submitted a DASR for the new location, or send a cancellation e-mail to the
Electric ESP if the ESP had not already submitted a DASR for the new location.
In the event the customer’s Electric ESP is serving only a geographic subset of PG&E’s service territory,
(a municipal aggregator, for example) and the customer is moving to a new location not served by the
Electric ESP, the ESP will not submit a DASR on behalf of the customer at the new location.
Limits to a Seamless Move Option
To be eligible for a seamless move, a customer must be:
• An existing Direct Access customer.
• Moving within the service territory.
• A residential or small commercial customer who is load-profiled.
All DASR options must remain the same from the existing or old service location to the new service
location; that is, the MSP/MDMA/billing/meter owner options must be the same in both locations.
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A change in responsible party, at the time of the move, constitutes a new customer and is not considered
simply a move of distribution service location.
Customers who move first, and notify PG&E after they have moved, will not be eligible for Direct
Access at the time of initial service.
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C HAPTER 4
DA ELECTRONIC DATA
EXCHANGE CONTINGENCY
PLANS
Overview
The objective of this chapter is to describe the contingency process for handling DA sign up should one
or more elements of the DASR process fail. Although, failure of the electronic process is not anticipated,
we have put procedures in place which will allow DASRs to be processed in the event of an unplanned
systems-related problem.
Behind the scenes look at the DASR process
DASRs which are submitted by Electric ESPs through DES are transmitted via the Internet to PG&E’s
systems through a mail server called “QUE.” The QUE acts as a data repository for the Electric ESPs
and PG&E to send and retrieve data. The QUE will sort and direct the incoming data by type. Once the
data is in QUE, another system called the PG&E DASR Interface (“DASR Interface”) will retrieve the
data for PG&E. The DASR Interface manages the data from the QUE. DASR Interface is a database
that contains a list of transactions. It takes the data in and stores the transactions, (e.g., to whom we sent
information to) the reasons why, and the data names (e.g. record type, operation type, service relation, SP
identifier). DASR Interface also time-stamps the data, looks for data changes, conducts basic validation
of data, error checks etc. Next, the DASR Interface sends the data to our Customer Information System
(CIS). CIS contains the “CSO5” file--the logic for switching customers to direct access service. CSO5 is
located in the “Master File”. At this point, the customer’s data would be “confirmed” or “rejected” back
to the Electric ESP. This entire process is also know as the DASR or Direct Access Service Request.

DASR Server Communication Illustrated
Risks
The diagram below depicts the flow of information between the external data repository QUE, PG&E’s
DASR Interface, which confirms transactions, and the CIS switching logic which establishes DA service
for a given customer.
ESP
ESP
ESP
Que
PG&E DASR
Interface
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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Fire
Wall
4.1 - INFORMATION FLOW BETWEEN QUE AND DASR INTERFACE
CIS
CS05 Switching Logic
At any point in this process described above, the electronic down-load or DASR could fail to operate as
planned. Conversely, the Electric ESP’s system may also fail. The impact is that PG&E will be unable to
sign-up customers for Direct Access through electronic means.
Event Scenario Back-up Plans
The following sections describe possible scenarios resulting from Internet failure, Electric ESP/PG&E
system incompatibility, ESP equipment failure or PG&E equipment failure.

Electric ESP unable to communicate with DES
ESP
ESP
ESP
DES
PG&E DASR
Interface
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Fire
Wall
4.2 - ELECTRIC ESP UNABLE TO COMMUNICATE WITH THE QUE
SITUATION
The Electric ESP is unable to send information to PG&E’s QUE because of:
• Electric ESP equipment failure.
• The incompatibility of the Electric ESP’s system with that of PG&E.
• Internet failure.
• Failure of the QUE/DES.
BACK-UP PLAN
CIS
CS05 Switching Logic
1. The Electric ESP will notify PG&E’s ESP Services Hotline or PG&E’s ESP Services will notify
Electric ESPs that there is a problem either by fax or phone..
2. If there is a failure of the QUE but a connection through the Internet is available, the ESP will be
given instructions on sending the data file by email. If an Internet connection is not available, the
Electric ESP will save customer DASR requests on a disk as a comma-delimited .CSV file. The
format should be according to the EDI format as described within Chapter 2: Direct Access Setup in
the section, Review electronic transfer procedures.
3. The Electric ESP should express mail the disk to the following address, ESP Services, Pacific Gas
and Electric Company, 77 Beale Street, 19 th Floor, San Francisco, CA 94105.

4. PG&E will send a confirmation file back to the Electric ESP containing confirmation or rejection
data for each DASR.
Failure of PG&E equipment (DASR Interface & CIS)
ESP
ESP
ESP
Que
4.3 - FAILURE OF PG&E EQUIPMENT
SITUATION
Fire
Wall
PG&E DASR
Interface
CIS
CS05 Switching Logic
The DASR Interface is unable to receive data from the QUE or pass data into CIS or PG&E’s CIS goes
down.
BACK-UP PLAN
1. This situation will be considered an emergency. ESP Services will notify all Electric ESPs of
emergency conditions.
2. PG&E will not accept DASRs until the problem has been resolved and the system is stable.
3. The CIS “masterfile” will be responsible for all data validation checks if the DASR Interface goes
down.
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C HAPTER 5
METERING
Overview
Metering Services
This chapter focuses on DA (Direct Access) interval metering including meter installation, meter
maintenance obligations, Meter Data Management Agent requirements (including procedures for meter
ownership), meter reading and meter data access.
Within the context of this chapter, the term “meter” refers to an hourly, non-load profile meter, known as
an “interval meter.”
Interval meters are required for DA customers whose maximum electrical demand is equal to or exceeds
50kW. Those DA customers whose demand is between 20-50kW may choose to have an interval data
meter installed; however, meters already in place for customers whose demand is between 20-50kW
already meet the requirements for DA load profile.
If any customer, including those with an electrical demand is 50kW or below, wishes to participate in
PG&E’s hourly PX rate option, that customer is required to have an interval data meter installed.
Similarly, those customers on electric rate schedules A-10 and E19V will be required to have an interval
meter installed if a “spike” of 80kW or over is reflected in their usage within the last 12 months.
PG&E’s Rule 22, Direct Access Service, describes the terms and conditions that apply to both PG&E
customers and Electric Energy Service Providers who participate in Direct Access. Fees for Direct
Access services are described in PG&E Schedules E-DASR, E-ESP and E-EUS. Refer to PG&E’s Web
Tariff Book (see Information Websites at the end of Chapter 1 in this handbook).
While PG&E is hopeful this chapter provides the reader with basic information regarding DA Metering
in PG&E’s service territory, we also strongly suggest contacting your PG&E assigned ESP Services
Representative to arrange a meeting to discuss your metering plans, along with procedures and processes.

METER SERVICE PROVIDER RESPONSIBILITIES
While CPUC decisions refer to meter service providers (MSPs), the industry currently identifies Meter
Installers and Meter Maintainers. ESPs may select approved Meter Installers and Meter Maintainers,
including PG&E, to perform interval meter installations and maintenance.
Responsibilities for Meter Installers and Meter Maintainers include:
• meter installation
• meter operation and maintenance services
• meter testing and certification
METER INSTALLATION STANDARDS
Meter installations will be conducted according to the requirements specified in DASMMD. PG&E shall
have no liability for any damage or injury caused by ESP-installed metering equipment.
EFFECTIVE DIRECT ACCESS DATE
The effective date and time of the switch to direct access are the time and date of the installation, unless
the account is DA Ready (see the “DA Ready Meter” section). If the account is DA Ready, the switch
date is the next meter read date. Also see the “Meter Work Not Completed Within 60 Days” section
under the heading, “Return to Bundled Service from Direct Access and Meter Ownership – Bundled Safe
Harbor.”
METER MAINTENANCE
The Meter Maintainer is responsible for the routine maintenance of all DA interval meters, including but
not limited to, DA interval meter testing, record keeping to assure safe and proper operation of the DA
interval meter, and timely repair in accordance with the CPUC’s (California Public Utilities
Commission’s) and other applicable standards.
METER EQUIPMENT SPECIFICATIONS
All meters installed by ESPs or their Meter Installers shall meet all CPUC-approved Direct Access
Standards for Metering and Meter Data (DASMMD) and shall be self-certified by the meter
manufacturer with the CPUC.
PG&E retains the right to replace an existing meter regardless of ownership if that meter fails to meet the
requirements specified in DASMMD. If PG&E replaces the meter, the installation terms, conditions and
procedures below will apply:
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• If the ESP does not elect to provide metering services, PG&E will provide those services at fees
specified in PG&E’s rate schedules to the DA customer.
• If PG&E removes the DA interval meter, PG&E will properly identify and return the meter to its
owner in the same condition as found within 5 business days.
Obtaining Meter Equipment Information for Existing Customer Accounts
ESPs submit DASRs in accordance with guidelines provided in Chapters 2 and 3 of this handbook,
“Processing Direct Access Service Requests.” Those DASRs which either require or request meter
installations become meter installation orders.
NOTE: No Direct Access metering services may be provided or started by an ESP, its Meter
Installer or MDMA for any customer unless the ESP’s DASR has been accepted by and the
ESP’s work has been scheduled with PG&E.
PG&E’s Meter Equipment Information web site provides authorized and secure access to ESPs and their
designees, generally their Meter Installer, Meter Maintainer or MDMA, for information on existing
metering equipment by customer account. For general information and procedures, see the Meter
Equipment Information Web site.
WEB SITE TEST
ESPs are required to test the Meter Equipment Information web site to ensure their passwords are
operational and meter information is easily downloaded. For further information on the Web Site Test,
go to http://meterinfo.pge.com/3rdparty/login.asp.
SELECTION OF THE METER INSTALLER
As described in the Meter Service Provider Responsibilities paragraph of this chapter, the ESP may select
PG&E as its Meter Installer or Meter Maintainer or select another Meter Installer or Meter Maintainer to
perform metering services. Those services include meter installation, meter operation, maintenance,
testing and calibration. Generally the work also includes the removal of the existing meter.
PG&E metering services fees will be charged to the ESP in accordance with CPUC-filed tariffs. (See the
filed document, E-ESP, located in the Web Tariff Book.)
SCHEDULING METER REMOVALS AND INSTALLATIONS - PG&E AS METER INSTALLER
When PG&E is the meter installer, meter installation scheduling is based upon the following:
• Each DASR’s renewable and non-renewable energy supply status
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• PG&E’s capacity to install meters which is dependent on its new construction volume, meter
compliance, and meter data recovery work
• Date PG&E accepted the DASR on a first-come, first-served basis
• Site readiness
• Mutually agreed upon date
The ESP is responsible to ensure the meter site is ready for the meter installation. A meter site is
considered ready when PG&E has ESP-provided meters on hand and the meter telecommunications are
in place and working.
PG&E AS METER INSTALLER
If the site is DA Ready with an interval meter in place or PG&E, as Meter Installer, installs a customerowned
DA interval meter, the ESP is responsible for the meter cost, local sales tax, Service Base Charge,
meter removal and installation charges and the programming and testing of the DA interval meter in
accordance with the filed rate schedules. (See PG&E’s Web Tariff Book.)
METER SUPPLIED BY ESP
If PG&E, as Meter Installer, installs an ESP-provided DA interval meter, the ESP will be responsible for
the Service Base Charge, the meter removal and the meter installation charges. Additionally, If the ESP
has not performed meter programming and testing, PG&E will charge for that work in accordance with
the provisions of PG&E’s Direct Access Service Rule 22 and its filed rate schedules. (See PG&E’s Web
Tariff Book.)
DA READY METER
A DA ready meter is an installed PG&E interval meter or a customer-owned meter that meets the
CPUC’s interim meter standards and is currently phone line read.
If an account has a PG&E DA ready meter, the ESP may elect to use this meter. Phone service account
payment responsibility is described below in the paragraph entitled, “Responsibility - Phone Service
Account Payment.”
PHONE SERVICE NOTIFICATION - PG&E AS METER INSTALLER
The ESP notifies PG&E’s MEG (Meter Event Group) by sending a “Phone Service Notification.” The
Phone Service Notification can be downloaded from the “DA Documents” link on the ESP Resource
Center Web site.
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Upon receipt of the Phone Service Notification, PG&E then schedules the installations in accordance
with its capacity to install meters and posts the scheduled date and order status update to its Meter
Equipment Information Web site.
If the ESPs want to coordinate a field meeting, they must notify the MEG by forwarding a “Field
Meeting Request.” Fees charged to the ESP for the field meeting will be in accordance with PG&E’s rate
schedules.
COMPLETED METER INSTALLS
PG&E will post completed meter removal and installation and maintenance work orders to PG&E’s
Meter Equipment Information Web site.
RE-SCHEDULING METER INSTALLATIONS
Site Not Ready. If at the time of the scheduled installation PG&E determines the site is not
ready, PG&E will notify the ESP.
Metering Equipment Not Available. If at the time of the scheduled installation, the metering
equipment (meter, cellular phone, etc.) is not on hand, PG&E will notify the ESP.
Other Operational Reasons. PG&E will notify the ESP of other operational reasons including,
but not limited to, regulatory compliance work, restoration of service, emergency response, new
business work load and meter repair and data recovery.
Scheduling Meter Removals and Installations - ESP as Meter Installer
The CPUC’s decision, “Opinion Regarding Direct Access Implementation Plans and Related Tariffs - 97-
10-087,” requires the ESP to provide UDCs with 5 business days advance notice of its meter
installations. As part of PG&E’s implementation process of the CPUC requirement, ESPs are asked to
submit install schedules no later than 3 working days prior to the scheduled date. The statewide accepted
form can be found on the CPUC Web site and includes such data fields as:
• UDC order number
• Customer Account number
• Customer name
• Install Date
• XREF ID
• Install Time - if one of first 20 installations
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Service Upgrades
• Meter Installer - if one of first 20 installations
When an installation does not occur on the scheduled date, the ESP or its designee will notify PG&E’s
Meter Event Group and advise PG&E of the status, i.e., new install date, on hold pending site access,
telecommunications not in place, etc.
Detailed Work Schedule - First Twenty Installations
In accordance with the CPUC’s Decision Regarding Permanent Standards for Metering and Meter Data,
98-12-080, a Meter Installer new to the PG&E service territory is required to provide PG&E with a
schedule of its first 20 installations, including a description of all the procedures it will follow for
removing and installing the meter, and what safety precautions it will take during those procedures.
Additionally, PG&E will exercise its right to meet with the Meter Installer for the first 20 installations
performed.
METER INSTALLATION/REMOVAL NOTIFICATION *
Within 3 business days of the meter removal and installation, the ESP shall return the MIRN (Meter
Installation & Removal Notification) to PG&E. Additionally, PG&E will post all completed MIRNs to
the PG&E Web site.
RETURN OF PG&E METERS
Within 10 business days from meter removal, the ESP must return the meter to:
PG&E Gas & Electric Meter Plant
42100 Boyce Road
Fremont, CA 94538
Attention: Marcia Holloway
PG&E highly recommends that ESPs advise their customers to contact the ESPs as soon as customers
know a service upgrade is in the planning stage. Generally, if the transfer of load to the new service is a
gradual one, a new agreement must be set up to maintain DA service. After a DASR is automatically
generated, the ESP is notified through the DASR notification process.
The coordination of a phone line installation (if applicable) and meter install and removal prior to the
service being energized is critical. Please also contact your assigned PG&E Meter Event Group
representative as soon as possible to ensure a smooth transition.
Return to Bundled Service from Direct Access and Meter Ownership
When a customer returns to bundled service from direct access and owns the interval meter, that meter
may remain in service if:
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• The meter meets the CPUC’s interval meter design specifications and is compatible with
PG&E’s meter reading systems.
• And the customer:
• Grants PG&E rights acceptable to PG&E to access, test, maintain and read the interval
meter at any time.
• Pays any costs that PG&E incurs in providing metering services using the interval meter to
the extent those costs exceed the costs that PG&E would incur using a standard PG&E
meter for bundled service.
• Agrees that PG&E may, at its discretion and at the customer’s expense, replace the interval
meter if it malfunctions with a standard PG&E meter for bundled service.
If the meter is not compatible with PG&E meter reading systems, the meter will be replaced at customer
expense with a standard PG&E meter.
TRANSITIONAL BUNDLED SERVICE (TBS), ALSO KNOWN AS SAFE HARBOR
On May 8, 2003 the CPUC issued Decision, D.03-05-034, the “Switching Order,” in order to adopt rules
to implement what is known as the “Switching Exemption.” The new rules, implemented on February
19, 2004 are outlined as follows:
• A customer may return to Transitional Bundled Service (TBS) for a period of 80 days if the
customer’s intent is to find an ESP and continue on Direct Access Service. This period is
also referred to as Safe Harbor. Customers selecting TBS will pay spot market rates for
power for a certain period of time. (??? Aimee, should we refer the reader to the Billing
Chapter 7 or take out this last sentence about spot market rates?)
• A customer may return to Bundled Service by providing six months advance notice of their
decision to the utility. During the six months, the customer may switch from one Third
Party ESP to another. Once returned to Bundled Service, the customer will have to remain
on Bundled Service for three years. The three-year minimum Bundled Service
Commitment is known as Bundled Portfolio Service (BPS).
• A customer may request to return to Bundled Service without providing six months advance
notice to the utility. The customer will have to remain on Bundled Service for three years.
Customers that return to Bundled Service without six months notice will pay spot market
rates for power for a certain period of time. (??? Aimee, should we refer the reader to
the Billing Chapter 7 or take out this last sentence about spot market rates?)
To summarize, if an ESP elects to discontinue service to a customer or a customer decides to contract
with a different ESP for DA service, the customer enters TBS and then has 80 days to find a new ESP. If
the customer does not find a new ESP within 80 days, they are automatically returned to PG&E Bundled
Service for three years.
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ESP Inquiries
The following scenarios describe how customers may switch under the new guidelines.
• Direct Access Swith to Transitional Bundled Service. A DA customer returns to TBS
while looking for a new ESP. Either the customer contacts PG&E to enter TBS or the ESP
submits a Disconnect DASR, which automatically puts the customer in TBS for 80 days.
• Direct Access Customer Gives Notice to Return to BPS. A DA customer who is not in
TBS wants to return to BPS. The customer gives PG&E six-months notice and remains a
DA customer. During the six-month notice period, the customer can continue to switch
between ESPs. At month 5, PG&E generates a connect DASR for the account to return to
BPS.
• Direct Access Customer Requests Switch to BPS ASAP. A DA customer who is not in
TBS requests a return to BPS and the account switches per DA switching rules.
• Transitional Bundled Service Defaults to Bundled Portfolio Service. A DA customer
enters TBS while looking for a new ESP. The customer is unable to find a new ESP to
generate a connect DASR within the 80-day TBS period, so the customer defaults to BPS
for three years.
• Transitional Bundled Service Switch to Direct Access. A new ESP submits a connect
DASR for a customer in TBS. The account switches to DA per DA switching rules.
• Transitional Bundled Service Customer Gives Notice to Return to BPS. A DA
customer switches to TBS to look for a new ESP. While in TBS, the customer decides to
switch back to BPS. When the customer gives 6 months notice, PG&E switches the
account to BPS immediately instead of waiting 6 months to perform the switch.
• ESP Wants Its Meter Back. When an account switches from DA to TBS, the ESP may
contact PG&E to request its meter back. PG&E also contacts the ESP to determine whether
or not the ESP wants its meter returned. PG&E then makes arrangements to return the
meter to the ESP.
• Meter Work Not Completed Within 60 Days. If meter work is not completed within 60
days of an account switch, PG&E contacts the ESP to find out if the ESP will complete the
meter work. If the ESP has completed or will complete the meter work, PG&E updates its
systems to record the meter work. If the ESP will not complete the meter work, PG&E
schedules and performs the meter change. The account then switches to DA on the meter
change date or the next read date (whichever occurs first).
PG&E’s Meter Event Group works with ESPs to ensure that metering inquiries described below are
answered in a timely manner:
• Meter phone number
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• Meter installations to include installation job forecasting
• Research on the status/tracking of meters
• Meter configuration data
To contact a MEG analyst, see DA Contacts on the ESP Web site.
For passwords, contact PG&E’s Telemetering Support Center (TMSC) at 1-800-343-7013, Option 1.
In situations where the ESP intends to use phone-read meter technology and/or selects PG&E as its
MDMA, the ESP is responsible for:
• Establishing phone service
• Ensuring the phone service billing in its name
• Ensuring its telephone service provider installs a phone line for electric meter reading
• Or ensuring it provides PG&E with an activated cellular phone upon meter install
“Metering Phone Service Providers,” Appendix B of this handbook includes the names and telephone
numbers of providers within PG&E’s service territory.
When PG&E is the ESP’s MDMA the requirements below for wired phone lines and wireless phones
apply.
WIRED PHONE LINE REQUIREMENTS
The phone line shall be a dedicated phone line. If this is not feasible, the ESP should contact ESP
Relations to discuss other alternatives. (See “DA Contacts.”)
Additionally the phone line shall be:
• Installed from the phone minimum point of entry (MPOE) to the meter location. The ESP
should be aware that in some instances, the ESP may be required by the customer or phone
service provider to install a conduit, trench, or penetrate a fire wall in order to accommodate the
installation.
• A “measured business” line with blocking on long distance, collect, 900, and 976 calls
• Installed in accordance with applicable codes and standards
• Labeled to show:
• “For Electric Meter Use Only”
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• Telephone number
• Maintenance and repair telephone number
• Telephone service provider’s name
For security reasons, a telephone network interface unit (NIU) shall be installed at the phone line
termination point. A Joslyn telephone network interface model #7550, #7090 or equivalent should be
used, following the requirements below.
Generally, the NIU should not be mounted on the switchboard, meter panels, poles or pedestals. If these
are the only location choices, the mounting must be secure without compromising the safety aspects of
the particular enclosure. In the case of pole mounted terminations, the NIU should be placed below the
meter panel or otherwise not interfering with the pole climbing path.
The NIU should be installed within 5 circuit feet of the meter centerline and from a minimum of 18
inches to a maximum of 72 inches above finished grade. (A circuit foot is the length of wire or conduit
that needs to be run along walls, etc., from the meter to the NIU. It is not a straight-line distance.)
WIRELESS PHONE INSTALLATION REQUIREMENTS
For situations in which it is not feasible for the telephone company to install a hardwired phone service,
the ESP shall arrange for a cellular telemetry system to be installed and activated.
1. The cellular telemetry system shall meet the following specifications:
• NEMA 3R weatherproof enclosure
• Thermal shutoff protection
• 5% to 95% relative humidity, non-condensing
• Cellular radio with antenna connector
• Capacity to operate in 120VAC, 50 watts maximum output power
• User replaceable fuse
• Transient and overcurrent protection for RJ11 connections
• External ground lug
• One RJ11 jack for data and one RJ45 jack for communications
• Two wire, loop start
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• Ring voltage, 25Hz, 60 VRMs 150Vp-p
• 350 Hz/440 Hz square wave dial tone
2. RJ45 jack for cellular handset programming and testing
3. The power supply for cellular telemetry system shall be outside any sealed section and on the load
side of the meter. The power supply should further be on a dedicated circuit or otherwise connected
so that it is energized at all times.
4. Mounting of the cellular telemetry system shall be the same requirement as the installation of NIU as
described above.
5. The ESP shall ensure that any accessories to the cellular telemetry system, such as an antenna and a
mounting bracket, are properly installed or attached.
6. The ESP shall have the system activated and functionally tested prior to notifying PG&E that the site
is ready.
7. The cellular telemetry system unit shall be labeled to read, “For Electric Meter Use Only.”
8. The unit shall be further labeled to show:
• Telephone number
• Maintenance and repair telephone number, and
• Cellular telephone service provider’s name
The ESP is responsible for the maintenance, repair and replacement of the cellular telemetry unit.
Responsibility - Phone Service Account Payment
If an active phone line exists for a PG&E interval data meter and the ESP chooses to remove the meter
and install its own, PG&E will advise the phone service provider to cancel the account.
Or in those cases where the ESP is installing phone-read technology, PG&E will change billing from
PG&E to the ESP. Some review of phone account responsibility may be required for those sites where
PG&E uses the data for load research.
Responsibility - Phone Service Operability and Maintenance
When PG&E is the ESP’s MDMA, the ESP is ultimately responsible for the on-going phone line
operability.
The ESP must ensure that phone service is not turned off due to late or lack of payments to the phone
service provider. Monthly payments should be made directly to the phone service provider.
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Retention of Rights
Phone lines and phone ancillary devices used for remote meter reading are part of DA meters. Therefore,
the ESP must make certain that the phone line and any ancillary devices are maintained as required. Any
failure caused by phone line or phone ancillary devices shall be considered as meter failure and must be
corrected as required in Rule 22, Section G, Metering Services.
PG&E may exercise its right to test its own meters or those owned by customers in accordance with Rule
22, Section G, paragraph 2.
Meter Data Management Agent (MDMA) Requirements
This section addresses the major systems responsibilities and requirements that Meter Data Management
Agents (MDMAs) are required to perform. An MDMA is an entity that takes raw meter outputs,
validates them using validation, editing, and estimating rules, adds corollary information needed to
characterize the customer, and makes complete customer information available to others for use in
various applications. As some of the rules and requirements for interval and monthly (template data) are
different, the two usage types will be addressed separately.
MDMA responsibilities and requirements were established in decision 97-12-048 and the Retail
Settlement and Information Flow (RSIF) Workshops. Decision and workshop reports are available for
those interested in obtaining comprehensive information on MDMA responsibilities at the CPUC Web
site.
MDMA Approval Process and Requirements
The CPUC Decision on the Meter and Data Communication Standards Workshop Report of December 3,
1997, directed the UDCs to develop a MDMA qualification/approval process for ESPs and MDMAs who
wish to offer MDMA services.
The CPUC requires that potential MDMAs comply with current UDC standards in experience, education
and training in order to perform the following functions of an MDMA:
• Manage the meter reading schedule
• Read and retrieve meter data
• Submit meter data to MDMA server using DES protocol
• Calculate usage
• Validate, edit and estimate meter data
• Format data
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• Manage data on MDMA server
• Meter/device management
If the applicant is found to be compliant, the MDMA may immediately begin to serve accounts for which
the ESP has identified the specific MDMA relationship through the submission of DASRs. Inception of
MDMA service is also contingent upon the coordination between PG&E and the MDMA regarding read
scheduling.
APPLICATION AND CHECKLIST
The potential MDMA must complete the Application for MDMA Approval and checklist which are
available on the DA Documents link on the ESP Resource Center website at (see Information Websites at
the end of Chapter 1 in this handbook). The name of the document is MDMA Qualification Instructions.
The MDMA must forward the application and checklist per the specifications in the section below,
Written Requirements.
WRITTEN REQUIREMENTS
The potential MDMA forwards the completed application, the checklist as well as all written
requirements by mail or fax to:
Pacific Gas and Electric Company
Yolanda Lerma
P.O. Box 770000
M/C B19C
San Francisco, CA 94177
PG&E will review the submitted documentation of this test, determine if the potential MDMA is
compliant with its standards and notify the MDMA via e-mail. PG&E has established a goal of 10
business days to review the documentation and respond to the potential MDMA. Omitted documentation
of the submitted written requirements will result in PG&E requesting that additional information. If it is
deemed after the UDC’s review of the submitted written requirements that the potential MDMAs process
is insufficient, the potential MDMA will fail the written requirements portion and will need to resubmit
for qualification/approval.
SERVER ACCEPTANCE TEST
1. Subsequent to PG&E receiving the completed qualification documentation, the potential MDMA
may contact PG&E to schedule the acceptance test.
2. PG&E will work with the applicant to ensure that it meets hardware and software requirements and
will also send a sample test to the applicant prior to the test date.
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3. PG&E will then provide the potential MDMA with data for the server acceptance test. The purpose
of the server acceptance test is for the potential MDMA to demonstrate that it can calculate usage,
validate, estimate and edit usage; format the usage in the Electronic Data Interchange (EDI) format;
post the data to the potential MDMA’s server; and provide the UDC with access to the server.
Detailed steps are outlined in the MDMA Server Acceptance Testing document.
4. The acceptance test is then performed. The UDC’s have established a 48 hour turn-around time
requirement for the completion of this test.
5. If the potential MDMA fails the server acceptance test the first time, they can reschedule for re-test.
However, if a failure occurs twice, the potential MDMA must wait three months before re-testing
will be allowed.
6. In addition, re-testing will be required if new software is installed or if new technology is
implemented by the potential MDMA and their use of the server.
BACK-UP READING PROCESS
If the potential MDMAs primary source of reading meters is a method other than the manual process, the
potential MDMA, in addition to submitting documentation on its primary method must also demonstrate
that it has a capable back-up process in place. Details of the backup process is also outlined on the
checklist.
DATA FORMAT
MDMA data format requirements for each UDC is included with the application and checklist.
SECURITY AND CONFIDENTIALITY
Data security and confidentiality requirements are outlined in more detail by PG&E. However in
general, data must be located in a secure facility and have firewall or equivalent protection.
HELP DESK
The CPUC decision requires that a technical help desk be provided by the UDCs as well as MDMAs.
Each UDC must have toll free numbers available. The potential MDMAs must provide a technical
support number as well. This phone must be answered immediately during normal business hours.
However, after hour calls regarding the server must be returned within one hour. All other after hour
calls can be deferred to the next business day.
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Validating and Editing Data
The MDMA will be responsible for performing approved quality checks to the raw data retrieved from
the meters as described in the CA VEE Rules. The quality checks include validating and editing the
usage data. Upon completion of the validation and editing processes, an estimation will be performed on
the data, if necessary. Data estimations are summarized in the subsequent section “Estimating Data”. A
comprehensive description of the rules for validating, editing, and estimating is also addressed within the
CA VEE Rules document.
Below are the basic quality checks for interval and monthly data.
INTERVAL DATA
The interval data validations are summarized below. For a complete description of the rules, refer to the
CA VEE Rules (see Information Websites at the end of Chapter 1 in this handbook).
Spike Check. The highest interval recorded in a 24 hour calendar day cannot exceed the third
highest interval for that day by more than 180%. When a spike is identified, the usage for that
interval is flagged as missing and the estimation rules are used to fill the missing intervals.
High Low Average Daily Usage Check. An average daily total consumption is calculated
from the current month’s usage data and is compared to the average daily consumption
calculated from the previous year’s data for the same billing month, if last years data is not
available. If the current month’s average consumption is outside of plus or minus 50% of the
historical average consumption, then the MDMA must verify the usage (i.e., re-polling, meter
test, etc.). If the data is verified, the usage is flagged as verified and continues on the data flow
path.
Sum Check. The energy use recorded by the meter is compared to the energy use recorded by
the pulse recorder. If the difference is greater than two meter multipliers (constant used to
convert meter read to KWh), the data must be verified by the MDMA (i.e., repolling, meter test,
etc.). If the data is verified, the usage is flagged as verified and continues on the data flow path.
Hardware Checks. The MDMA must ensure that the polling device is synchronized to the
national time standard before data collection begins. The MDMA must verify that the time
difference in the meter device is within 180 seconds for a 30-day time period. An interval
tolerance check comparing the number of expected data intervals to the number intervals
received is performed to ensure the time drift is less than 5 intervals. See the CA VEE Rules for
a complete description of how to correct the time drift.
Kilovolt-Ampere-Reactive hours (KVARH) Checks (if collected). If the kWh channel has
zero consumption and for the corresponding time the kVARh channel has registered
consumption, the kWh data must be treated as missing. The kWh data should be estimated
using the estimation rules described in the CA VEE Rules.
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Estimating Data
Following the validation and editing (flagging usage as missing) of the usage data, the estimation
routines are performed to ensure that complete usage data will be provided for the given billing period.
Where raw data is available with incomplete entries, the MDMA will estimate the data gaps using
approved and documented algorithms. After performing the estimation the MDMA will be responsible
for providing the usage to the UDC and ESP. The following are the estimation rules for interval data.
INTERVAL DATA ESTIMATION RULES
Greater than two continuous hours of missing interval data:
1. Compute the average daily profile by using the days from the current usage period and as
much historical data (up to 90 days) as required to select three complete days (which were
not estimated) corresponding to the day of week or holiday with missing data. See the CA
VEE Rules for additional details on how to select historical data when three complete days
worth of data are not available.
2. If no historical holidays exist, use Sundays.
3. The historical data used should be that data immediately preceding the usage period,
regardless of seasonal crossover.
4. Estimate the missing data by applying the appropriate average daily profile to fill the
missing intervals.
Two hours or less of continuous missing interval data:
1. Use the point to point linear interpolation method to estimate the missing data where there
is a gap in the data.
2. If the gap occurs at the beginning of the span, use the last interval from the historical data as
the first point, if the historical data is available and the interval data is not estimated.
Otherwise, use the second point (the nearest good interval data) as the first point (i.e., a flat
load). If the gap occurs at the end of the span, use the first point as the second point (i.e., a
flat load).
Accuracy and Timeliness of Usage Data
All usage data will be accurate unless otherwise indicated. Data known to be inaccurate or missing will
be estimated and flagged as estimated data. The following accuracy and timeliness standards for interval
and monthly data must be followed by MDMAs. The accuracy and timeliness requirements stated below
were adopted by the CPUC in decision 97-12-048.
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INTERVAL DATA
Accuracy. Either no more than 10% of the accounts will contain estimated data, or no more that 1% of
all the data will be estimated.
Timeliness. Assuming that the meter read date is time zero:
• 80% of all usage data will be made available within 1 calendar day of the scheduled read
date of the meter
• 90% of all usage data will be made available within 2 calendar days of the scheduled read
date of the meter
• 99.99% of all usage data will be made available within 5 calendar days of the scheduled
read date of the meter
MONTHLY DATA
Accuracy. Either no more than 10% of the accounts will contain estimated data, or no more than 1% of
the data will be estimated.
Timeliness
Data retention period
• 85% of all the monthly meter reads will be made available by 6:00 am on the 1 st working day after
the scheduled meter read date.
• 95% of all the monthly meter reads will be made available by 6:00 am on the 2 nd working day after
the scheduled meter read date.
• 99.99% of all monthly meter reads will be made available by 6:00 am on the 5 th working day after
the scheduled meter read date.
On a monthly basis, the MDMA will provide interval data for the billing period in 27 to 33 measured
usage intervals. The interval may or may not be equal to a twenty four hour period depending upon the
meter read cycle and scheduling. Once the interval data or the monthly usage is posted to the MDMA
server it will remain available for 3 business days. Upon request, this data will be available after the
three-day business period. The MDMA must also store 36 months of historical consumption data.
Electronic exchange of metering data
The diagram below illustrates the flow of metering information from the meter to the ESP.
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ESP
Meter
Data Exchange Server
MV-90
Firewall
5.1 - METERING CONFIGURATION CHANGES AND METERING CHANGE OUTS
VEE
Process
Internal
Server
Currently, ESPs submit metering configuration changes and metering change-out requests by fax and not
by DASR. PG&E anticipates that electronic submission of these requests will be feasible by early 1998.
Metering configuration changes and metering change outs should be faxed to the MEG (see the DA
Contacts link on the ESP Resource Center website).
INTERVAL AND TIME-OF-USE (TOU) DATA
Interval data, which represents regular interval energy usage information (i.e. 5 minute, 15 minute,
hourly), is submitted via the DES in EDI 867 record format type. .
Time-Of-Use data, which is characterized by consumption reads at different time periods, is also
represented by using the DES in EDI 867record format type.
Field definitions and requirements for the EDI 867 record format types are provided in the the EDI 867
Guidelines located at PG&E’s EDI website http://www.pge.com/edi .
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Meter Reading
METER READING DATA OBLIGATIONS
1. Meter data for DA Customers shall be read, validated, edited, and transferred pursuant to CPUCapproved
standards.
2. Regardless of whether the ESP or PG&E perform Meter reading services, both PG&E and the ESP
shall have access to the server containing the data, including at a minimum the following data:
a) Customer account number;
b) Customer location;
c) Starting and ending read, date and time if available;
d) Usage data (e.g.; kWh, kW, interval use, kVArh if measured);
e) Estimated usage and adjustment flag or adjustment code;
f) Meter identification number;
g) ESP identification number;
h) Identity of metering agent, if any, employed by ESP or PG&E;
i) Load Profile ID (if applicable);
3. PG&E and the ESP shall provide reasonable and timely access to Meter data to the ISO, Scheduling
Coordinators (or their designated agents), and each other as required to allow the proper performance
of billing, settlement, scheduling, forecasting and other functions.
4. Until future notice, load point information will need to be communicated manually.
5. The Party providing Meter reading services is required to keep the most recent 12 months of
Customer consumption data for each DA Customer. Such data must be retained for a period of 36
months. Such data must be released on request to any ESP, or to PG&E, if authorized by the
Customer.
PG&E METER READING
1. PG&E will read DA interval meters for DA customers on PG&E’s read schedule for each service
account provided that the meter is compatible with PG&E’s meter reading systems and processes.
The ESP will be responsible for any meter reading costs for this service as set forth in DA Rule 22.
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2. PG&E, or its metering and data management agent (MDMA), will be required to install and maintain
a data server in accordance with standards approved by the CPUC.
ELECTRIC ESP METER READING
General Requirements.
1. No ESP may perform meter reading services for its own or any affiliated entity’s use of DA
Services.
2. No meter reading service may be provided by theESP until that ESP has been approved by
PG&E.
3. The ESP must keep PG&E notified at all times of the identity of the ESP’s agent, if any,
conducting Meter reading.
Schedule for ESP Meter reading. If the ESP or it’s agent perform meter reading, it must do so on
PG&E’s meter read schedule for that service account as specified by PG&E, unless a different schedule
is mutually agreed to by PG&E and ESP.
Metered Usage Rates
Metered usage rates are determined by end-use customers’ electric rate schedules. Electric rate schedule
information is available on PG&E’s Web Tariff Book Web site.
Life Support Customers and Medical Baseline Quantities
Life Support customers are residential end-use customers who have a medical disability necessitating the
use of a medical device(s) powered by utility supplied gas and/or electricity. These customers may
qualify for a Standard Medical Baseline Quantity in addition to their regular baseline quantity (i.e., gas
and/or electricity at the lowest Tier 1 residential rate). The Standard Medical Baseline Quantity is 500
kWh of electricity and/or 25 therms of gas per month year-round.
Additional amounts of gas and electricity (Medical Baseline Quantities) are available at the Tier 1 rate to
customers when a full-time member of the household is:
• dependent upon a medical life-support device used in the home.
• a paraplegic, hemiplegic, or quadriplegic person or a multiple sclerosis patient with special
heating and/or cooling needs.
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• a person being treated for a life-threatening illness or a person with a compromised immune
system with special heating and/or cooling needs to sustain the life of the person or prevent
deterioration of the person’s medical condition.
• a scleroderma patient with special heating needs.
ESPs who have identified end-use customers which require Standard and/or additional Medical Baseline
Quantities should refer to Electric Rule 14 for information concerning commodity service continuity and
Rule 19 for details on end-use customer qualifications. These rules can be found within PG&E’s Web
Tariff Book.
For information on additional DASR requirements when submitting DASRs for Life Support customers,
see the subsection, “Electric ESP evaluates customer DA elections and obtains customer information” in
Chapter 3: Processing Direct Access Service Requests.
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C HAPTER 6
DASR PROCESSES FOR
METERING DATA
ADJUSTMENTS AND CHANGES
Overview
This chapter covers information on PG&E DASR processes that are initiated as a result of metering data
adjustments and changes to DA account commodity status. The purpose of including this information in
the handbook is to foster Electric ESPs’ understanding of the PG&E-initiated transaction records it may
receive when certain account events take place and to make Electric ESPs aware of situations in which
they may need to initiate DASR transactions in response.
The processes and scenarios addressed include those, which occur subsequent to the initial DA customer
account switch. Additional DASR processes related to initial DA account setup and switching are
discussed in Chapter 3: Processing Direct Access Service Requests, under the section heading,
Additional DASR procedures performed by PG&E.
The material addressed includes details which are specific to DES transaction record types MEPAD01
(DASR), MEPMD01, and MEPMD02. Readers may want to familiarize themselves with these record
types and gain an understanding of regular metering data records before proceeding with the material in
this chapter. For detailed information on DES DASR transactions see the DES Transaction Map link on
the DES Web site.

DA Account Commodity Status Changes
DA Account Commodity Shut-Offs
PG&E can initiate the DA account commodity shut-off process if the end-use customer requests this
action or in cases of non-payment. The processes discussed do not apply to situations where the Electric
ESP decides to discontinue service to the end-use customer.
PROCESS
Please note that the following processes apply to both monthly, TOU, demand and interval metered
accounts.
1. When all meters associated with an account commodity have either been locked or removed, the
account commodity status is considered “Removed” or “Closed” by PG&E. Due to the frequency
with which end-use customers oftentimes change their commodity shut-off dates and also because of
the lack of lead time, PG&E will initiate disconnect notification to the Electric ESP after the final
shut-off meter read is taken and the Commodity Status of the account has been changed to
“REMOVED” or “CLOSED”.
2. PG&E will then issue an administrative data type record, MEPAD01, to the current, pending, and
any ancillary service providers communicating the date the account commodity was shut-off. This
transaction record will reflect “SVC” within the Operation Type field, “DISCONNECT” within the
Reason field, and the date the commodity was shut-off in the Effective End Date field.
3. PG&E will also issue the metering data record(s), MEPMD01 and/or MEPMD02 to the current
Electric ESP, and current bill-calculator if PG&E is not the MDMA. These records will include
usage information, but will not indicate that the end-use customer has been shut-off.
PG&E’s system should initiate the relevant administrative and metering data records within two (2)
business days following the account commodity status change.
MATRIX OF PG&E-INITIATED RECORDS RELATED TO SHUT-OFFS BY METER TYPE
The records indicated in the table below are issued by PG&E at the time the DA account commodity is
shut-off.
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ACTION ISSUE RECORD TO
CURRENT ELECTRIC ESP,
PENDING ELECTRIC ESP,
AND ALL ASSOCIATED
ELECTRIC ESPS
RECORD TYPE
ISSUED
MONTHLY SINGLE-
METERED
MONTHLY MULTI-
METERED
INTERVAL SINGLE-
METERED
INTERVAL MULTI-
METERED
ISSUE RECORD TO CURRENT
ELECTRIC ESP AND BILL
CALCULATOR
ISSUE RECORD TO
CURRENT ELECTRIC
ESP AND BILL
CALCULATOR
MEPAD01 MEPMD01 MEPMD02
One MEPAD01 record:
Operation Type field =
“SVC”
Reason field =
“DISCONNECT”
Effective End Date
Field = date the account
commodity was closed
One MEPMD01 record:
Normal start/end read
information record.
Same as above A MEPMD01 record for each
meter:
Normal start/end read
information record
Same as above 1. One or more MEPMD01
record(s), depending
upon interval and period
reported: normal
(monthly, not interval)
start/end read information
record.
2. One or more MEPMD01
record(s): normal usage
information record by
interval.
Same as above 1. One or more MEPMD01
record(s), depending
upon interval and period
reported: normal
(monthly, not interval)
start/end read information
record.
2. One or more MEPMD01
record(s): normal usage
information record by
interval.
Meter field = “TOTAL”
One MEPMD02
record:
Normal totalized
usage information
record.
A MEPMD02 record:
Normal totalized
usage information
record.
Meter field = “TOTAL”
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None
None

ACTION ISSUE RECORD TO
CURRENT ELECTRIC ESP,
PENDING ELECTRIC ESP,
AND ALL ASSOCIATED
ELECTRIC ESPS
ISSUE RECORD TO CURRENT
ELECTRIC ESP AND BILL
CALCULATOR
DEMAND METERED Same as above One MEPMD01 Record:
normal start/end red
information record
ISSUE RECORD TO
CURRENT ELECTRIC
ESP AND BILL
CALCULATOR
1. One MEPMD02
record: normal
usage
information
record
2. One MEPMD02
Record: normal
demand usage
information
TOU METERED Same as above None 1. One MEPMD02
record: normal
start read
information
2. One MEPMD02
record: normal
end read
information
3. One MEPMD02
record: normal
usage
information
record
EXAMPLE
Scenario: An interval meter customer has been billed from 5/15 to 6/15. The customer requests a shutoff
for 7/28.
Process:
1. PG&E will issue the metering data record(s), MEPMD01 and/or MEPMD02, to the current Electric
ESP as well as the bill-calculator if PG&E is not the MDMA for the period 6/15 to 7/15.
2. After the 7/28 shut-off is processed, the current Electric ESP, the pending Electric ESP, and any
ancillary service providers will receive an administrative data record MEPAD01, indicating that the
account commodity service has been disconnected and the effective date of 7/28.
3. The current Electric ESP, as well as the bill-calculator if PG&E is not the MDMA, will receive a
metering data record MEPMD01 for the period 7/15 to 7/28. This metering record will be initiated
as soon as the shut-off has been processed, it will not be subject to the timing of the customer’s
normal billing cycle.
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Meter Change
Exception: If a Lock Pending is issued, this means the account is marked to not bill until the account
commodity is closed (i.e., there will not be a bill for on-cycle bill on 7/15). In this case, the metering
records will be for the period 6/15 to 7/28.
A meter change should not cause an interruption of DA service. Monthly, interval, demand, and time-ofuse
(TOU) metered accounts should receive the metering records shown in the table below at the time of
the customer’s normal billing cycle.
MATRIX OF PG&E-INITIATED RECORDS RELATED TO METER CHANGE
The records indicated in the table below are issued by PG&E in correspondence with the customer’s
regular bill cycle.
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ACTION ISSUE RECORD TO CURRENT ELECTRIC
ESP AND BILL CALCULATOR
RECORD TYPE
ISSUED
MONTHLY SINGLE-
METERED
MONTHLY MULTI-
METERED
INTERVAL SINGLE-
METERED
MEPMD01 MEPMD02
• One MEPMD01 record for the old
meter: normal start/end read
information
Meter field = old meter number
• One MEPMD01 record for the
new meter: normal start/end read
information
Meter field = new meter number
• One MEPMD01 record for each
old meter removed: normal
start/end read information
Meter field = old meter number
• One MEPMD01 record for each
new meter installed: normal
start/end read information
Meter field = new meter number
• One MEPMD01 record for the old
meter: normal monthly (not
interval)start/end read information
Meter field = old meter number
• One MEPMD01 record for the
new meter: normal monthly (not
interval) start/end read
information
Meter field = new meter number
• One MEPMD01 record: normal
totalized usage record
Meter field = “TOTAL”
ISSUE RECORD TO CURRENT ELECTRIC ESP
AND BILL CALCULATOR
One MEPMD02 record:
Normal totalized usage information record
for both meters
Meter field = “TOTAL”
One MEPMD02:
Normal usage information record totalizing
usage for all meters.
Meter field = “TOTAL”
None
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ACTION ISSUE RECORD TO CURRENT ELECTRIC
ESP AND BILL CALCULATOR
INTERVAL MULTI-
METERED
• One MEPMD01 record for each
old meter: normal start/end read
information
Meter field = old meter number
• One MEPMD01 record for each
new meter: normal start/end read
information
Meter field = new meter number
• One MEPMD01 record: totalized
usage record
Meter field = “TOTAL”
DEMAND METERED • One MEPMD01 record for the old
meter: normal start/end read
information (kwhreg)
Meter field = old meter number
• One MEPMD01 record for the
new meter: normal start/end read
information (kwhreg)
Meter field = new meter number
ISSUE RECORD TO CURRENT ELECTRIC ESP
AND BILL CALCULATOR
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10/5/05 Page 77
None
• One MEPMD02 record for the old
meter: usage information (kwh)
• One MEPMD02 record for the new
meter: usage information (kwh)
• One MEPMD02 record for the old
meter: demand usage information (kw)
• One MEPMD02 record for the new
meter: demand usage information (kw)

ACTION ISSUE RECORD TO CURRENT ELECTRIC
ESP AND BILL CALCULATOR
ISSUE RECORD TO CURRENT ELECTRIC ESP
AND BILL CALCULATOR
TOU METERED None • One MEPMD02 records for the old
meter: start reads information
EXAMPLE
Meter field = old meter number
• One MEPMD02 records for the new
meter: start reads information
Meter field = new meter number
• One MEPMD02 records for the old
meter: end reads information
Meter field = old meter number
• One MEPMD02 records for the new
meter: end reads information
Meter field = new meter number
• One MEPMD02 record for the old and
new meters’ totalized usage
information
Meter field = “TOTAL”
Scenario: 1/2 was the last on cycle billing read date with a read of 00500. On 1/15 there was a meter
change, and the old meter had an end read of 00550. The new meter had a start read of 00000. On 2/2
the billing cycle end read was 00060. Thus, the billing cycle usage reflects 50 kWh for the old meter and
60 kWh for the new meter for a total of 110 kWh totalized usage.
Process:
1. PG&E will issue to the Electric ESP, the appropriate metering data type records, (MEPMD01,
MEPMD02) on 2/2. The appropriate metering data type records will show the old meter number
and new meter number start/end reads as described in the above matrix. The metering data record
for usage will indicate “TOTAL” in the Meter Field.
NEW METER SETS WHICH ARE NOT CONCURRENT WITH OLD METER REMOVALS
The example above assumes that the new meter is set on the same day that the old meter is removed. In
reality, there may be situations where the old meter is removed, but the new meter cannot be set on the
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same day. In these cases, the account Commodity Status will be changed to “REMOVED” until the new
meter is set.
If the account is a dual commodity, the Commodity Status for the commodity receiving the new meter
will be changed to “OPEN” after the new meter has been set and the Account number and XREF ID
fields will remain unchanged.
If the account is a single commodity, a new account may be created after the new meter has been set. A
new XREF ID will be created if a new account number is created.
For both dual and single commodity accounts, an account status of CLOSED or REMOVED will require
PG&E’s system to initiate a disconnect notice to the Electric ESP. The Electric ESP will be required to
initiate a SP-REQ/CONNECT MEPMD01 record to re-establish the account once the Commodity Status
changes to “OPEN”.
METER CONFIGURATION DATA
PG&E will communicate the new meter configuration information to Electric ESPs through its Metering
Event Group (MEG).
Usage Adjustments
Usage adjustments occur when previously reported usage for the account requires modification. The
modification can be read and/or usage changes or changes in the reported periods (i.e., billing dates,
interval period). PG&E communicates usage adjustments to ESPs through Electronic Data Interchange
(EDI 867). The EDI 867 Guidelines has a code in the BPT segment that identifies corrected usage as
“CO” located in the BPT01. There is also an adjustment code that is in QTY01 of the EDI 867. This
code is “A5”. The QTY segment is in the PTD loop. The adjusted reads/usage records for an account
will reflect the correct reads/usage for a period which has already been reported. The metering data
records will reflect usage amounts only and not dollar values associated with usage. The initiation of
adjustment records is not dependent upon the timing of the end-use customer’s billing cycle. Therefore,
PG&E can issue adjustment records to the ESP immediately following an adjustment transaction at any
time during a billing cycle.
For more detailed information regarding usage adjustments, please refer to the EDI 867 Guidelines
located at http://www.pge.com/edi.
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USAGE ADJUSTMENTS TO MONTHLY METER DATA DUE TO ADDITIONAL VALIDATION
CHECKING OF DATA WHEN PG&E IS THE MDMA
One reason adjustments may occur when PG&E is the MDMA for monthly meter data is because
PG&E continues to perform validation of meter data after that data is sent to ESPs. PG&E uses
several systems to validate meter data. A metering record will sometimes pass initial validation
checks, and fail later checks. Data is sent to the ESP after the initial checks. If potential problems
are identified as the record is passed through additional tests, the information is re-verified to
determine if there is in fact an error. In many cases, the data is not in error and does not have to be
adjusted. However, when there is an error, adjustments need to be made to the data. Adjustments
made in accordance with the processes described in the subsequent sections of this document are
then sent to the ESP.
MATRIX OF PG&E-INITIATED RECORDS RELATED TO USAGE ADJUSTMENTS
The records indicated in the table below are issued by PG&E at the time the adjustment is made.
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ACTION ISSUE RECORD TO CURRENT ELECTRIC
ESP AND BILL CALCULATOR
RECORD TYPE
ISSUED
MONTHLY SINGLE-
METERED
MONTHLY MULTI-
METERED
INTERVAL SINGLE-
METERED
INTERVAL MULTI-
METERED
MEPMD01 MEPMD02
• One MEPMD01 record with the
adjusted read in the Data field for
each adjusted period
Example for a two months
adjustment:
Data field = “199804150001,
,750,199805150001,A,1300”
Data field =
“199805150001,A,1300,19980615
0001,A ,1650”
• One MEPMD01 record for the
adjusted meter, with the adjusted
reads in the Data field (similar to
monthly single-metered reads
adjustment record).
Meter field = adjusted meter number
• One or more MEPMD01 record(s)
with adjusted start/end reads
information record (similar to
monthly single-metered reads
adjustment record).
• One or more MEPMD01 record(s)
with adjusted totalized usage
(similar to monthly single-metered
usage adjustment record).
ISSUE RECORD TO CURRENT ELECTRIC ESP
AND BILL CALCULATOR
One MEPMD02 record for each adjusted
period with the adjusted total usage
Example for a two months adjustment:
Eff Start field = “199804150001”
Eff End field = “199805150001”
Data field = “TOTAL,A,550”
Eff Start field = “199805150001”
Eff End field = “199806150001”
Data field = “TOTAL,A,350”
One MEPMD02 record for each adjusted
period with the adjusted totalized usage for
all the meters (similar to single-metered
usage adjustment record).
Meter field = “TOTAL”
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None
Same as above. None
DEMAND METERED • One MEPMD01 record with the
adjusted reads in the Data field
(similar to monthly single-metered
reads adjustment record).
• One MEPMD02 record with the
adjusted total usage in the Data field
(similar to monthly single-metered
usage adjustment record).
• One MEPMD02 with the adjusted
demand usage information (similar to
the monthly single-metered usage
adjustment record).

ACTION ISSUE RECORD TO CURRENT ELECTRIC
ESP AND BILL CALCULATOR
ISSUE RECORD TO CURRENT ELECTRIC ESP
AND BILL CALCULATOR
TOU METERED None • One MEPMD02 record with the
adjusted start reads information
EXAMPLE
• One MEPMD02 record with the
adjusted end reads information
• One MEPMD02 record with the
adjusted totalized usage information
Scenario: A monthly metered account has been billed in the following manner and the normal
MEPMD01 and MEPMD02 record(s) have already been sent to the Electric ESP when the account was
billed:
ELECTRIC ESP
NAME
DATE MEPMD02
USAGE
MEPMD01:
START READ
PG&E 2/15 -3/15 400 KWH 0 400
PG&E 3/15 - 4/15 350 KWH 400 750
ESP 4/15 - 5/15 500 KWH 750 1250
ESP 5/15 - 6/15 400 KWH 1250 1650
END READ
On 6/23 a correction is made to the period 4/15 - 5/15. The usage for the period should have been
reported as 550 kWh with an end read of 1300. Then on 6/26 a correction is made to the period 5/15 -
6/15. The usage should have been 350 kWh with an end read of 1650.
Process:
Under the given scenario PG&E would issue the records shown in the table below when the adjustment is
made to the account.
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TIMING ORDER RECORD TYPE
ISSUED
DATA INCLUDED IN RECORD
1. MEPMD01 Data field = 199804150001, ,750,199805150001,A,1300
2. MEPMD02 Eff Start field = 199804150001
Eff Stop field = 199805150001
Data field = TOTAL,A,550
3. MEPMD01 Data field = 199805150001,A,1300,199806150001,A,1650
4. MEPMD02 Eff Start field = 199805150001
Eff Stop field = 199806150001
Data field = TOTAL,A,350
Records for items 1 and 2 will be sent on the same day (6/23) when the bill period 4/14 - 5/15 is adjusted.
Then the records for items 3 and 4 will be sent on the same day (6/26) when the bill period 5/15 - 6/15 is
adjusted. The timing between the sending of the two sets of records will be around 3 days and based on
when each adjustment transaction is processed.
STAND ALONE REBATE TRANSACTIONS (REVERSAL ONLY ADJUSTMENT)
Under some circumstances only a rebate transaction will need to be made to the account. A rebate is a
reversal of what was originally billed. This business scenario may occur when PG&E needs to reverse a
bill and then wait for the next on cycle bill to rebill the account. In this situation, PG&E’s system will
wait for three (3) processing days after a rebill transaction is processed by the biller. If the rebill
transaction does not occur within three (3) processing days of the rebate, the system will interpret the
rebill as an reversal only adjustment and send the rebate as a meter adjustment record reversing the reads,
and with 0 usage. When the rebill transaction is eventually processed through the system, then the rebill
transaction will be sent to the Electric ESP’s as adjusted reads/usage records.
Using the same scenario as the previous example, adjust the billing for the bill period of 5/15 - 6/15. The
adjustment is to just reverse the bill and let next month’s on cycle read generate the rebill. So, on 6/20, a
reversal is processed. On 6/23, the system did not receive the rebill for 5/15 to 6/15, so it assumed the
biller wanted to do just a reversal only adjustment. The system will send to the Electric ESP the
following records on 6/23:
MEPMD01 - DATA field = 199805150001,A,1250,199805150001,A,1250
MEPMD02 - Eff Start field = 199805150001 Eff Stop field = 199805150001 DATA field = TOTAL, A,0
On 7/15 - the next on cycle billing, the following records will be sent. Note that since the billing period
includes the bill period that was reversed, the quality code will be A to indicate an adjustment to a
previously sent metering data record.
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MEPMD01 - DATA field = 199805150001, ,1250,199807150001,A,1850
MEPMD02 - Eff Start field = 199805150001 Eff Stop field = 199807150001 DATA field =
TOTAL,A,600
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C HAPTER 7
ELECTRIC ESP ACCOUNT
BILLING
Overview
This chapter focuses on ongoing DA billing and credit related issues, which are not a part of the initial
DA setup process. The material covers bill processing; the collection and disbursement of funds for
either PG&E or the Electric ESP with respect to Consolidated UDC billing; Consolidated ESP billing,
and Separate billing.
Bill Components and Billing Options
Summary of bill components
Utility bills which are sent to end-use customers are required to show “unbundled” charges listed on the
bill. These unbundled charges consist of the following components:
• Generation
• Transmission
• Distribution
• Public Purpose Programs (PPP)
• California Energy Commission Tax (ECT)

• CTC
• Nuclear Decommissioning
• Energy Procurement Surcharge
About the California Energy Commission Tax
In keeping with the developments of electric direct access, the California State Board of Equalization
decided that the Energy Commission Tax (ECT), will be billed and collected by PG&E, for all UDC
Consolidated Billing. The utility distribution company will cease billing of this tax immediately when
the customer’s service is switched to direct access. The customer’s current Electric ESP will assume the
responsibility of billing and collecting this tax from the customer effective with the direct access service
switch date. The Electric ESP is responsible for remitting the ECT to the California State Board of
Equalization.
The ECT, also known as the California Energy Resources Surcharge, applies to the consumption of
electrical energy. It is intended to provide funding for the California Energy Commission. The
regulations for ECT are covered in the California Administrative Code, Title 18, Chapter 2, Subchapter
5, Article 1, which states:
“Every electric utility making sales of electrical energy to consumers in this state shall collect
the surcharge from each consumer other than a consumer that is an electric utility or is exempt
under Chapter 3, part 19, of the Revenue and Taxation Code, at the time it collects its billing
from the consumer for the electrical energy sold. A consumer is any person receiving electrical
energy furnished by an electric utility and includes a person receiving electrical energy for
redistribution for the use of this tenants.”
The ECT rate, which is subject to revision from time to time, is currently set at two-tenths of a mil
($0.0003) per kilowatt-hour. It is shown as a separate line item on the customer’s bill.
The ECT is based on the consumption of electrical energy and applies to all but the following end-use
customers:
1. The United States, its unincorporated agencies and instrumentalities
2. Any incorporated agency or instrumentality of the United States wholly owned by either the United
States or by a corporation wholly owned by the United States
3. The American National Red Cross, chapters, and branches
4. Insurance companies, including title insurance companies, subject to taxation under the California
Constitution, Article XIII, Section 28
5. Indians purchasing and consuming electrical energy on Indian reservations
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Billing options
6. Career consular officers and employees of certain foreign governments who are exempt from tax by
treaties and other diplomatic agreements with the United States
7. Federal credit unions organized in accordance with the provisions of the Federal Credit Union Act.
Questions regarding the tax exemption and remittance timelines should be directed to the State Board of
Equalization. Additional information may be found in the Revenue and Taxation Code.
Customer bills will reflect the total amounts charged for each of the bill items described in the table
above regardless of the billing option which the customer chooses at the time of DA sign-up. Again the
billing options available to end-use customers are:
CONSOLIDATED UDC BILLING
Under the Consolidated EDC billing option, the Electric ESP will send its rate schedules to PG&E.
PG&E will then compute the Electric ESP’s charges based upon the Electric ESP’s rate schedules and
customer meter data and send a consolidated invoice to the DA customer which will include both Electric
ESP’s and PG&E’s charge amounts. Rate schedule information is available within PG&E’s Web Tariff
Book Web site.
PG&E will purchase the Electric ESP’s receivables under the terms and conditions set forth in PG&E’s
tariffs.
CONSOLIDATED ESP BILLING
Electric ESPs who elect to offer Consolidated ESP billing may choose Partial Consolidated ESP billing
or Full Consolidated ESP billing pursuant to PG&E’s DA Rule 22. Prior to providing either of these
billing options, the Electric ESP must meet CPUC-specified creditworthiness requirements. The
differences between Partial Consolidated ESP and Full Consolidated ESP billing options are described
below.
PARTIAL CONSOLIDATED ESP BILLING
Under Partial Consolidated ESP billing, PG&E will calculate and send its bill to the Electric ESP. The
Electric ESP in turn will then send a consolidated bill to the customer. The Electric ESP is not
responsible for the accuracy of PG&E’s charges.
FULL CONSOLIDATED ESP BILLING
Under the Full Consolidated ESP billing option, the Electric ESP will read the meter, calculate both the
UDC and ESP charges and bill the customer. The Electric ESP will detail PG&E’s charges in
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conformance with PG&E’s specifications. The Electric ESP must obtain PG&E’s consent and approval
prior to offering Full Consolidated ESP billing to its customers, and must also comply with all relevant
provisions under PG&E’s DA Rule 22.
SEPARATE BILLING
Under Separate billing, customers receive two bills, one from the Electric ESP detailing their fees and
one from PG&E detailing PG&E fees.
Although an Electric ESP can select Separate billing as a service option, PG&E may also under certain
circumstances require an Electric ESP to proceed under Separate billing for reasons including but not
limited to the items below.
• If the Electric ESP selected Consolidated UDC billing but the ESP’s rate schedule was not properly
received when the DASR was transmitted, PG&E will establish Separate billing for the
corresponding end-use customers. Consolidated UDC billing, in this case would be established once
the Electric ESP resubmitted the rate schedule and the schedule data was entered into PG&E’s
systems.
• If the current Electric ESP has defaulted on the terms and conditions of ESP Consolidated billing
under either PG&E’s ESP Service Agreement or DA Rule 22, PG&E will establish separate billing
for that end-use customer.
• If an Electric ESP has indicated that it would like to offer Consolidated ESP billing but has not
fulfilled creditworthiness and/or EDI requirements, PG&E will require the Electric ESP to proceed
under Separate billing.
Read and Bill Serial Dates
Because multiple services may be represented on one bill, the meter Read Date will not always be equal
to the Bill Date. PG&E will retain the serial system currently in use and apply it towards the Read and
Bill cycles. Both Read and Bill serials will be communicated to the ESP via the acknowledgement
(ACK) DASR.
Consolidated UDC Billing
The Electric ESP and PG&E will work together to establish the ESP’s billing information in PG&E’s
billing system. For a fee, PG&E can generate Consolidated UDC bills for Electric ESPs and serve as the
collection agent as well. Set up fees are based upon PG&E rate schedule E-ESP.
When DA begins, PG&E will offer Electric ESPs Rate Ready pricing options. In order to calculate the
Electric ESPs charges for Rate Ready options, PG&E will need the rate structure(s) and rate schedules
that the Electric ESP has selected. The Electric ESP may have up to 100 rate schedules. The Electric
ESP will then populate the rate schedules with their respective rates and prices.
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Pricing options
Electric ESPs communicate Rate-ready pricing options by completing the PG&E Consolidated Billing
Pricing Worksheet. The following exhibit is an example of the worksheet.
7.1 - PG&E CONSOLIDATED BILLING PRICING WORKSHEET
The Electric ESP must complete and submit the PG&EConsolidated Billing Pricing Worksheet for every
pricing change that it wants to make. The worksheet can be downloaded from the “DA Documents” link
on the PG&E’s ESP Resource Center Web site or obtained by contacting ESP Services at 415-973-1666.
Completed worksheets should be faxed to ESP Services at 415-973-2194.
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The following Rate Ready pricing options will be available in on the DA implementation date:
FLAT ($/MONTH)
Also referred to as fixed price, a flat rate structure is a non-volumetric set cost that is billed per month
regardless of the amount of the customer’s usage.
An additional flat rate to cover monthly Electric ESP administrative customer charges may be combined
with this rate structure.
SINGLE-TIERED ($/KWH)
A single-tiered rate structure is a set cost billed per usage unit (kilowatt-hour or therm). The customer’s
energy charge will vary according to the amount of electricity consumption per month.
A flat rate to cover monthly Electric ESP administrative customer charges may be combined with this
rate structure.
DOUBLE-TIERED ($/KWH, ELECTRIC ESP DESIGNATES TIERS)
A double-tiered rate structure has two set costs billed per usage unit (kilowatt-hour or therm) which is
charged whenever a usage baseline or threshold is designated. The first-tier price will apply until the
usage threshold is exceeded. The second-tier price will apply to any usage above the designated
threshold. The customer’s energy charge will vary according to the amount of electricity consumption
per month.
A flat rate to cover monthly Electric ESP administrative customer charges may be combined with this
rate structure.
TIME-OF-USE - TOU ($/KWH, BASED ON PG&E’S TIERS)
A TOU structure is a combination of set costs billed per usage unit (kilowatt-hour or therm) based on
consumption during a particular period of the day. Depending on the customer class and the installed
metering device, TOU pricing may have up to three different rates for three different peak periods. The
TOU periods are on-peak, partial-peak, and off-peak. Rates are more expensive during the on-peak
periods, when more customers demand energy. Customers may tailor their energy consumption during
the off-peak hours to take advantage of the low off-peak rates. The customer’s energy charge will vary
according to the amount of electricity consumed during a particular time of the day.
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Bill format
CUSTOM PRICING
A rate plan that does not fit with any of the above four pricing structures is considered custom pricing.
On an individual case basis, PG&E will evaluate an Electric ESP’s customized pricing structure to
determine whether it can be accommodated and implemented by PG&E.
SUBMITTING RATE-READY DATA TO PG&E
Electric ESPs should contact PG&E’s ESP Billing Services (ESPBS - see the “DA Contacts" link on
PG&E’s ESP Resource Center Web site) to discuss transmission requirements prior to submitting rateready
data.
DEADLINES FOR THE SUBMISSION OF RATE-READY DATA
In order for PG&E to send out consolidated bills which include Electric ESP billing information for a
given DA billing cycle, the Electric ESP must provide the following information to ESPBS by the dates
specified:
• Electric ESP billing rates and structures at least thirty (30) days prior to the billing cycle end date.
• Customer list with associated Electric ESP billing rates at least fifteen (15) days before the billing
cycle end date.
There is a fee for a rate change based on PG&E’s rate schedule E-ESP. If the Electric ESP should
require custom programming, ESPBS will make a concerted effort to fulfill the requirements specified
within the time frame above but cannot guarantee billing implementation for that billing cycle period.
PG&E will include the Electric ESP’s logo on the page of the customer’s bill which details Electric ESP
charges. However, the Electric ESP must provide ESPBS with the company information that must
appear on the bill (i.e. Electric ESP’s name, address, telephone number) as well as the Electric ESP’s
company logo. The logo should be provided in the form of a bitmap image file. All details regarding the
Electric ESP bill page format are addressed in the Direct Access Consolidated Billing Options Worksheet
which can be located and downloaded from the “DA Documents” link on the ESP Resource Center Web
site.
Bill preparation and processing
PG&E will prepare the consolidated bill according to the procedures outlined below.
1. PG&E will calculate the Electric ESP’s energy cost charges. The Electric ESP’s rate schedule is
used to calculate the energy cost component. Information regarding the submission of rate schedule
information by the Electric ESP is covered within Chapter 3: Processing DASRs.
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2. PG&E’s charges for transmission, delivery, PPPs, CTC, and other charges that may apply to a given
customer, are calculated separately using the customer’s PG&E rate schedule.
3. The Electric ESP’s charges are then combined with PG&E’s charges onto one bill.
4. Utility user taxes, if applicable, are calculated on the total of the PG&E and Electric ESP combined
charges.
5. Other processing functions such as the update of receivables, payments, credits, debits, and other
adjustments are performed by PG&E to generate the Consolidated UDC bill.
Bill Printing and Delivery
1. Bills will follow the format designated by the Electric ESP in the Direct Access Consolidated Billing
Options Worksheet, to include the layout, logos, and other enclosures specified.
2. A printed copy of the bill is mailed to end-use customers on Summary Billing and to those end-use
customer not on Electronic Data Interchange (EDI).
3. If the customer has an EDI Trading Partner Agreement in place with PG&E and has followed the
requirements for implementing EDI as outlined in Chapter 2: DA Setup, PG&E can submit invoices
to the end-use customer electronically.
Reports generated by PG&E
Daily Billing File
Since the billing process is a collaborative effort, it requires constant communication between the Electric
ESP and PG&E. Reports are the method by which PG&E and the Electric ESP coordinate their
consolidated billing effort. Reports are sent manually by PG&E in an electronic format, to the Electric
ESP. Contents of the report include data relating to rate schedule changes and billed data and revenue.
Reports are created daily.
The daily billing file consists of two sections. The first section includes the billing data. He second
section includes any adjustments made to a particular bill.
Utility User Tax Application
Under the rate-ready billing type, PG&E will calculate any applicable utility user taxes on the total of the
PG&E and Electric ESP combined charges. PG&E will apply the utility user tax, including exemptions
and caps based on PG&E’s agreement with the governing cities and counties in PG&E’s service territory.
Under the bill-ready billing type, PG&E, will apply utility user taxes on the Electric ESP’s charges.
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Remittance of utility user tax is the responsibility of each party, PG&E, and Electric ESP for their
respective taxable charges. PG&E will report the taxes billed on the Electric ESP charges to the Electric
ESP. PG&E will only remit the utility user tax collected to the Electric ESP. The Electric ESP is
responsible for remitting the utility user tax to the governing authority.
How PG&E calculates Electric ESP payments
WHEN A CUSTOMER MAKES PAYMENT TO PG&E
The portion due to the ESP is then forwarded on the the ESPs financial institution. This is done via ACH
wire fund transfer, using banking data provided by the ESP.
Because the amount deposited to the bank is one lump sum, PG&E then sends to the ESP an electronic
file which lists the detail for that deposit (customers’ names, account ID’s and associated remittance
amounts) since this payment file is sent automatically, the ESP must provide PG&E with one e-mail
address where the report is to be sent.
PAYMENTS FROM ELECTRIC ESP TO PG&E
Payments from the Electric ESP to PG&E encompass service charges for billing services, which PG&E
provides on behalf of the Electric ESP. The Electric ESP will be responsible for the payment of PG&E’s
charges on an ongoing basis while Consolidated UDC billing is in effect. Charges are dependent upon
the transactions incurred during a given month, and Electric ESPs are billed once a month for these
charges by PG&E. Service charge amounts billed can vary for each account specified under the
Consolidated UDC billing option. Charges associated with Consolidated UDC billing are specified on
PG&E’s Web Tariff Book Web site. PG&E, upon ten (10) days written notice, may net any past due
payment for associated Consolidated UDC billing services, as outlined in Rate Schedule E-ESP (see
PG&E’s Web Tariff Book Web site), against payments by PG&E on the Electric ESP’s accounts
receivable.
Consolidated ESP Billing
Consolidated ESP billing involves the transmission of charges for transmission, distribution, PPP, and
CTC from PG&E to the Electric ESP.
BILL FORMAT REQUIREMENTS
PG&E requires that Electric ESPs provide detailed page showing PG&E related charges according to a
standardized format. Electric ESPs should consult the PG&E Bill Format for Consolidated ESP Billing
document for detailed requirements on the representation and transmission of PG&E billing information.
The document can be downloaded from the “DA Documents” link on the ESP Resource Center.
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CALCULATION OF CHARGES OWED TO PG&E
PG&E calculates charges for a given service account’s electric transmission and distribution services.
Transmission and distribution charge information is then sent electronically to the Electric ESP for
inclusion in the Electric ESP’s bill.
PAYMENT PROCESSING
Once PG&E’s charges are calculated, these charges are transmitted to the Electric ESP through
Electronic Data Interchange (EDI). The Electric ESP is responsible for payment to PG&E regardless of
whether or not it receives payment from the end-use customer. The Electric ESP must submit payments
to PG&E via EDI as discussed below.
ELECTRONIC DATA INTERCHANGE (EDI)
Electric ESPs wishing to provide billing services for PG&E must meet EDI requirements (see Chapter 2:
DA Setup for detailed information). EDI is the adopted standard for the transmission of charge
information from PG&E to the Electric ESP and for PG&E’s subsequent receipt of payments from the
Electric ESP. Service accounts that are billed through Consolidated ESP billing must be added to the list
of EDI customers for a given Electric ESP.
Separate Billing Procedures
Under the Separate billing option, both PG&E and the Electric ESP will bill the end-use customer
individually for their respective charges. Neither billing nor payment information is exchanged between
the Electric ESP and PG&E since each entity is responsible for the billing and collection of payments
associated with Separate billing service accounts.
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C HAPTER 8
CUSTOMER INFORMATION
RELEASES
Overview
This chapter provides information on how Electric ESPs participating in DA with PG&E can obtain
certain types of customer information.
Confidential Customer Information Release
Electric ESPs have the opportunity to request customer specific information that includes energy usage
for the last 12 billing transactions.. In order to request information for a customer, the Electric ESP will
be required to obtain and provide ESP Services with a signed Customer Information Release form and
indicate the specific customer account number(s). The form can be obtained from the “DA Documents”
link on the ESP Resource Center website. The signed form should be faxed to Robert Reeder at (415)
973-2194 or e-mailed to rwr6@pge.com.
The following data will be provided in the customer information release:
• Service ID • Meter Number
• Customer Name • Meter Read Date (current/prior)
• Service Address • Billing Cycle Days
• Billing Address • TOU Split (Demand & Energy)

• SIC 2 • Total revenue for last 12 billing periods
• Rate Schedule • Total kWh for last 12 billing periods
Note: Load research sample data will not be included in the release of customer
information.
PG&E will forward the information described above within 10 working days of its receipt of the Electric
ESP’s request. PG&E will provide DA customer data free of charge for up to two times a year.
However, a charge of $40.00 per data set will apply to subsequent requests. Data format options include
hard copy report, floppy disk or e-mail file.
Regarding a request status contact Robert Reeder at (415) 973-5480 or e-mail rwr6@pge.com.
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G LOSSARY
DIRECT ACCESS TERMS
APPLICANT A person or agency requesting PG&E to supply electric service or for charges in electric service.
Electric service may consist of both energy and energy related services.
APPLICATION An oral, electronic, or a written request to PG&E for electric service; not an inquiry as to the
availability or charges for such service. The form of the request shall be at PG&E’s discretion.
BASELINE A rate structure mandated by the California Legislative and implemented at PG&E in 1984 that
insures all residential customers are provided a minimum necessary quantity of electricity at the
lowest possible cost.
BILLING AGENT The billing agent prepares and submits bills to end-use customers; collects and processes
payments; and remits aggregate funds and records to its clients.
BILLING CYCLE The regular interval at which a bill for electric service is rendered; typically spans a 27 to 33 day
period.
BILLING DEMAND The demand on which the customer is to be billed in accordance with the terms and conditions
of their applicable rate schedule.
BILLING FACTOR Factor used to calculate a bill on a daily basis as opposed to monthly, when the billing period is
other than 27 to 33 days. All rate schedules assume monthly billings of 27 to 33, and the Billing
Factor for these billings is equal to 1. The factor is used to adjust flat monthly charges (such as
fixed usage accounts), monthly customer, monthly meter, and minimum service charges to
monthly parity when an account is billed for fewer than 27 days (Billing Factor is less than 1), or
when billed for more than 33 days (Billing Factor is greater than 1). The factor is based on 365
days divided by 12 months, which is 30.4166, the number of average days in an average month.
The billing Factor formula is:
Billing Factor = Number of Billing Days divided by 30.4166
BILLING MONTH The period of time over which a customer is billed for services rendered during a particular
billing cycle.
BILLING SERVICE DATE The effective date for commencement of either of the direct Access Consolidated Billing options.
BUSINESS DAY A day on which PG&E offices are open to conduct general business in California.
COMMISSION The Public Utilities Commission of the State of California, sometimes referred to as the Public

COMPETITIVE TRANSITION
CHARGE (CTC)
Utilities Commission (PUC) or the CPUC.
Defined in Public Utilities Code Section 840 and by the Commission.
CONNECTED LOAD The sum of the rated capacities of all the customer’s equipment that can be connected to
PG&E’s lines at any one time as more completely described in the rate schedules.
CPUC (CALIFORNIA PUBLIC
UTILITIES COMMISSION)
The Public Utilities Commission of the State of California.
CURTAILMENT The temporary reduction or interruption of service to customers because of projected or actual
supply or capacity constraints, as further defined in Rule 14 and PG&E’s Electrical Emergency
Plan. PG&E may also request such load reduction under the provisions of its nonfirm programs.
CUSTOMER The person, group of persons, firm, corporation, institution, municipality, or other civic body, in
whose name service is rendered, as evidenced by the signature on the application, contract, or
agreement for that service, or in the absence of a signed instrument, by the receipt and payment
of bills regularly issued in that name, regardless of the identity of the actual user of the service.
a customer may take Full Service or Direct Access Service, but must take final delivery of
electrical power, and not resell that power.
DEMAND The amount of energy drawn by a Customer at a specific time. Typically expressed in kilowatts
or kW.
DEMAND CHARGE One component of an electric customer’s bill (along with, but not limited to, the customer charge,
meter charge, and the energy charge). This charge recovers some of the costs PG&E incurs in
providing sufficient operating capacity to meet that customer’s maximum demand. The demand
charge is based on the highest level of kW required by the customer during a billing period.
DIRECT ACCESS METER A meter meeting the Commission’s requirements to support Direct Access Service to a Direct
Access Customer not eligible for a Load Profile.
DIRECT ACCESS SERVICE Defined in Rule 22.
DIRECT ACCESS SERVICE
REQUEST (DASR)
An application for Direct Access Service submitted to PG&E on behalf of a Customer by an
Electric ESP, as described in Rule 22.
DISTRIBUTION LOSS FACTORS The loss of energy over distribution lines are categorized into two distinct loss factor types:
Distribution Line Losses and Total Distribution System Losses.
Distribution Line Losses consist of:
• losses due to resistance in the distribution lines
• transformer core losses
Total Distribution System Losses consist of:
• distribution line losses
• metering error - the difference between the actual electric usage at the meter and
the recorded meter read plus any differences due to malfunctioning meters
• energy theft - the deliberate and unauthorized use of energy
DISTRIBUTION SERVICES The delivery of electrical supply and related services by PG&E to a customer over PG&E’s
Distribution System.
DISTRIBUTION SYSTEM Those non-ISO transmission and distribution facilities owned, controlled, and operated by PG&E
that are used to provide Distribution Service under these tariffs.
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ELECTRIC SUPPLY OR
PROCUREMENT SERVICES
ELECTRONIC DATA INTERCHANGE
(EDI)
ENERGY SERVICE PROVIDER
(ESP)
FIXED TRANSITION AMOUNT (FTA)
CHARGE
FULL SERVICE As defined in Rule 22.
Includes, but is not limited to, procurement of electric energy; all scheduling; settlement, and
other interactions with Scheduling Coordinators, the ISO and the PX; all ancillary services and
congestion management.
The electronic transmission and receipt of data and/or funds in agreed upon formats in
accordance with PG&E’s specifications.
An entity who provides electric supply services to DA Customers within PG&E’s service territory.
An ESP may also provide certain metering and billing services to its DA Customers as provided
for within these tariffs.
A non-bypassable, separate charge that is authorized by the Commission to be charged to
residential and small commercial customers to allow PG&E to recover financed transition costs
and the costs of providing, recovering, financing or refinancing transition costs, including the
costs of issuing, servicing, and retiring Rate Reduction Bonds.
GENERATION CUSTOMER Any PG&E electric customer with electric generation facilities (including back-up generation in
parallel with PG&E) on the customer’s side of the interconnection point.
INDEPENDENT SYSTEM OPERATOR
(ISO)
The California Independent System Operator Corporation, a state chartered, non-profit
corporation that controls the transmission facilities of all participating transmission owners and
dispatches certain generating units and loads. The ISO is responsible for the operation and
control of the statewide transmission grid.
KILOWATT 1,000 watts; a watt is a unit of electrical power equal to a current of one ampere under one volt
of pressure.
KILOWATT-HOUR 1,000 watts, or one (1) kilowatt of electricity used for one hour.
LOAD PROFILES An approximation of a Customer’s electric usage pattern as approved by the Commission for
certain purposes set forth in PG&E’s tariffs.
MASTER-METERED CUSTOMER A PG&E Customer who takes Full or Direct Access Service at a single “master meter” and
distributes electric supply, by its own means, to tenants within its own premises. The availability
of master metering is limited by Rule 18 and the P.U. Code.
MASTER-METERING Where PG&E installs one service and meter supply more than one residence, apartment
dwelling unit, mobile home space, store, office, etc.
METER The instrument that is used for measuring the electricity delivered to the Customer. In certain
circumstances, the terms “meter” or “metering” also include related metering facilities or
equipment.
METER DATA MANAGEMENT
AGENT (MDMA)
METER SERVICE PROVIDER
(MSP)
METERING FACILITIES OR
METERING EQUIPMENT
the entity that takes raw meter outputs, validates them using validation, editing, and estimating
rules, adds corollary information needed to characterize the customer, and makes complete
customer information available to others for use in various applications.
The entity that installs, validates, registers, and maintains the physical meter required on a
premise to measure the required variables.
A meter, its associated current and potential transformers, test facilities, communication
interfaces, and other associated metering equipment required for the measurement of supply
deliveries to a Customer’s Account.
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OPTIONAL RATE SCHEDULES Commission-approved rate schedules for a customer class from which any customer in that
class may choose. Optional rate schedules do not include experimental schedules or schedules
available at the sole option of PG&E.
PAID OR PAYMENT Funds received by PG&E through the postal service, PG&E payment office, PG&E authorized
agent, or deposited in PG&E’s bank account by Electronic Data Interchange.
PERSON Any individual, partnership, corporation, public agency, or other organization operating as a
single entity.
POWER EXCHANGE (PX) The California Power Exchange Corporation, a state chartered, non-profit organization charged
with establishing a competitive spot market for electric power through day and hour ahead
auction of generation and demand bids, in accordance with the PX Tariff.
POWER EXCHANGE SUPPLY COST PX supply costs will be shown as either the cost of PX energy purchased by PG&E for a full
Service Customer’s use, or the credit for a Direct Access Customer.
POWER FACTOR The percent of total power delivery (kV) which does useful work. for billing purposes, average
power factor is calculated from a trigonometric function of the ratio of reactive kilovolt-amperehours
to the kilowatt-hours consumed during the billing month.
PREMISES All of the real property and apparatus employed in a single enterprise on an integral parcel of
land undivided, excepting, in the case of industrial, agricultural, oil field, resort enterprises, and
public or quasi-public institutions, by a dedicated street, highway or public thoroughfare or
railway. Automobile parking lots constituting part of land adjacent to a single enterprise may be
separated by an alley from the remainder of the Premises served.
PUBLIC PURPOSE PROGRAMS
CHARGES
A non-bypassable surcharge imposed on all retail sales of electricity and electrical services to
fund public goods research, development and demonstration, energy efficient activities, and low
income assistance programs.
PUBLIC UTILITIES COMMISSION The Public Utilities Commission of the State of California.
QUALIFIED CONTRACTOR/
SUBCONTRACTOR (QC/S)
An applicant’s contractor or subcontractor who:
• is licensed in California for the appropriate type of work such as, but not limited
to, electrical and general;
• employs electric workmen properly qualified (Qualified Electrical Worker,
Qualified Person, etc.) as defined in State of California High Voltage Safety
Orders (Title 8, Chapter 4, Subchapter 5, Group 2); and
• complies with applicable laws such as but not limited to, Equal Opportunity
Regulations, OSHA, and EPA
RATE SCHEDULE One or more tariff sheet(s) setting forth the charges and conditions for a particular class or type
of service in a given area or location. A rate schedule includes all of the wording on the
applicable tariff sheet(s), such as Schedule number, title, class of service, applicability, territory,
rates, conditions, and references to rules.
RULES Tariff sheets which cover the application of all rates, charges, and services when such
applicability is not set forth in and as part of the rate schedules.
SCHEDULED METER READING
DATE
The date PG&E has scheduled a Customer’s meter to be read for the purposes of ending the
current billing cycle and beginning a new one. PG&E’s meter reading schedule is published
annually, but is subject to periodic change.
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SCHEDULING COORDINATOR An entity meeting requirements as set forth by the Commission, FERC, and these tariffs.
SERVICE ID A PG&E-specific identifier for tracking energy service deliveries for a specific load through one
or more meters at a customer premises or location. one customer may have several accounts
within a premises or throughout PG&E’s service territory.
SETTLEMENT QUALITY DATA With respect to metering, validated or estimated interval data that is formatted into hourly usage
data. This data includes monthly cumulative data that has been converted to an hourly format
by the application of an approved load profile.
SETTLEMENT READY DATA With respect to metering, settlement quality data that has had the appropriate distribution loss
factors applied and is aggregated for delivery to the scheduling coordinator.
SUBMETERING Where the master-metered customer installs, owns, maintains, and reads the meters for billing
the tenants in accordance with Rule 18.
TARIFF SHEET An individual sheet of tariff schedules.
TARIFFS The entire body of effective rates, rentals, charges, and rules, collectively, of PG&E, including
title page, preliminary statement, rate schedules, rules, sample forms, service area maps, and a
list of contracts and deviations.
TIME-OF-USE Rate option that prices electricity according to the season or time of day that it is used. Such
usage is aggregated into discrete time periods, which are called “TOU” periods and are as
specified in the PG&E rate schedules.
TRANSMISSION LOAD CUSTOMER A PG&E electric customer, interconnected to PG&E’s power system at a transmission level
voltage, who has no generation of its own paralleled with the PG&E system and is not
interconnected with any generation source other than PG&E.
UTILITY Pacific Gas and Electric Company (PG&E).
UTILITY USERS TAX A tax imposed by local governments on PG&E’s customers. PG&E is required to bill customers
within the city or county for the taxes due, collect the taxes from customers, and then pay the
taxes to the city or county. The tax is calculated as a percentage of the charges billed by PG&E
for energy use.
XREF ID A unique non-changing customer-commodity-location specific number. Once the XREF ID has
been assigned to a DA commodity account, it will not change throughout the life of the account
unless DA is cancelled. Essentially, the XREF ID provides a way to readily identify DA
commodity accounts and to reference the history of the commodity even if the customer
switches to different ESPs.
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A PPENDIX A
SERVICE TERRITORY CITY
CODES
CITY CODE LETTERS CORRESPOND TO THE SECOND AND THIRD CHARACTERS OF THE CUSTOMER ACCOUNT NUMBER.
CITY NAME CITY
CODE
ACADEMY TK
ACAMPO AK
ADAMS SPRINGS ZH
AGNEW VP
AGUA CALIENTE NV
AHWAHNEE AE
ALAMEDA JP
ALAMO AL
ALBANY AB
ALBION QA
ALDER SPRINGS FJ
ALDER SPRINGS TK
ALDERPOINT G4
ALEXANDER VALLEY NH
ALLEGHANY IU
ALLENSWORTH AF
ALMANOR Q1
ALPAUGH AF
ALTA H1
ALTAVILLE XB
ALTO NK
ALTON KT
ALVISO AV
AMADOR CITY QB
AMBOY T3
AMERICAN CANYON NY
ANCHOR BAY P2
ANDERSON AS
ANDERSON SPRINGS ZM
ANDRUS ISLAND PP
ANGELS CAMP XB
ANGWIN N2
ANNAPOLIS 1N
ANNAPOLIS 1N
ANTELOPE AN
ANTIOCH JC
APPLEGATE H2
APTOS AP
ARBUCKLE DB
ARCATA AC
ARGUS TD
ARNOLD XA
AROMAS XK
AROMAS XK

ARROYO GRANDE AG
ARROYO GRANDE AG
ARROYO SECO GF
ARTOIS 9A
ARVIN AR
ASTI 2N
ATASCADERO WW
ATHERTON AT
ATWATER AW
AUBERRY AU
AUBURN HB
AUBURN HB
AUCKLAND TJ
AUKUM XD
AVENAL AZ
AVERY XY
AVILA BEACH AA
AVON JG
BACHELOR VALLEY ZU
BADGER AD
BAKER RANCH GE
BAKERSFIELD TC
BAKERSFIELD TC
BAKERSFIELD TC
BALLARD B7
BALLICO BQ
BANGOR YB
BANTA X2
BASS LAKE LD
BAXTER H3
BAY POINT DP
BAYLISS FJ
BAYSIDE YS
BAYWOOD PARK LG
BEALE AFB BY
BEAR VALLEY 9S
BEAR VALLEY ZS
BEAR VALLEY 2T
BEAR VALLEY
SPRING
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TR
BELDEN Q9
BELL SPRINGS LM
BELLA VISTA VH
BELLA VISTA VH
BELMONT RN
BELVEDERE NU
BEN LOMOND BP
BENBOW LM
BEND FN
BENICIA BE
BERENDA TN
BERKELEY JR
BERKELEY JR
BERRY CREEK IY
BETHANY XV
BETHEL ISLAND BI
BETTERAVIA BX
BIEBER UQ
BIG BEND UD
BIG BEND H8
BIG BEND VILLAGE DS
BIG LAGOON LF
BIG MEADOW TJ
BIG OAK FLAT EF
BIG SPRINGS FP
BIG SUR ME
BIGGS JM
BIOLA BA
BIRCHVILLE HM
BIRDS LANDING P7
BIRDS LANDING PP
BITTERWATER BJ
BLACK POINT NM
BLACKWELLS
CORNER
TX
BLAKES LANDING MM
BLOCKSBURG KD
BLOOMFIELD NN
BLUE CANYON H5
BLUE LAKE CQ
BLUE LAKE CQ

BODEGA BB
BODEGA BAY BB
BODEGA BAY BB
BOGARD STATION FF
BOLINAS BZ
BONNY DOON VT
BOONVILLE UF
BOOTJACK TS
BORON BO
BOULDER CREEK BC
BOWLES TT
BOWMAN HB
BOYES HOT SPRINGS 7N
BRADLEY DC
BRADLEY DC
BRANNAN ISLAND PP
BRANSCOMB W9
BRENTWOOD BW
BRICELAND LM
BRIDGEPORT HM
BRIDGEVILLE KE
BRIGHTON PS
BRISBANE AH
BROOKDALE BD
BROOKS 2P
BROWNS FLAT XR
BROWNS VALLEY BL
BROWNSVILLE IV
BRUSH CREEK IH
BRYTE WS
BUCKINGHAM PARK ZK
BUCKS LAKE FP
BUELLTON B9
BUMBLEBEE XR
BURLINGAME BS
BURNEY FF
BURNT RANCH L3
BURREL BF
BURREL BF
BURSON XI
BURSON XI
BUTTE CITY ET
BUTTE MEADOWS F1
BUTTONWILLOW BU
BYRON BN
CACHAGUA CY
CACHUMA 3B
CADIZ 2C
CALAVERAS BIG
TREES
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XA
CALIFORNIA VALLEY 3C
CALISTOGA N3
CALPELLA UG
CALWA TK
CAMANCHE XD
CAMBRIA KA
CAMDEN TT
CAMERON PARK GS
CAMINO GP
CAMP CONNELL XA
CAMP MEEKER CR
CAMP MONTECITO TJ
CAMP SACRAMENTO HT
CAMPBELL CM
CAMPBELL CM
CAMPO SECO XE
CAMPO SECO VS
CAMPTONVILLE IQ
CANTUA CREEK KK
CANYON J2
CANYON DAM Q4
CAPAY FJ
CAPAY 3P
CAPITOLA CP
CARBONA XV
CARIBOU FP
CARLOTTA KH
CARMEL CE
CARMEL HIGHLAND CE
CARMEL VALLEY CY
CARMEL VALLEY CE

CARMICHAEL CA
CARRISA PLAINS T4
CARSON HILL XB
CARUTHERS CB
CARUTHERS CB
CASMALIA B6
CASPAR QC
CASSEL UR
CASTLE GARDENS TR
CASTRO VALLEY CV
CASTROVILLE CT
CATHEYS VALLEY CZ
CAWELO TX
CAYTON VALLEY FF
CAYUCOS KY
CAZADERO 4N
CEDAR FLAT LW
CEDAR GROVE TJ
CEDAR RIDGE JE
CEDARBROOK TJ
CENTERVILLE FB
CENTERVILLE KQ
CENTERVILLE TK
CENTRAL VALLEY VE
CERES AJ
CERES AJ
CHALLENGE YQ
CHAMBLESS TD
CHEROKEE FM
CHESTER Y8
CHICAGO PARK JF
CHICO FB
CHILES VALLEY N3
CHINESE CAMP EJ
CHOLAME DG
CHOWCHILLA TP
CHOWCHILLA TP
CHRISTIAN VALLEY HB
CHROME FJ
CHUALAR CF
CISCO GROVE H8
CITRUS HEIGHTS CH
CLARKSBURG CG
CLARKSVILLE HT
CLAY XF
CLAYTON CL
CLEAR CREEK Q7
CLEARLAKE ZC
CLEARLAKE OAKS ZE
CLEARLAKE PARK ZP
CLEMENTS KM
CLEONE NF
CLINGANS JUNCTION TJ
CLINTON XD
CLIPPER GAP HB
CLIPPER MILLS IM
CLOVERDALE ND
CLOVIS CI
CLYDE CD
COALINGA TF
COARSEGOLD GO
COBB ZH
COHASSET FB
COLD CREEK NX
COLD SPRINGS YU
COLFAX HF
COLLEGE CITY CC
COLLINSVILLE PP
COLMA AI
COLOMA GQ
COLUMBIA YW
COLUSA PX
COMPTCHE UH
CONCORD JG
CONCOW FM
CONEJO TT
CONFIDENCE XR
COOL GD
COPPEROPOLIS XC
CORCORAN TG
CORDELIA PK
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 106

CORDELIA PJ
CORNING WF
CORRAL DE TIERRA BT
CORRALITOS VX
CORTE MADERA CN
COTATI CO
COTTONWOOD KO
COTTONWOOD KO
COULTERVILLE CX
COULTERVILLE CX
COVELO W7
COW CREEK SR
COYOTE VR
CRESCENT MILLS EY
CRESSEY CS
CRESSMAN AU
CRESTON DQ
CROCKETT CK
CROWS LANDING X6
CUMMINGS G5
CUNNINGHAM NR
CUPERTINO VV
CUSHENBURY
SPRINGS
TD
CUTLER CW
CUTTEN LF
CUYAMA VALLEY CJ
DAGGETT TD
DAIRYVILLE FN
DALY CITY RB
DANA DY
DANVILLE DD
DAVENPORT DN
DAVIS PY
DAYTON FB
DE SABLA FM
DEER PARK N4
DEHAVEN QW
DEL LOMA L1
DEL PASO HEIGHTS PS
DEL REY DR
DEL REY DR
DEL REY OAKS BT
DELEVAN PX
DELFT COLONY TJ
DELHI 1X
DENAIR DK
DENAIR DK
DENVERTON FS
DERBY ACRES DE
DIABLO DL
DIAMOND SPRINGS GT
DIBBLE CREEK FN
DIGIORGIO TC
DILLON BEACH ZD
DINSMORE KE
DINUBA TJ
DINUBA TJ
DIXON PF
DIXON PF
DOBBINS DO
DONNER SUMMITT H8
DORRINGTON XA
DOS PALOS DZ
DOS PALOS (SOUTH) DT
DOS PALOS (SOUTH) TM
DOS PALOS Y TM
DOS RIOS W6
DOUGLAS FLAT XG
DOWNIEVILLE HJ
DRUM VALLEY TJ
DRYTOWN QD
DUBLIN DU
DUNCAN MILLS M1
DUNLAP DI
DUNNIGAN DB
DUNNIGAN DB
DURHAM DH
DUSTIN ACRES DA
DUTCH FLAT H4
EARLIMART EA
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 107

EAST NICOLAUS HP
EAST NICOLAUS NO
EAST OAKLAND JQ
EAST PALO ALTO EP
EASTON TK
ECHO LAKE HT
EDISON TC
EDWARDS ED
EDWARDS (NORTH) ED
EDWARDS AFB ED
EEL ROCK LM
EL CAMINO WF
EL CERRITO EC
EL DORADO GV
EL DORADO HILLS GW
EL GRANADA VG
EL MACERO EO
EL NIDO EN
EL PORTAL EL
EL SOBRANTE ES
EL VERANO NV
ELDERWOOD WJ
ELDRIDGE NV
ELK P3
ELK CREEK 9E
ELK GROVE EG
ELK RIVER LF
ELKHORN BT
ELMIRA EI
ELVERTA EV
ELVERTA EV
ELVERTA EV
EMERYVILLE EM
EMIGRANT GAP H5
EMMET B6
EMPIRE ER
ENTERPRISE FQ
ESCALON X5
ESCALON X5
ESHOM VALLEY TJ
ESPARTO 4P
ETTERSBURG 1G
EUREKA LF
FAIR OAKS FO
FAIR PLAY HT
FAIRFAX FX
FAIRFIELD PJ
FAIRHAVEN AM
FAIRMEAD TP
FALL RIVER MILLS UE
FALLON ZB
FAMOSO TX
FARMINGTON FA
FEATHER FALLS IF
FELLOWS FW
FELTON FE
FERNBRIDGE KJ
FERNDALE KQ
FETTERS HOT
SPRINGS
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 108
NV
FIDDLETOWN QE
FIELDBROOK OX
FIELDS LANDING YL
FINLEY ZF
FIREBAUGH FG
FISH CAMP YF
FITCH MOUNTAIN NH
FIVE POINTS FT
FLORIN PS
FLOURNOY OF
FOLSOM FL
FORBESTOWN IT
FORD CITY TV
FOREST IX
FOREST GLEN 8F
FOREST KNOLLS FK
FOREST RANCH F9
FORESTHILL GE
FORESTVILLE FV
FORESTVILLE FV
FORT BRAGG NF

FORT ORD SS
FORT ORD MA
FORT ROSS 5N
FORT SEWARD 2G
FORTUNA LJ
FOSTER CITY FC
FOUR COURNERS TD
FOWLER FI
FRANKLIN PS
FRANZ VALLEY NL
FREEDOM XM
FREEPORT PS
FREESTONE NR
FREMONT JJ
FRENCH CAMP FH
FRENCH CAMP FH
FRENCH CORRAL JO
FRENCH CORRAL IJ
FRENCH GULCH ZG
FRESH POND HT
FRESHWATER LF
FRESNO TK
FRESNO TK
FRIANT FR
FRIANT FR
FRIANT FR
FRUITLAND LM
FRUITVALE TC
FULTON FU
GALT GA
GALT GA
GANNS MEADOW XA
GARBERVILLE LM
GARDEN VALLEY GG
GARDENLAND PS
GAREY BX
GENERAL GRANT
GROVE
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 109
TJ
GENESEE EZ
GEORGETOWN GH
GERBER GB
GEYSERS ND
GEYSERVILLE NC
GILROY VF
GLEN ELLEN 6N
GLENBURN DX
GLENCOE QV
GLENHAVEN ZJ
GLENN 9G
GOLD HILL HT
GOLD LAKE IG
GOLD RIVER RA
GOLD RUN H6
GONZALES GZ
GOODYEARS BAR JD
GRAND ISLAND PP
GRANITE BAY HS
GRANITE BAY KR
GRANITE STATION TC
GRAPEVINE TC
GRASS VALLEY HM
GRATON GR
GRAYSON X7
GREELEY HILL 7G
GREENACRES TC
GREENBRAE LK
GREENFIELD GF
GREENFIELD TC
GREENVILLE YG
GREENWOOD GI
GRIDLEY FD
GRIMES ZA
GRIMES ZA
GRIZZLEY BLUFF LJ
GRIZZLY FLATS GX
GRIZZLY ISLAND FS
GROVELAND YY
GROVER BEACH GC
GUADALUPE B8
GUALALA P4
GUERNEVILLE NG

GUERNSEY TG
GUINDA 5P
GUSTINE GU
GUSTINE GU
HACIENDA FV
HALCYON AG
HALES GROVE LM
HALF MOON BAY RH
HAMES VALLEY DC
HAMILTON CITY 9H
HAMILTON FIELD NM
HAMLET NN
HAMMONTON HP
HANFORD HA
HANFORD HA
HANFORD HA
HARDON FLAT XR
HARDWICK TT
HARMONY T7
HARRIS 4G
HARTLAND TJ
HASTINGS ISLAND PP
HAT CREEK US
HATHAWAY PINES XO
HAUSNA AG
HAWKINS BAR L8
HAYWARD JK
HEALDSBURG NH
HEART MEADOW TJ
HELM HE
HENLEYVILLE WF
HERCULES HR
HERITAGE RANCH BR
HERNDON TK
HICKMAN HC
HIGHWAY CITY TK
HILLCREST FF
HILLSBOROUGH HL
HILMAR HQ
HILTON NG
HOBERGS ZH
HOLLISTER BG
HOLLYDALE PARK NR
HOLMES LJ
HOLY CITY VJ
HOLY CITY VJ
HONCUT FQ
HONEYDEW KU
HONEYDEW KU
HOOPA L1
HOPETON TR
HOPLAND UI
HORNITOS HN
HORSE CORAL FLAT TJ
HUB TT
HUGHSON HG
HUGHSON HG
HUMBOLDT HILL LF
HUME LAKE HK
HUMPHREYS
STATION
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 110
TK
HUNTER LIG RES JO
HURLETON FQ
HURON HU
HYDESVILLE KV
IGNACIO NM
IGO W1
INDIAN FALLS FP
INVERNESS IN
INYOKERN C9
IONE QF
IOOF PARK NG
IRWIN XX
ISLAND MOUNTAIN 3G
ISLETON P8
JACKASS HILL XR
JACKSON XD
JACKSONVILLE XR
JACOBY CREEK LF
JAMESTOWN YZ
JARBO GAP FM

JEFFERSONVILLE XR
JENNER 5N
JENNY LIND XT
JOHNSON PARK TU
JOLON JO
JONESVILLE FB
JOYCE ISLAND FS
KEDDIE Y3
KELSEY G1
KELSEYVILLE ZK
KENSINGTON KN
KENTFIELD KF
KENWOOD KW
KERMAN TH
KETTENPOM LM
KETTLEMAN CITY KC
KEYES 2X
KEYES 2X
KEYSTONE XR
KING CITY BJ
KING SALMON LF
KINGS CANYON
NATIONAL PARK
KG
KINGSBURG KI
KINGSBURG KI
KINGVALE H8
KIRKWOOD WF
KNEELAND KL
KNIGHTS FERRY XN
KNIGHTS LANDING KS
KNIGHTSEN K3
KNOWLES TN
KORBEL KB
KRAMER JUNCTION TD
KYBURZ GY
LA GRANGE LR
LA HONDA LH
LA HONDA LH
LA PORTE IL
LA PURISMA 2B
LA SELVA BEACH VX
LAFAYETTE LY
LAGUNITAS LU
LAKE ALMANOR Q2
LAKE BERRYESSA N7
LAKE DON PEDRO SX
LAKE DON PEDRO CX
LAKE DON PEDRO LR
LAKE MADRONE FQ
LAKE OF THE PINES HM
LAKEHEAD LB
LAKEPORT NJ
LAMONT LT
LANARE TT
LARGO UI
LARKFIELD NR
LARKSPUR LK
LAS CRUCES 2B
LAS DELTA TM
LASSEN CAMP MW
LATHROP LP
LATHROP LP
LATHROP LP
LATON LX
LATON LX
LATROBE HT
LAYTONVILLE W8
LAYTONVILLE W8
LE GRAND LQ
LEBEC LE
LEESVILLE 9S
LEGGETT 5G
LEMOORE TL
LIBERTY FARMS PK
LINCOLN HD
LINCOLN HD
LINDA HP
LINDEN LI
LITTLE GRASS
VALLEY
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 111
IL
LITTLE NORWAY 8R

LITTLE RIVER QL
LITTLE VALLEY W5
LIVE OAK LO
LIVE OAK LO
LIVERMORE JN
LIVINGSTON LV
LOCH LOMOND ZO
LOCKEFORD LC
LOCKWOOD VW
LODI XF
LODOGA FJ
LOLETA KX
LOLETA KX
LOMA MAR VM
LOMA RICA HP
LOMPICO FE
LOMPOC 2B
LONDON TJ
LONE STAR TK
LONG BARN EB
LONGVALE NZ
LONOAK BJ
LOOMIS LZ
LOOMIS LZ
LOS ALAMOS B4
LOS ALTOS LA
LOS ALTOS HILLS LA
LOS BANOS TM
LOS BERROS AG
LOS GATOS VJ
LOS GATOS VJ
LOS MOLINOS OM
LOS OLIVOS B5
LOS OSOS LG
LOST HILLS LL
LOTUS 8S
LOVELOCK FM
LOWER LAKE ZL
LUCERNE ZI
LUCERNE VALLEY T8
LYONSVILLE PC
LYTTON NC
MAD RIVER KZ
MADERA TN
MADERA TN
MADISON 6P
MAGALIA F3
MAGUNDEN TC
MALAGA TK
MANCHESTER P1
MANILA LF
MANTECA XH
MANTECA XH
MANTON MQ
MAPLE CREEK LF
MARICOPA MF
MARICOPA HEIGHTS TV
MARINA MA
MARINWOOD NQ
MARIPOSA TS
MARSHALL MM
MARSHALL MM
MARSHALL STATION TK
MARTELL QP
MARTINEZ MR
MARTINS BEACH RH
MARYSVILLE HP
MATHER AFB MN
MAXWELL EU
MC ARTHUR UU
MC CANN LM
MC CLELLAN FIELD PS
MC FARLAND MC
MC KINLEYVILLE MV
MC KITTRICK MK
MEADOW LAKES TK
MEADOW VALLEY EX
MEADOW VISTA GJ
MEADOWMONT XB
MENDOCINO QM
MENDOTA MY
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 112

MENLO PARK MP
MERCED TR
MERCED FALLS TR
MERIDIAN EK
MERRITT ISLAND PP
METTLER STATION MZ
MI WUK VILLAGE UW
MICHIGAN BLUFF GE
MIDDLETOWN ZM
MIDPINES TS
MILL CREEK MX
MILL VALLEY NK
MILLBRAE MI
MILLVILLE MJ
MILPITAS ML
MINERAL MW
MINKLER SR
MINTURN TN
MIRABLE PARK FV
MIRAMONTE MU
MIRANDA 6G
MISSION DISTRICT SL
MISSION HILLS 2B
MO TRIANGLE TV
MOCCASIN YY
MODESTO XJ
MODESTO XJ
MOJAVE T5
MOKELUMNE HILL QT
MOKELUMNE HILL QT
MOLINO NR
MONMOUTH TT
MONO PINES XR
MONO VISTA XR
MONSON TJ
MONTA VISTA VV
MONTARA VD
MONTE RIO ZR
MONTE SERENO MS
MONTEREY BM
MONTGOMERY
CREEK
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 113
UT
MOONSTONE BEACH LF
MOOSE CAMP FF
MORAGA MG
MORGAN HILL MH
MORGAN HILL MH
MORRO BAY MB
MOSS BEACH VK
MOSS LANDING MD
MOUNT AUKUM GP
MOUNT AUKUM 8P
MOUNT AUKUM
(NORTH)
8P
MOUNT BULLION TS
MOUNT HAMILTON VP
MOUNT HERMON MT
MOUNTAIN RANCH XQ
MOUNTAIN REST TK
MOUNTAIN VIEW VL
MUIR BEACH OW
MUROC TD
MURPHYS XU
MYERS FLAT G6
NAPA NL
NASHVILLE HT
NAVARRO UJ
NAVELENCIA RV
NELSON NA
NEVADA CITY HH
NEW CUYAMA 3N
NEW IDRIA AY
NEWARK NE
NEWBERRY SPRINGS C4
NEWCASTLE GK
NEWMAN XL
NEWVILLE FJ
NICASIO N8
NICE ZN
NICOLAUS NO
NIMSHEW FM
NIPINNAWASEE TQ

NIPOMO B2
NIPOMO B2
NORD FB
NORDEN H8
NORTH COLUMBIA HM
NORTH FORK NT
NORTH HIGHLANDS HI
NORTH SAN JUAN IO
NORTHWOOD ZR
NOVATO NM
NOYO NF
NUBIEBER UV
O'BRIEN LB
O'NEALS ON
OAK RUN OU
OAK RUN OU
OAK SHORES BR
OAK SHORES DC
OAKDALE XN
OAKHURST TQ
OAKLAND JQ
OAKLAND JQ
OAKLEY OK
OAKVILLE OQ
OCCIDENTAL OC
OCCIDENTAL OC
OCEANO OO
ODD FELLOWS EB
OIL CENTER TC
OILDALE TC
OLD CUYAMA TV
OLD RIVER TC
OLD STATION UX
OLEANDER TK
OLEMA OA
OLIVEHURST OL
OMO RANCH HX
ONO V3
OPHIR HB
ORA VISTA FQ
ORANGE COVE OE
ORANGEVALE OV
ORCUTT 4B
ORD BEND FJ
OREGON CITY FM
OREGON HOUSE OH
ORICK OI
ORINDA OR
ORLAND FJ
ORLEANS L2
OROSI OS
OROVILLE FQ
OROVILLE FQ
ORRS HOT SPRINGS NX
OSWALD HP
OUTINGDALE HT
PACHECO PA
PACIFIC GROVE PG
PACIFIC HOUSE HV
PACIFICA RP
PAGES CORNER TK
PAICINES AY
PALERMO IP
PALO CEDRO AO
PANOCHE VALLEY AY
PARADISE FM
PARADISE PINES FM
PARKFIELD KP
PARLIER PE
PASKENTA XP
PASO ROBLES BK
PATTERSON X8
PAYNES CREEK PC
PEACH TREE BJ
PEARDALE HM
PEBBLE BEACH PB
PENN VALLEY IJ
PENNGROVE 9P
PENNINGTON FQ
PENRYN GL
PEPPERWOOD LF
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 114

PESCADERO VO
PETALUMA NN
PETALUMA NN
PETALUMA NN
PETERS XT
PETROLIA JV
PETROLIA JV
PHILLIPSVILLE G9
PHILO UK
PIEDMONT PD
PIEDRA SR
PIERCY G7
PIKE CITY IZ
PILOT HILL GN
PINE FLAT SR
PINE GROVE QJ
PINE MOUNTAIN
LAKE
XR
PINE RIDGE AU
PINECREST YU
PINEDALE PI
PINEHURST PU
PINNACLES AY
PINOLE PN
PIONEER QK
PIONEER POINT TD
PISMO BEACH PW
PITTSBURG JH
PITTVILLE FF
PLACERVILLE HT
PLANADA PM
PLATINA 8A
PLEASANT GROVE PO
PLEASANT GROVE PO
PLEASANT HILL PH
PLEASANT VALLEY HT
PLEASANTON PL
PLEASANTON PL
PLYMOUTH QS
POINT ARENA NP
POINT REYES PQ
POINT REYES
STATION
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 115
PQ
POLLOCK PINES HW
POND TX
PONDEROSA SKY
RANCH
PC
PONDOSA 1W
POPE VALLEY N5
PORT COSTA DF
PORTOLA VALLEY PV
POTTER VALLEY UM
PRAIRIE CREEK LF
PRATHER PR
PRATTVILLE Q1
PRESIDIO PT
PRESTON NC
PRINCETON EQ
PRINCETON VG
PROBERTA RW
PROJECT CITY WO
PRUNEDALE BT
PULGA F6
PUMPKIN CENTER TC
QUAIL FLAT TJ
QUINCY FP
RACKERBY IK
RAILROAD FLAT QX
RAINBOW TAVERN H8
RAISIN CITY RR
RANCHO CORDOVA RA
RANCHO MURIETA RF
RANCHO TEHAMA WF
RAYMOND RY
RAYMOND RY
RAYMOND RY
RED BANK FN
RED BANK WJ
RED BLUFF FN
RED MOUNTAIN TD
RED TOP C8
REDCREST JW

REDDING FY
REDWAY G2
REDWOOD CITY RC
REDWOOD CREEK LW
REDWOOD ESTATES RE
REDWOOD ESTATES RE
REDWOOD VALLEY UN
REDWOOD VALY L3
REEDLEY RV
REEDLEY RV
RESCUE HY
RHEEM RM
RICHARDSON
GROVE
RICHARDSON
SPRINGS
LM
FB
RICHFIELD WF
RICHMOND JT
RICHVALE IR
RIDGECREST TD
RIEGO HP
RIO BRAVO TC
RIO DELL NR
RIO DELL NR
RIO DELL JX
RIO DELL JX
RIO LINDA RL
RIO NIDO 9N
RIO OSO RO
RIO VISTA PP
RIPON X4
RIVER PINES QG
RIVERBANK RI
RIVERBANK RI
RIVERDALE RZ
RIVERDALE RZ
RIVERTON HT
ROBBINS ZQ
ROCKLIN RT
ROCKPORT QR
RODEO RQ
ROHNERT PARK RK
ROHNERT PARK
(SOUTH)
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 116
RK
ROHNERVILLE LF
ROLINDA TK
ROSEDALE TC
ROSEVILLE HS
ROSEVILLE HS
ROSS RS
ROUGH & READY IW
ROUND MOUNTAIN UB
RUMSEY 7P
RUTH JY
RUTHERFORD N6
RYDE PP
RYER ISLAND PP
SACRAMENTO PS
SALIDA ID
SALINAS BT
SALMON CREEK BB
SALYER L4
SAMOA AM
SAN ANDREAS ZT
SAN ANSELMO SW
SAN ARDO AQ
SAN BENANCIO
CANYON
BT
SAN BENITO BG
SAN BRUNO RD
SAN CARLOS SC
SAN FRANCISCO RG
SAN GERONIMO GM
SAN GREGORIO VQ
SAN JOAQUIN SJ
SAN JOSE VP
SAN JOSE VP
SAN JOSE VP
SAN JUAN BAUTISTA B1
SAN JUAN BAUTISTA B1
SAN LEANDRO SO
SAN LORENZO SZ

SAN LUCAS AX
SAN LUIS OBISPO BV
SAN MARTIN UA
SAN MATEO SM
SAN MIGUEL KP
SAN PABLO SB
SAN QUENTIN QU
SAN RAFAEL NQ
SAN RAMON SN
SAN SIMEON SP
SAND CITY EW
SANGER SR
SANGER SR
SANGER SR
SANTA BARBARA 5B
SANTA CLARA SA
SANTA CLARA SA
SANTA CRUZ VT
SANTA MARGARITA WZ
SANTA MARGARITA WZ
SANTA MARIA BX
SANTA NELLA GU
SANTA RITA PARK TM
SANTA ROSA NR
SANTA VENTIA NQ
SANTA YNEZ 3B
SARATOGA SG
SARATOGA SG
SARATOGA SG
SAUSALITO NS
SAWMILL FLAT XR
SCHELLVILLE NV
SCIOTS CAMP HT
SCOTIA JU
SCOTTS VALLEY SY
SEACLIFF AP
SEA RANCH P5
SEASIDE SS
SEAVIEW NG
SEBASTOPOL SE
SEBASTOPOL SE
SELBY JT
SELMA TT
SEQUOIA TJ
SEVILLE VE
SHAFTER TE
SHANDON WY
SHASTA W2
SHASTA LAKE VE
SHASTA LAKE CITY VE
SHAVER LAKE SK
SHAWS FLAT XR
SHEEP RANCH XS
SHELL BEACH PW
SHERIDAN SH
SHERMAN ISLAND PP
SHINGLE SPRINGS HZ
SHINGLETOWN WQ
SHIVELY LF
SIEGLER SPRINGS ZH
SIERRA CITY IG
SIERRA CITY HM
SIERRA VILLAGE UW
SILVER FORK HT
SISQUOC B3
SITES PX
SKAGGS SPRINGS NC
SKY LONDA LH
SLOUGHHOUSE QQ
SLY PARK HT
SMARTVILLE SV
SMARTVILLE SV
SMITH CAMP FF
SNELLING SX
SO BEIRIDGE TV
SODA SPRINGS H8
SOLEDAD SL
SOLEDAD SL
SOLVANG 1B
SOMERSET IC
SOMES BAR L6
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 117

SONOMA NV
SONOMA NV
SONORA XR
SOQUEL SQ
SOULSBYVILLE YR
SOUTH FORK TQ
SOUTH SAN
FRANCISCO
RJ
SPANISH FLAT N7
SPANISH RANCH EX
SPRECKELS SF
SPRINGVILLE VU
SPRUCE POINT LF
SQUAW VALLEY VY
SAINT HELENA NW
STANDARD YR
STANFORD
UNIVERSITY
ST
STENT XR
STEVINSON SI
STEWARTS POINT P6
STINSON BEACH BH
STIRLING CITY F2
STOCKTON XT
STOCKTON XT
STOCKTON XT
STONE CORRAL WJ
STONE LAGOON LF
STONYFORD 9S
STORRIE F7
STOUT XR
STRATFORD RX
STRAWBERRY HT
STRAWBERRY X1
STRAWBERRY POINT NQ
STRAWBERRY
VALLEY
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 118
IS
SUGAR PINE TQ
SUGAR PINE UW
SUISUN FS
SUISUN FS
SULTANA UL
SUMMERHOME PARK NR
SUMMIT CITY FY
SUNNYBRAE LF
SUNNYVALE VB
SUNOL SU
SUTTER SD
SUTTER SD
SUTTER CREEK QI
SUTTER HILL XD
SUTTER ISLAND PP
SWAINS FLAT LF
SYCAMORE PX
TAFT TV
TAFT TV
TAFT (SOUTH) TV
TAFT HEIGHTS TV
TALMAGE UO
TAMARACK XA
TAMARACK PINES HT
TAYLORSVILLE EZ
TEHACHAPI 2T
TEHAMA YT
TEMPLETON BR
TEPUSQUET BX
TERMINOUS XF
TERRA LINDA NQ
THERMALITO FQ
THORNTON TW
THREE ROCKS KK
TIBURON OT
TIERRA BUENA HP
TIVY VALLEY SR
TOADTOWN FM
TOBIN F8
TOCOLOMA LU
TODD VALLEY GE
TOLLHOUSE T1
TOMALES N1
TRACY XV
TRANQUILLITY TI

TRAVER TZ
TRAVIS AFB EE
TRES PINOS 6B
TRIMMER TK
TRINIDAD TB
TRONA TO
TRONA (SOUTH) TO
TUDOR HP
TULARE TY
TUOLUMNE YX
TUPMAN TA
TURLOCK XX
TUTTLETOWN XR
TWAIN Y6
TWAIN HARTE YV
TWIN BRIDGES IE
TWITCHELL ISLAND PP
TWO ROCK NN
TYLER HH
TYLER ISLAND PP
UKIAH NX
UNION CITY UC
UPPER LAKE ZU
VACATION BEACH NG
VACAVILLE PK
VALLECITO XZ
VALLEJO NY
VALLEJO NY
VALLEY ACRES VA
VALLEY FORD BB
VALLEY HOME XN
VALLEY SPRINGS VS
VALLEY SPRINGS VS
VAN ARSDALE VM
VANDENBURG AFB 2B
VERNALIS X3
VERONA HP
VICHY SPRINGS NX
VICTOR VC
VICTORVILLE C5
VILLA GRANDE N9
VINA IA
VINEBURG 8N
VIRGILIA FP
VISALIA VI
VOLCANO QN
VOLTA TM
WALLACE WL
WALNUT CREEK WC
WALNUT GROVE WV
WALNUT GROVE WV
WASCO TX
WASHINGTON II
WATERFORD WT
WATERLOO XT
WATSONVILLE VX
WATSONVILLE VX
WAUKENA WG
WAWONA C6
WEIMAR HF
WEIMAR H9
WEITCHPEC L7
WEOTT JZ
WEST POINT QY
WEST SACRAMENTO WS
WESTEND TD
WESTHAVEN LF
WESTLEY X9
WESTPORT QW
WESTWOOD Q7
WHEATLAND WE
WHEELER RIDGE TV
WHISKEYTOWN WB
WHISPERING PINE ZH
WHITE HALL NN
WHITE PINES XW
WHITETHORN G3
WHITMORE W3
WHITTAKER FOREST TJ
WILDWOOD 8W
WILLIAMS DV
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 119

WILLITS NZ
WILLOW CREEK LW
WILLOW SPRINGS XD
WILLOW SPRINGS YR
WILLOWS 9W
WILLOWS 9W
WILSEYVILLE QZ
WILSONIA TJ
WINDSOR WI
WINDSOR WI
WINTERS 7W
WINTERS 7W
WINTON WN
WISHON WU
WITTER SPRINGS ZW
WONDER VALLEY SR
WOODACRE WA
WOODBRIDGE WR
WOODEN VALLEY NL
WOODLAKE WJ
WOODLAND PZ
WOODLEAF FQ
WOODSIDE WD
WYANDOTTE FQ
YANKEE HILL FM
YETTEM YE
YOLO YO
YORKVILLE UP
YOSEMITE YX
YOSEMITE (WEST) T2
YOUNTVILLE YN
YUBA CITY YC
YUBA GAP HB
YUBA GAP H5
ZACA LAKE 3B
ZAMORA PZ
ZENIA G8
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 120

A PPENDIX B
SERVICE CITY ZIP CODES
City Zip Code
ACAMPO 95220
AHWAHNEE 93601
AHWAHNEE 93601
ALAMEDA 94501
ALAMEDA 94502
ALAMO 94507
ALBANY 94706
ALBANY 94707
ALBANY 94710
ALBION 95410
ALDERPOINT 95511
ALLEGHANY 95910
ALLENSWORTH 93201
ALLENSWORTH 93219
ALLENSWORTH 93219
ALMANOR 95947
ALPAUGH 93201
ALTA 95701
ALTAVILLE 95221
ALTON 95540
ALVISO 95002
AMADOR CITY 95601
AMBOY 92304
AMERICAN CANYON 94503
AMERICAN CANYON 94503
AMERICAN CANYON 94588
AMERICAN CANYON 94590
ANDERSON 96007
ANDERSON 96007
ANGELS CAMP 95221
ANGELS CAMP 95222
ANGWIN 94508
ANNAPOLIS 95412
ANTELOPE 95843
ANTIOCH 90212
ANTIOCH 90406
ANTIOCH 92626
ANTIOCH 92806
ANTIOCH 94507
ANTIOCH 94509
ANTIOCH 94509
ANTIOCH 94523
ANTIOCH 94531
ANTIOCH 94566
ANTIOCH 97478
APPLEGATE 95703
APTOS 95001
APTOS 95003
ARBUCKLE 95912
ARBUCKLE 95932
ARCATA 95518
ARCATA 95519
ARCATA 95521
ARNOLD 95223
ARNOLD 95223
AROMAS 95004
AROMAS 95004
ARROYO GRANDE 93401
ARROYO GRANDE 93420
ARROYO GRANDE 93421
ARROYO GRANDE 93444
ARROYO GRANDE 93445
ARTOIS 95913
ARTOIS 95913
ARVIN 93203
ATASCADERO 93422
ATASCADERO 93423
ATASCADERO 93442
ATASCADERO 93446
ATHERTON 94027
ATWATER 95301
AUBERRY 93602
AUBURN 95602
AUBURN 95602
AUBURN 95603
AUBURN 95603
AUBURN 95603
AUBURN 95604
AVENAL 93204
AVENAL 93204
AVERY 95224
AVILA BEACH 93424
AVILA BEACH 93449
BADGER 93603
BADGER 93603
BAKERSFIELD 90404

BAKERSFIELD 90503
BAKERSFIELD 91210
BAKERSFIELD 92658
BAKERSFIELD 92887
BAKERSFIELD 93203
BAKERSFIELD 93206
BAKERSFIELD 93220
BAKERSFIELD 93280
BAKERSFIELD 93301
BAKERSFIELD 93302
BAKERSFIELD 93303
BAKERSFIELD 93303
BAKERSFIELD 93304
BAKERSFIELD 93305
BAKERSFIELD 93306
BAKERSFIELD 93307
BAKERSFIELD 93308
BAKERSFIELD 93309
BAKERSFIELD 93309
BAKERSFIELD 93311
BAKERSFIELD 93312
BAKERSFIELD 93313
BAKERSFIELD 93314
BAKERSFIELD 93380
BAKERSFIELD 93381
BAKERSFIELD 93383
BAKERSFIELD 93384
BAKERSFIELD 93387
BAKERSFIELD 93388
BAKERSFIELD 93389
BAKERSFIELD 93390
BALLARD 93463
BALLICO 95303
BANGOR 95914
BANGOR 95914
BANTA 95304
BASS LAKE 93604
BASS LAKE 93669
BAXTER 95701
BAXTER 95722
BAY POINT 94565
BAYSIDE 95524
BEALE AFB 95903
BEAR VALLEY 95222
BEAR VALLEY 95222
BEAR VALLEY 95223
BEAR VALLEY 95223
BELDEN 95915
BELLA VISTA 96008
BELMONT 94002
BELMONT 94002
BELVEDERE 94920
BEN LOMOND 95005
BENICIA 94510
BENICIA 94553
BERKELEY 94618
BERKELEY 94701
BERKELEY 94702
BERKELEY 94703
BERKELEY 94704
BERKELEY 94704
BERKELEY 94705
BERKELEY 94706
BERKELEY 94707
BERKELEY 94707
BERKELEY 94708
BERKELEY 94708
BERKELEY 94709
BERKELEY 94710
BERKELEY 94720
BERRY CREEK 95916
BETHEL ISLAND 94511
BETHEL ISLAND 94513
BIEBER 96009
BIEBER 96130
BIG BEND 96011
BIG SUR 93920
BIGGS 95917
BIOLA 93606
BIRDS LANDING 94512
BLOCKSBURG 95514
BLUE LAKE 95524
BLUE LAKE 95525
BODEGA 94922
BODEGA BAY 94923
BOLINAS 94924
BOONVILLE 95415
BORON 93516
BORON 93516
BOULDER CREEK 95006
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 122
BRADLEY 93426
BRADLEY 93426
BRADLEY 93426
BRANSCOMB 95417
BRENTWOOD 94513
BRENTWOOD 94513
BRENTWOOD 94513
BRENTWOOD 94513
BRENTWOOD 94513
BRENTWOOD 94514
BRENTWOOD 94561
BRENTWOOD 94566
BRENTWOOD 94588
BRIDGEVILLE 95526
BRIDGEVILLE 95526
BRISBANE 94005
BROOKDALE 95007
BROOKS 95606
BROWNS VALLEY 95918
BROWNSVILLE 95919
BRUSH CREEK 95916
BUELLTON 93101
BUELLTON 93427
BURLINGAME 94010
BURLINGAME 94011
BURNEY 96013
BURNEY 96130
BURNT RANCH 95527
BURNT RANCH 95546
BURREL 93607
BURSON 95225
BURSON 95225
BUTTE CITY 95920
BUTTE CITY 95920
BUTTE MEADOWS 95942
BUTTONWILLOW 93206
BUTTONWILLOW 93260
BYRON 92626
BYRON 94513
BYRON 94514
BYRON 94514
BYRON 94514
BYRON 94514
CALIFORNIA VALLEY 93453
CALIFORNIA VALLEY 93453

CALISTOGA 94515
CALISTOGA 94515
CALPELLA 95418
CAMBRIA 93428
CAMERON PARK 95682
CAMINO 95709
CAMP CONNELL 95223
CAMP MEEKER 95419
CAMPBELL 95008
CAMPBELL 95008
CAMPBELL 95008
CAMPBELL 95008
CAMPBELL 95009
CAMPBELL 95009
CAMPBELL 95009
CAMPO SECO 95226
CAMPTONVILLE 95922
CAMPTONVILLE 95922
CANTUA CREEK 93608
CANYON 94516
CANYON DAM 95923
CAPAY 95607
CAPAY 95607
CAPITOLA 95010
CARLOTTA 95528
CARMEL 93921
CARMEL 93922
CARMEL 93923
CARMEL 93924
CARMEL VALLEY 93924
CARMICHAEL 95608
CARMICHAEL 95609
CARRISA PLAINS 93276
CARRISA PLAINS 93453
CARRISA PLAINS 93453
CARUTHERS 93609
CASMALIA 93429
CASPAR 95420
CASSEL 96016
CASTRO VALLEY 94541
CASTRO VALLEY 94544
CASTRO VALLEY 94546
CASTRO VALLEY 94546
CASTRO VALLEY 94552
CASTROVILLE 95012
CATHEYS VALLEY 95306
CATHEYS VALLEY 95338
CAYUCOS 93430
CAZADERO 95421
CEDAR RIDGE 95924
CERES 95307
CERES 95351
CHALLENGE 95925
CHALLENGE 95925
CHESTER 96020
CHICO 95926
CHICO 95927
CHICO 95928
CHICO 95929
CHICO 95973
CHICO 95973
CHINESE CAMP 95309
CHOLAME 93431
CHOLAME 93461
CHOWCHILLA 93610
CHOWCHILLA 93610
CHUALAR 93925
CITRUS HEIGHTS 95610
CITRUS HEIGHTS 95621
CLARKSBURG 95612
CLAYTON 94517
CLAYTON 94566
CLEARLAKE 95422
CLEARLAKE OAKS 95423
CLEARLAKE PARK 95424
CLEMENTS 95220
CLEMENTS 95227
CLIPPER MILLS 95930
CLOVERDALE 95425
CLOVERDALE 95425
CLOVIS 93611
CLOVIS 93612
CLOVIS 93613
CLOVIS 93619
CLOVIS 93706
CLOVIS 93720
CLOVIS 93725
CLOVIS 95834
CLYDE 94520
COALINGA 93210
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 123
COALINGA 93210
COALINGA 93210
COARSEGOLD 93614
COBB 95426
COHASSET 95973
COLFAX 95713
COLFAX 95736
COLLEGE CITY 95912
COLMA 94014
COLMA 94015
COLOMA 95613
COLUMBIA 95310
COLUSA 95932
COMPTCHE 95427
CONCORD 94518
CONCORD 94519
CONCORD 94520
CONCORD 94520
CONCORD 94521
CONCORD 94522
CONCORD 94523
CONCORD 94524
COOL 95614
COPPEROPOLIS 95228
CORCORAN 93212
CORCORAN 93212
CORCORAN 93212
CORCORAN 93221
CORCORAN 93230
CORNING 96021
CORNING 96021
CORNING 96022
CORTE MADERA 94925
CORTE MADERA 94948
CORTE MADERA 94976
COSTA MESA 92626
COTATI 94928
COTATI 94931
COTTONWOOD 96022
COTTONWOOD 96022
COULTERVILLE 95311
COULTERVILLE 95311
COURTLAND 95615
COVELO 95428
COYOTE 95013

CRESCENT CITY 95531
CRESCENT MILLS 95934
CRESSEY 95312
CRESTON 93432
CROCKETT 94525
CROWS LANDING 95313
CUMMINGS 95585
CUPERTINO 95014
CUPERTINO 95015
CUPERTNIO 95014
CUTLER 93615
CUTTEN 95534
CUYAMA 93252
CUYAMA 93254
DAGGETT 92327
DALY CITY 94014
DALY CITY 94015
DANVILLE 94005
DANVILLE 94506
DANVILLE 94526
DANVILLE 94526
DANVILLE 94526
DANVILLE 94526
DAVENPORT 95017
DAVIS 91789
DAVIS 95616
DAVIS 95616
DAVIS 95617
DEER PARK 94576
DEL REY 93616
DEL REY 93657
DELEVAN 95988
DELHI 95315
DENAIR 95316
DENAIR 95316
DERBY ACRES 93224
DERBY ACRES 93268
DIABLO 94520
DIABLO 94526
DIABLO 94528
DIAMOND SPRINGS 95619
DIAMOND SPRINGS 95675
DILLON BEACH 94929
DILLON BEACH 94929
DINUBA 93271
DINUBA 93618
DINUBA 93618
DINUBA 93662
DISCOVERY BAY 94514
DIXON 95615
DIXON 95620
DIXON 95620
DIXON 95662
DIXON 95694
DOBBINS 95935
DOBBINS 95962
DORRINGTON 95223
DOS PALOS 93620
DOS PALOS 93620
DOS PALOS 95340
DOS RIOS 95429
DOUGLAS FLAT 95229
DOWNIEVILLE 95936
DRYTOWN 95699
DUBLIN 94566
DUBLIN 94568
DUBLIN 94568
DUBLIN 94568
DUBLIN 94568
DUNCANS MILLS 95430
DUNLAP 93621
DUNNIGAN 95937
DURHAM 95926
DURHAM 95938
DUSTIN ACRES 93268
DUTCH FLAT 95714
EARLIMART 93219
EAST NICOLAUS 95659
EAST PALO ALTO 94303
EAST PALO ALTO 94303
EDISON 93220
EDWARDS 93523
EL CERRITO 94530
EL DORADO 95623
EL DORADO HILLS 95762
EL DORADO HILLS 95762
EL GRANADA 94018
EL MACERO 95618
EL NIDO 95317
EL PORTAL 95318
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 124
EL SOBRANTE 94803
EL SOBRANTE 94806
ELK 95432
ELK CREEK 95939
ELK GROVE 95624
ELK GROVE 95757
ELK GROVE 95758
ELK GROVE 95828
ELK GROVE 95829
ELMIRA 95625
ELVERTA 95626
ELVERTA 95626
ELVERTA 95626
EMERALD HILLS 94062
EMERYVILLE 94601
EMERYVILLE 94608
EMIGRANT GAP 95715
EMIGRANT GAP 95715
EMPIRE 95319
ESCALON 95320
ESPARTO 95607
ESPARTO 95627
EUREKA 90274
EUREKA 95501
EUREKA 95502
EUREKA 95503
EUREKA 95521
EUREKA 98101
FAIR OAKS 95628
FAIRFAX 94930
FAIRFIELD 94533
FAIRFIELD 94534
FAIRFIELD 94534
FAIRFIELD 94535
FAIRFIELD 94585
FAIRFIELD 95687
FALL RIVER MILLS 96028
FALLON 94952
FARMINGTON 95230
FARMINGTON 95230
FEATHER FALLS 95940
FELLOWS 93224
FELTON 95018
FERNBRIDGE 95540
FERNDALE 95536

FIDDLETOWN 95629
FIDDLETOWN 95629
FIELDBROOK 95519
FIELDBROOK 95521
FIELDBROOK 95525
FIELDS LANDING 95537
FINLEY 95435
FIREBAUGH 93622
FIREBAUGH 93622
FIREBAUGH 93622
FISH CAMP 93623
FISH CAMP 93623
FIVE POINTS 93624
FLOURNOY 96029
FOLSOM 95630
FOLSOM 95630
FOLSOM 95763
FORBESTOWN 95941
FORBESTOWN 95941
FOREST GLEN 96041
FOREST KNOLLS 94933
FOREST RANCH 95942
FORESTHILL 95631
FORESTVILLE 95436
FORT BRAGG 95437
FORT BRAGG 95456
FORT SEWARD 95542
FORTUNA 95540
FOSTER CITY 94403
FOSTER CITY 94404
FOWLER 93625
FREEDOM 95019
FREMONT 94536
FREMONT 94537
FREMONT 94538
FREMONT 94538
FREMONT 94539
FREMONT 94555
FREMONT 94583
FRENCH CAMP 95231
FRENCH CAMP 95336
FRENCH GULCH 96033
FRESNO 90707
FRESNO 93612
FRESNO 93650
FRESNO 93657
FRESNO 93668
FRESNO 93701
FRESNO 93702
FRESNO 93703
FRESNO 93704
FRESNO 93705
FRESNO 93706
FRESNO 93710
FRESNO 93710
FRESNO 93711
FRESNO 93720
FRESNO 93721
FRESNO 93722
FRESNO 93722
FRESNO 93725
FRESNO 93726
FRESNO 93726
FRESNO 93727
FRESNO 93727
FRESNO 93728
FRESNO 93729
FRESNO 93740
FRESNO 93760
FRESNO 93776
FRESNO 93778
FRESNO 93778
FRESNO 93792
FRESNO 95816
FRIANT 93626
FRIANT 93626
FRIANT 93626
FULTON 95439
GALT 95632
GALT 95632
GALT 95632
GARBERVILLE 95501
GARBERVILLE 95542
GARBERVILLE 95542
GARBERVILLE 96127
GARDEN VALLEY 95633
GEORGETOWN 95634
GEORGETOWN 95634
GERBER 96035
GEYSERVILLE 92081
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 125
GEYSERVILLE 95441
GILROY 95020
GILROY 95021
GLEN ELLEN 95442
GLENCOE 95232
GLENHAVEN 95443
GLENN 95943
GOLD RIVER 95670
GOLD RUN 95717
GONZALES 93926
GOODYEARS BAR 95944
GRANITE BAY 95746
GRASS VALLEY 95945
GRASS VALLEY 95949
GRASS VALLEY 95959
GRASS VALLEY 95960
GRATON 95444
GRAYSON 95360
GRAYSON 95363
GRAYSON 95387
GREENBRAE 94904
GREENFIELD 93927
GREENVILLE 95947
GREENWOOD 95635
GRIDLEY 95948
GRIMES 95950
GRIZZLY FLATS 95636
GRIZZLY FLATS 95684
GROVELAND 95321
GROVELAND 95321
GROVER BEACH 93433
GROVER BEACH 93483
GUADALUPE 93434
GUADALUPE 93434
GUALALA 95445
GUERNEVILLE 95446
GUERNEVILLE 95471
GUINDA 95637
GUSTINE 95322
GUSTINE 95322
HALCYON 93420
HALF MOON BAY 94019
HAMILTON CITY 95951
HANFORD 93230
HANFORD 93232

HARMONY 93435
HAT CREEK 96040
HATHAWAY PINES 95233
HAWKINS BAR 95527
HAWKINS BAR 95563
HAYWARD 94540
HAYWARD 94541
HAYWARD 94542
HAYWARD 94542
HAYWARD 94543
HAYWARD 94544
HAYWARD 94544
HAYWARD 94544
HAYWARD 94545
HAYWARD 94545
HAYWARD 94545
HAYWARD 94546
HAYWARD 94552
HAYWARD 96064
HEALDSBURG 95448
HELM 93627
HERCULES 94547
HICKMAN 95323
HIDDEN VALLEY
LAKE 95467
HILLSBOROUGH 94010
HILMAR 95324
HOLLISTER 95023
HOLLISTER 95023
HOLLISTER 95024
HOLT 95234
HONEYDEW 95545
HOOPA 95546
HOOPA 95547
HOOPA 95573
HOPLAND 95449
HORNITOS 95325
HUGHSON 95326
HUME 93628
HURON 93210
HURON 93234
HURON 93245
HYDESVILLE 95547
IGO 96047
INVERNESS 94937
INYOKERN 93526
INYOKERN 93527
INYOKERN 93555
IONE 95640
IRVINE 92612
ISLETON 95641
JACKSON 92629
JACKSON 95642
JACKSON 95647
JACKSON 99210
JAMESTOWN 95327
JENNER 95450
JOHNSON PARK 96013
JOLON 93928
KEDDIE 95971
KELSEY 95667
KELSEYVILLE 95451
KENSINGTON 94706
KENSINGTON 94707
KENSINGTON 94707
KENSINGTON 94708
KENTFIELD 94901
KENTFIELD 94904
KENWOOD 95409
KENWOOD 95452
KERMAN 93630
KERMAN 93631
KETTLEMAN CITY 93234
KETTLEMAN CITY 93239
KEYES 95328
KING CITY 93930
KING CITY 93930
KING CITY 93930
KINGS CANYON 93633
KINGS CANYON 93633
KINGSBURG 93631
KINGSBURG 93631
KINGSBURG 93631
KNEELAND 95549
KNIGHTS FERRY 95361
KNIGHTS LANDING 95645
KNIGHTS LANDING 95645
KNIGHTS LANDING 95645
KNIGHTSEN 94548
KORBEL 95550
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 126
KYBURZ 95720
LA GRANGE 95329
LA GRANGE 95329
LA GRANGE 95329
LA HONDA 94020
LA HONDA 94020
LA PORTE 95981
LA SELVA BEACH 95076
LAFAYETTE 94549
LAGUNITAS 94938
LAKE ALMANOR 96020
LAKE ALMANOR 96137
LAKE ALMANOR 96137
LAKE BERRYESSA 94558
LAKEHEAD 96051
LAKEPORT 90267
LAKEPORT 95453
LAMONT 93241
LARKSPUR 94904
LARKSPUR 94939
LARKSPUR 94977
LATHROP 95330
LATON 93242
LATON 93242
LAYTONVILLE 95417
LAYTONVILLE 95454
LAYTONVILLE 95490
LE GRAND 95333
LEBEC 93243
LEBEC 93243
LEGGETT 95585
LEMOORE 93245
LEMOORE 93656
LINCOLN 95648
LINCOLN 95648
LINDEN 95236
LINDEN 95236
LITTLE NORWAY 95721
LITTLE NORWAY 95735
LITTLE RIVER 95456
LITTLE VALLEY 96056
LIVE OAK 95816
LIVE OAK 95953
LIVERMORE 92660
LIVERMORE 94513

LIVERMORE 94550
LIVERMORE 94550
LIVERMORE 94550
LIVERMORE 94551
LIVERMORE 94551
LIVERMORE 94551
LIVERMORE 94551
LIVERMORE 94551
LIVERMORE 94588
LIVINGSTON 95334
LOCH LOMOND 95426
LOCH LOMOND 95461
LOCKEFORD 95237
LOCKWOOD 93932
LODI 95240
LODI 95241
LODI 95242
LOLETA 95551
LOMA MAR 94021
LOMPOC 93436
LOMPOC 93437
LOMPOC 93438
LONG BARN 95335
LOOMIS 95650
LOS ALAMOS 93440
LOS ALAMOS 93441
LOS ALTOS 94022
LOS ALTOS 94022
LOS ALTOS 94024
LOS ALTOS HILLS 94022
LOS ALTOS HILLS 94024
LOS BANOS 93635
LOS BANOS 93635
LOS GATOS 95030
LOS GATOS 95030
LOS GATOS 95030
LOS GATOS 95031
LOS GATOS 95032
LOS GATOS 95032
LOS GATOS 95032
LOS GATOS 95033
LOS GATOS 95033
LOS GATOS 95033
LOS MOLINOS 96055
LOS OLIVOS 93441
LOS OSOS 93401
LOS OSOS 93402
LOS OSOS 93405
LOS OSOS 93412
LOST HILLS 93249
LOTUS 95651
LOWER LAKE 95457
LUCERNE 95458
LUCERNE VALLEY 92356
MAD RIVER 95552
MAD RIVER 95552
MADERA 93637
MADERA 93638
MADERA 93638
MADERA 93639
MADISON 95653
MAGALIA 95954
MANCHESTER 95459
MANTECA 95336
MANTECA 95337
MANTECA 95366
MANTON 96059
MANTON 96059
MARICOPA 93252
MARICOPA 93252
MARINA 93933
MARIPOSA 95338
MARIPOSA 95338
MARKLEEVILLE 96120
MARSHALL 94940
MARTELL 95642
MARTELL 95654
MARTINEZ 94553
MARTINEZ 94553
MARYSVILLE 95661
MARYSVILLE 95901
MARYSVILLE 95901
MARYSVILLE 95903
MARYSVILLE 95991
MARYSVILLE 95992
MAXWELL 95955
MC ARTHUR 96056
MC FARLAND 93205
MC FARLAND 93250
MC FARLAND 93350
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MC KITTRICK 93251
MCARTHUR 96056
MCARTHUR 96056
MCCLELLAN 95652
MCKINLEYVILLE 95519
MCKINLEYVILLE 95521
MEADOW VALLEY 95656
MEADOW VALLEY 95956
MEADOW VALLEY 95971
MEADOW VISTA 95722
MENDOCINO 95460
MENDOTA 93640
MENLO PARK 94025
MENLO PARK 94027
MENLO PARK 94028
MERCED 95329
MERCED 95340
MERCED 95341
MERCED 95344
MERCED 95348
MERIDIAN 95957
MERIDIAN 95957
METTLER STATION 93301
METTLER STATION 93313
MI WUK VILLAGE 95346
MIDDLETOWN 95461
MIDDLETOWN 95461
MIDDLETOWN 95467
MIDPINES 95345
MILL CREEK 96061
MILL VALLEY 94941
MILL VALLEY 94941
MILL VALLEY 94942
MILLBRAE 94030
MILLVILLE 96062
MILPITAS 94583
MILPITAS 94583
MILPITAS 95035
MILPITAS 95035
MILPITAS 95036
MINERAL 96061
MINERAL 96063
MIRAMONTE 93641
MIRANDA 95553
MODESTO 95350

MODESTO 95351
MODESTO 95352
MODESTO 95353
MODESTO 95354
MODESTO 95355
MODESTO 95355
MODESTO 95356
MODESTO 95357
MODESTO 95358
MOJAVE 93502
MOKELUMNE HILL 95245
MONTARA 94037
MONTE RIO 95462
MONTE SERENO 95030
MONTEREY 93924
MONTEREY 93940
MONTEREY 93942
MONTEREY 93944
MONTGOMERY
CREEK 96001
MONTGOMERY
CREEK 96065
MONTGOMERY
CREEK 96084
MORAGA 94556
MORGAN HILL 95037
MORGAN HILL 95038
MORRO BAY 93442
MORRO BAY 93443
MOSS BEACH 94038
MOSS LANDING 93950
MOSS LANDING 95039
MOUNT AUKUM 95656
MOUNT HERMON 95018
MOUNT HERMON 95041
MOUNTAIN HOUSE 95391
MOUNTAIN RANCH 95246
MOUNTAIN RANCH 95246
MOUNTAIN VIEW 94039
MOUNTAIN VIEW 94040
MOUNTAIN VIEW 94040
MOUNTAIN VIEW 94041
MOUNTAIN VIEW 94043
MUIR BEACH 94965
MURPHYS 95247
MYERS FLAT 95554
NAPA 94558
NAPA 94558
NAPA 94559
NAVARRO 95463
NELSON 95958
NEVADA CITY 95949
NEVADA CITY 95959
NEW CUYAMA 93254
NEWARK 94538
NEWARK 94560
NEWARK 94560
NEWBERRY SPRINGS 92365
NEWCASTLE 95658
NEWMAN 95350
NEWMAN 95360
NEWMAN 95360
NICASIO 94946
NICE 95464
NICOLAUS 95659
NIPOMO 93420
NIPOMO 93444
NIPOMO 93444
NIPOMO 93454
NORDEN 95724
NORDEN 95724
NORTH EDWARDS 93523
NORTH FORK 93643
NORTH HIGHLANDS 95652
NORTH HIGHLANDS 95660
NORTH SAN JUAN 95960
NORTH SAN JUAN 95960
NORTH SAN JUAN 95960
NOVATO 94945
NOVATO 94945
NOVATO 94947
NOVATO 94947
NOVATO 94948
NOVATO 94949
NOVATO 94954
NOVATO 94998
NUBIEBER 96068
O NEALS 93645
OAK RUN 96069
OAKDALE 95361
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 128
OAKDALE 95361
OAKDALE 95361
OAKHURST 93644
OAKHURST 95389
OAKLAND 94601
OAKLAND 94602
OAKLAND 94603
OAKLAND 94604
OAKLAND 94605
OAKLAND 94606
OAKLAND 94607
OAKLAND 94607
OAKLAND 94608
OAKLAND 94609
OAKLAND 94610
OAKLAND 94611
OAKLAND 94612
OAKLAND 94612
OAKLAND 94613
OAKLAND 94614
OAKLAND 94615
OAKLAND 94618
OAKLAND 94619
OAKLAND 94621
OAKLAND 94623
OAKLAND 94623
OAKLAND 94623
OAKLAND 94704
OAKLAND 94705
OAKLAND 95816
OAKLEY 94513
OAKLEY 94561
OAKVILLE 94562
OCCIDENTAL 95465
OCEANO 93445
OLD STATION 96071
OLEMA 94950
OLIVEHURST 95901
OLIVEHURST 95918
OLIVEHURST 95961
ORANGE COVE 93646
ORANGE COVE 93646
ORANGE COVE 93675
ORANGEVALE 95662
ORANGEVALE 95662

ORCUTT 93440
ORCUTT 93454
ORCUTT 93455
OREGON HOUSE 95962
ORICK 95555
ORINDA 94523
ORINDA 94563
ORLAND 95963
ORLAND 95963
ORLAND 95963
ORLAND 96130
ORLEANS 95556
OROSI 93647
OROVILLE 95965
OROVILLE 95966
OROVILLE 95966
PACHECO 94553
PACIFIC GROVE 93950
PACIFIC HOUSE 95726
PACIFICA 94044
PAICINES 95043
PALERMO 95968
PALO ALTO 94034
PALO ALTO 94066
PALO ALTO 94301
PALO ALTO 94303
PALO ALTO 94303
PALO ALTO 94304
PALO ALTO 94304
PALO ALTO 94305
PALO ALTO 94306
PALO CEDRO 96073
PARADISE 95967
PARADISE 95969
PARLIER 93648
PARLIER 93727
PASKENTA 96074
PASO ROBLES 93446
PASO ROBLES 93447
PASO ROBLES 93465
PATTERSON 95363
PAYNES CREEK 96075
PEBBLE BEACH 93953
PENN VALLEY 95946
PENN VALLEY 95946
PENNGROVE 94951
PENRYN 95663
PESCADERO 94060
PETALUMA 93003
PETALUMA 94952
PETALUMA 94952
PETALUMA 94953
PETALUMA 94954
PETROLIA 95558
PHILLIPSVILLE 95559
PHILO 95466
PIEDMONT 94602
PIEDMONT 94610
PIEDMONT 94611
PIEDMONT 94618
PIERCY 95587
PIERCY 95587
PIKE CITY 95960
PILOT HILL 95664
PILOT HILL 95664
PINE GROVE 95665
PINE GROVE 95666
PINECREST 95314
PINECREST 95364
PINEDALE 93650
PINEHURST 93641
PINOLE 94564
PINOLE 94803
PIONEER 95666
PISMO BEACH 93448
PISMO BEACH 93449
PITTSBURG 94553
PITTSBURG 94565
PLACERVILLE 95667
PLANADA 95365
PLATINA 96076
PLATINA 96076
PLEASANT GROVE 95668
PLEASANT GROVE 95668
PLEASANT HILL 94523
PLEASANTON 94538
PLEASANTON 94566
PLEASANTON 94566
PLEASANTON 94566
PLEASANTON 94566
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 129
PLEASANTON 94566
PLEASANTON 94566
PLEASANTON 94568
PLEASANTON 94588
PLEASANTON 94588
PLEASANTON 94588
PLEASANTON 94588
PLEASANTON 94588
PLUMAS LAKE 95961
PLYMOUTH 95669
POINT ARENA 95468
POINT REYES 94956
POINT REYES
STATION 94956
POLLOCK PINES 95726
POPE VALLEY 94567
PORT COSTA 94569
PORTOLA VALLEY 94028
POTTER VALLEY 95469
PRATHER 93651
PRESIDIO 94129
PRINCETON 95970
PRINCETON 95970
PRINCETON 95970
PROBERTA 96078
PULGA 95965
QUINCY 95971
RACKERBY 95972
RAIL ROAD FLAT 95232
RAIL ROAD FLAT 95245
RAIL ROAD FLAT 95248
RAIL ROAD FLAT 95248
RAISIN 93652
RAISIN CITY 93652
RANCHO CORDOVA 95655
RANCHO CORDOVA 95670
RANCHO CORDOVA 95742
RAYMOND 93653
RAYMOND 93653
RED BLUFF 96080
RED BLUFF 96080
RED TOP 95340
REDCREST 95569
REDDING 96001
REDDING 96002

REDDING 96003
REDDING 96049
REDDING 96099
REDDING 97405
REDWAY 95560
REDWOOD CITY 94061
REDWOOD CITY 94062
REDWOOD CITY 94063
REDWOOD CITY 94063
REDWOOD CITY 94064
REDWOOD CITY 94065
REDWOOD ESTATES 95044
REDWOOD ESTATES 95044
REDWOOD VALLEY 95470
REEDLEY 93654
REEDLEY 93654
REEDLEY 93654
REEDLEY 99999
RESCUE 95672
RESCUE 95682
RICHMOND 90221
RICHMOND 94530
RICHMOND 94801
RICHMOND 94802
RICHMOND 94803
RICHMOND 94804
RICHMOND 94805
RICHMOND 94806
RICHMOND 94806
RICHMOND 94807
RICHMOND 94808
RICHMOND 94850
RICHVALE 95974
RIDGECREST 93555
RIDGECREST 93555
RIO DELL 95562
RIO LINDA 95661
RIO LINDA 95673
RIO NIDO 95471
RIO OSO 95674
RIO VISTA 94520
RIO VISTA 94571
RIO VISTA 94571
RIPON 95366
RIPON 95366
RIVER PINES 95675
RIVERBANK 95361
RIVERBANK 95363
RIVERBANK 95367
RIVERBANK 95367
RIVERDALE 93656
RIVERDALE 93656
ROBBINS 95676
ROBBINS 95676
Rocklin 95677
ROCKLIN 95677
ROCKLIN 95765
ROCKLIN 95775
RODEO 94572
RODEO 94577
ROHNERT PARK 94927
ROHNERT PARK 94928
ROHNERT PARK 94931
ROSEVILLE 95661
ROSEVILLE 95678
ROSEVILLE 95678
ROSEVILLE 95678
ROSEVILLE 95746
ROSEVILLE 95747
ROSEVILLE 95841
ROSS 94957
ROUGH AND READY 95975
ROUND MOUNTAIN 96084
RUMSEY 95679
RUTH 95526
RUTH 95526
RUTH 95551
RUTHERFORD 94573
RYDE 95680
SACRAMENTO 94298
SACRAMENTO 95628
SACRAMENTO 95758
SACRAMENTO 95812
SACRAMENTO 95814
SACRAMENTO 95814
SACRAMENTO 95815
SACRAMENTO 95816
SACRAMENTO 95816
SACRAMENTO 95816
SACRAMENTO 95816
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 130
SACRAMENTO 95816
SACRAMENTO 95816
SACRAMENTO 95816
SACRAMENTO 95817
SACRAMENTO 95818
SACRAMENTO 95818
SACRAMENTO 95819
SACRAMENTO 95820
SACRAMENTO 95821
SACRAMENTO 95822
SACRAMENTO 95823
SACRAMENTO 95824
SACRAMENTO 95825
SACRAMENTO 95825
SACRAMENTO 95826
SACRAMENTO 95827
SACRAMENTO 95828
SACRAMENTO 95829
SACRAMENTO 95830
SACRAMENTO 95831
SACRAMENTO 95832
SACRAMENTO 95833
SACRAMENTO 95834
SACRAMENTO 95834
SACRAMENTO 95834
SACRAMENTO 95834
SACRAMENTO 95834
SACRAMENTO 95835
SACRAMENTO 95836
SACRAMENTO 95837
SACRAMENTO 95837
SACRAMENTO 95838
SACRAMENTO 95841
SACRAMENTO 95842
SACRAMENTO 95843
SACRAMENTO 95864
SAINT HELENA 94574
SAINT HELENA 94574
SALIDA 95368
SALINAS 93901
SALINAS 93902
SALINAS 93905
SALINAS 93905
SALINAS 93906
SALINAS 93907

SALINAS 93908
SALINAS 93912
SALINAS 93915
SALYER 95563
SAMOA 95564
SAN ANDREAS 95249
SAN ANSELMO 94960
SAN ARDO 93450
SAN BRUNO 94066
SAN CARLOS 94070
SAN CARLOS 94070
SAN CARLOS 94303
SAN FRANCISCO 94080
SAN FRANCISCO 94101
SAN FRANCISCO 94102
SAN FRANCISCO 94103
SAN FRANCISCO 94104
SAN FRANCISCO 94105
SAN FRANCISCO 94105
SAN FRANCISCO 94105
SAN FRANCISCO 94106
SAN FRANCISCO 94106
SAN FRANCISCO 94107
SAN FRANCISCO 94108
SAN FRANCISCO 94108
SAN FRANCISCO 94109
SAN FRANCISCO 94110
SAN FRANCISCO 94111
SAN FRANCISCO 94111
SAN FRANCISCO 94112
SAN FRANCISCO 94114
SAN FRANCISCO 94115
SAN FRANCISCO 94116
SAN FRANCISCO 94117
SAN FRANCISCO 94118
SAN FRANCISCO 94119
SAN FRANCISCO 94121
SAN FRANCISCO 94122
SAN FRANCISCO 94123
SAN FRANCISCO 94123
SAN FRANCISCO 94124
SAN FRANCISCO 94127
SAN FRANCISCO 94128
SAN FRANCISCO 94129
SAN FRANCISCO 94131
SAN FRANCISCO 94132
SAN FRANCISCO 94133
SAN FRANCISCO 94133
SAN FRANCISCO 94134
SAN FRANCISCO 94143
SAN FRANCISCO 94158
SAN GERONIMO 94963
SAN GREGORIO 94074
SAN JOAQUIN 93660
SAN JOSE 94538
SAN JOSE 95002
SAN JOSE 95008
SAN JOSE 95013
SAN JOSE 95035
SAN JOSE 95037
SAN JOSE 95101
SAN JOSE 95102
SAN JOSE 95110
SAN JOSE 95110
SAN JOSE 95110
SAN JOSE 95111
SAN JOSE 95112
SAN JOSE 95113
SAN JOSE 95113
SAN JOSE 95116
SAN JOSE 95117
SAN JOSE 95118
SAN JOSE 95119
SAN JOSE 95119
SAN JOSE 95119
SAN JOSE 95120
SAN JOSE 95121
SAN JOSE 95122
SAN JOSE 95123
SAN JOSE 95124
SAN JOSE 95124
SAN JOSE 95125
SAN JOSE 95125
SAN JOSE 95125
SAN JOSE 95126
SAN JOSE 95126
SAN JOSE 95126
SAN JOSE 95126
SAN JOSE 95127
SAN JOSE 95128
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 131
SAN JOSE 95129
SAN JOSE 95129
SAN JOSE 95130
SAN JOSE 95131
SAN JOSE 95132
SAN JOSE 95133
SAN JOSE 95133
SAN JOSE 95134
SAN JOSE 95135
SAN JOSE 95136
SAN JOSE 95138
SAN JOSE 95139
SAN JOSE 95140
SAN JOSE 95141
SAN JOSE 95148
SAN JOSE 95150
SAN JOSE 95151
SAN JOSE 95153
SAN JOSE 95153
SAN JOSE 95154
SAN JOSE 95160
SAN JOSE 95160
SAN JOSE 95161
SAN JOSE 95192
SAN JUAN BAUTISTA 95045
SAN LEANDRO 94577
SAN LEANDRO 94577
SAN LEANDRO 94578
SAN LEANDRO 94579
SAN LEANDRO 94580
SAN LORENZO 94580
SAN LUCAS 93930
SAN LUCAS 93954
SAN LUIS OBISPO 90071
SAN LUIS OBISPO 90603
SAN LUIS OBISPO 93401
SAN LUIS OBISPO 93402
SAN LUIS OBISPO 93403
SAN LUIS OBISPO 93405
SAN LUIS OBISPO 93406
SAN LUIS OBISPO 93408
SAN LUIS OBISPO 93420
SAN LUIS OBISPO 93433
SAN LUIS OBISPO 93449
SAN MARTIN 95046

SAN MATEO 94025
SAN MATEO 94062
SAN MATEO 94401
SAN MATEO 94401
SAN MATEO 94402
SAN MATEO 94403
SAN MATEO 94404
SAN MATEO 94404
SAN MATEO 94404
SAN MIGUEL 93446
SAN MIGUEL 93451
SAN MIGUEL 93451
SAN MIGUEL 93451
SAN MIGUEL 93451
SAN PABLO 94806
SAN QUENTIN 94964
SAN RAFAEL 92264
SAN RAFAEL 94901
SAN RAFAEL 94901
SAN RAFAEL 94903
SAN RAFAEL 94904
SAN RAFAEL 94912
SAN RAFAEL 94913
SAN RAFAEL 94915
SAN RAFAEL 94915
SAN RAFAEL 94956
SAN RAFAEL 95816
SAN RAMON 94506
SAN RAMON 94582
SAN RAMON 94583
SAN RAMON 94583
SAN RAMON 94583
SAN RAMON 94583
SAN RAMON 94583
SAN SIMEON 93452
SAND CITY 93955
SANGER 93657
SANGER 93711
SANTA BARBARA 93101
SANTA BARBARA 93103
SANTA BARBARA 93105
SANTA BARBARA 93110
SANTA CLARA 95050
SANTA CLARA 95050
SANTA CLARA 95050
SANTA CLARA 95051
SANTA CLARA 95053
SANTA CLARA 95054
SANTA CRUZ 95060
SANTA CRUZ 95062
SANTA CRUZ 95062
SANTA CRUZ 95062
SANTA CRUZ 95062
SANTA CRUZ 95064
SANTA CRUZ 95065
SANTA CRUZ 95066
SANTA MARGARITA 93422
SANTA MARGARITA 93453
SANTA MARIA 92674
SANTA MARIA 92693
SANTA MARIA 93454
SANTA MARIA 93454
SANTA MARIA 93455
SANTA MARIA 93456
SANTA MARIA 93457
SANTA MARIA 93458
SANTA NELLA 95322
SANTA ROSA 95401
SANTA ROSA 95402
SANTA ROSA 95403
SANTA ROSA 95404
SANTA ROSA 95405
SANTA ROSA 95406
SANTA ROSA 95407
SANTA ROSA 95407
SANTA ROSA 95409
SANTA ROSA 95492
SANTA YNEZ 93460
SARATOGA 95070
SARATOGA 95070
SARATOGA 95071
SAUSALITO 94965
SAUSALITO 94966
SCOTIA 95565
SCOTTS VALLEY 95060
SCOTTS VALLEY 95065
SCOTTS VALLEY 95066
SEA RANCH 95445
SEA RANCH 95497
SEA RANCH 95497
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 132
SEASIDE 93955
SEBASTOPOL 95401
SEBASTOPOL 95472
SEBASTOPOL 95473
SELMA 90720
SELMA 93622
SELMA 93622
SELMA 93657
SELMA 93662
SELMA 93706
SELMA 93721
SEVILLE 93292
SHAFTER 93263
SHANDON 93451
SHANDON 93461
SHASTA 96087
SHASTA LAKE 96003
SHASTA LAKE 96019
SHASTA LAKE 96089
SHAVER LAKE 93602
SHAVER LAKE 93664
SHEEP RANCH 95250
SHELL BEACH 93449
SHERIDAN 95681
SHINGLE SPRINGS 95682
SHINGLE SPRINGS 95682
SHINGLETOWN 96088
SIERRA CITY 96125
SISQUOC 93454
SISQUOC 93455
SITES 95979
SMARTVILLE 95977
SMARTVILLE 95977
SNELLING 95369
SNELLING 95369
SODA SPRINGS 95724
SODA SPRINGS 95724
SODA SPRINGS 95728
SODA SPRINGS 95728
SOLEDAD 93960
SOLVANG 93463
SOLVANG 93464
SOMERSET 95684
SOMES BAR 95568
SONOMA 95476

SONOMA 95476
SONORA 92651
SONORA 95370
SONORA 95379
SOQUEL 95073
SOULSBYVILLE 95372
SOUTH DOS PALOS 93665
SOUTH SAN
FRANCISCO 94080
SOUTH SAN
FRANCISCO 94083
SOUTH SAN
FRANCISCO 94112
SPRECKELS 93962
SQUAW VALLEY 93646
SQUAW VALLEY 93675
STANDARD 95373
STANFORD 94305
STEVINSON 95374
STEWARTS POINT 95480
STINSON BEACH 94970
STIRLING CITY 95978
STOCKTON 90212
STOCKTON 90404
STOCKTON 94545
STOCKTON 95201
STOCKTON 95202
STOCKTON 95202
STOCKTON 95203
STOCKTON 95204
STOCKTON 95204
STOCKTON 95204
STOCKTON 95205
STOCKTON 95206
STOCKTON 95206
STOCKTON 95207
STOCKTON 95207
STOCKTON 95208
STOCKTON 95209
STOCKTON 95209
STOCKTON 95210
STOCKTON 95211
STOCKTON 95212
STOCKTON 95213
STOCKTON 95213
STOCKTON 95215
STOCKTON 95219
STOCKTON 95219
STOCKTON 95234
STOCKTON 95236
STOCKTON 95240
STOCKTON 95267
STOCKTON 95336
STONYFORD 95979
STONYFORD 95979
STORRIE 95980
STRATFORD 93266
STRAWBERRY 95375
STRAWBERRY
VALLEY 95981
SUISUN 94533
SUISUN 94534
SUISUN 94585
SUISUN 95685
SUISUN CITY 94534
SUISUN CITY 94585
SUISUN CITY 94585
SUISUN CITY 94585
SULTANA 93666
SUNNYVALE 94085
SUNNYVALE 94086
SUNNYVALE 94087
SUNNYVALE 94088
SUNNYVALE 94089
SUNNYVALE 95014
SUNOL 94586
SUTTER 95982
SUTTER CREEK 95685
TAFT 92647
TAFT 93268
TAFT 93453
TAYLORSVILLE 95934
TAYLORSVILLE 95983
TEHACHAPI 93561
TEHAMA 96090
TEMPLETON 93465
THORNTON 95686
TIBURON 94920
TOLLHOUSE 93667
TOMALES 94971
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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TRACY 92110
TRACY 92691
TRACY 92707
TRACY 94520
TRACY 94550
TRACY 94577
TRACY 94588
TRACY 95201
TRACY 95206
TRACY 95304
TRACY 95304
TRACY 95304
TRACY 95376
TRACY 95376
TRACY 95376
TRACY 95377
TRACY 95377
TRACY 95378
TRACY 95378
TRACY 95385
TRACY 95385
TRACY 95391
TRACY 95391
TRANQUILLITY 93668
TRAVER 93673
TRAVIS AFB 94535
TRES PINOS 95075
TRINIDAD 95570
TRONA 93562
TULARE 93274
TUOLUMNE 95379
TUPMAN 93276
TURLOCK 95380
TURLOCK 95380
TURLOCK 95382
TWAIN 95984
TWAIN HARTE 95383
TWIN BRIDGES 95735
UKIAH 95482
UKIAH 95482
UNION CITY 94587
UNION CITY 94587
UPPER LAKE 95485
UPPER LAKE 95493
VACAVILLE 95687

VACAVILLE 95688
VACAVILLE 95696
VALLECITO 95229
VALLECITO 95251
VALLEJO 94503
VALLEJO 94503
VALLEJO 94583
VALLEJO 94589
VALLEJO 94590
Vallejo 94590
VALLEJO 94590
VALLEJO 94591
Vallejo 94591
VALLEJO 94592
VALLEY ACRES 93268
VALLEY FORD 94972
VALLEY FORD 94972
VALLEY HOME 95361
VALLEY SPRINGS 95252
VALLEY SPRINGS 95255
VERNALIS 95385
VERNALIS 95385
VICTOR 95253
VICTORVILLE 92394
VILLA GRANDE 95486
VINA 96092
VISALIA 93277
VISALIA 93279
VISALIA 93291
VISALIA 93292
VOLCANO 95689
WALLACE 95254
WALNUT CREEK 94595
WALNUT CREEK 94595
WALNUT CREEK 94596
WALNUT CREEK 94596
WALNUT CREEK 94597
WALNUT CREEK 94597
WALNUT CREEK 94597
WALNUT CREEK 94598
WALNUT CREEK 94598
WALNUT GROVE 95690
WALNUT GROVE 95690
WALNUT GROVE 95690
WALNUT GROVE 95690
WASCO 93280
WASHINGTON 95986
WATERFORD 95386
WATSONVILLE 95019
WATSONVILLE 95076
WATSONVILLE 95076
WATSONVILLE 95076
WATSONVILLE 95077
WAUKENA 93274
WAUKENA 93282
WAWONA 95389
WEIMAR 95713
WEIMAR 95736
WEITCHPEC 95546
WEOTT 95571
WEST POINT 95255
WEST POINT 95255
WEST POINT 95404
WEST SACRAMENTO 95605
WEST SACRAMENTO 95691
WEST SACRAMENTO 95691
West Sacramento 95691
WEST SACRAMENTO 95695
WEST SACRAMENTO 95695
WEST SACRAMENTO 95798
WEST SACRAMENTO 95828
WEST SACRAMENTO 95961
WESTLEY 95387
WESTPORT 95488
WESTWOOD 96137
WESTWOOD 96137
WHEATLAND 95692
WHEATLAND 95692
WHISKEYTOWN 96095
WHITE PINES 95223
WHITETHORN 95589
WHITETHORN 95589
WHITMORE 96096
WILDWOOD 96076
WILLIAMS 95987
WILLITS 95490
WILLOW CREEK 95573
WILLOW CREEK 96039
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 134
WILLOWS 95988
WILLOWS 95988
WILSEYVILLE 95257
WILSEYVILLE 95257
WINDSOR 95492
WINTERS 95694
WINTERS 95694
WINTERS 95695
WINTON 95301
WINTON 95388
WISHON 93669
WITTER SPRINGS 95493
WOODACRE 94973
WOODBRIDGE 95258
WOODBRIDGE 95258
WOODLAKE 93286
WOODLAND 95695
WOODLAND 95695
WOODLAND 95776
WOODSIDE 94026
WOODSIDE 94061
WOODSIDE 94062
YETTEM 93670
YOLO 95697
YORKVILLE 95494
YOSEMITE NATIONAL
PARK 95389
YOSEMITE NATIONAL
PARK 95389
YOUNTVILLE 94599
YUBA CITY 95661
YUBA CITY 95901
YUBA CITY 95991
YUBA CITY 95992
YUBA CITY 95993
YUBA CITY 95994
ZAMORA 95698
ZENIA 95595

A PPENDIX C
DA APPROVED METERS
The table below lists the makes and models of currently approved DA meters. The contents of the list is
subject to change. The list has been provided for informational purposes only.
MAKE MODEL
PSI QUAD 4
SCHLUMBERGER VECTRON LXS
GE KV