The Electric ESP Handbook
A G UIDE TO P ACIFIC G AS &E LECTRIC C OMPANY ’ S D IRECT A CCESS
P ROCEDURES FOR E LECTRIC E NERGY S ERVICE P ROVIDERS
Pacific Gas and Electric Company - ESP Services
January 16, 2012
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 ................................................... 12
EDI Trading Partner Agreement................................................................................................................................................. 12
Main Agreement ......................................................................................................................................................................... 12
Appendix .................................................................................................................................................................................... 13
EDI Setup Form ......................................................................................................................................................................... 15
Meter Data Management Agent (MDMA) qualification/approval ............................................................................................. 16
2. Electric ESP submits completed DA startup documentation to ESP Services ........................................................................... 16
3. ESP Services Representative contacts Electric ESP upon receipt of DA startup documents..................................................... 16
4. PG&E reviews all submitted DA startup documentation ........................................................................................................... 16
DA startup Documentation Review Timeline............................................................................................................................. 17
ESP Service Agreement Processing ........................................................................................................................................... 17
ESP Credit Application processing ............................................................................................................................................ 17
Credit Acceptance ...................................................................................................................................................................... 18
Credit Denial .............................................................................................................................................................................. 18
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Direct Access Consolidated Billing Options Worksheet ............................................................................................................ 18
EDI Trading Partner Agreement processing ............................................................................................................................... 18
EDI Setup Form ......................................................................................................................................................................... 18
MDMA Application and Checklist ............................................................................................................................................ 18
5. ESP Services Representative informs the Electric ESP of the type of DA participation for which it is eligible ....................... 18
Information Websites ...................................................................................................................................................... 20
CHAPTER 2 .......................................................................................................................................................................... 21
DIRECT ACCESS SETUP ........................................................................................................................................................ 21
Overview ......................................................................................................................................................................... 21
Prerequisites ................................................................................................................................................................... 21
Checklist of key steps ...................................................................................................................................................... 22
Direct Access Setup Illustrated ....................................................................................................................................... 22
Procedures ...................................................................................................................................................................... 22
Electronic data exchange synopsis.................................................................................................................................................. 23
1. Prepare systems setup for electronic data exchange .................................................................................................................. 23
2. Review electronic transfer procedures and rules as designated by PG&E for DES and EDI (if applicable). ............................ 23
Data transfer specifics: How DES is used to exchange DA information .................................................................................... 24
DES implementation....................................................................................................................................................................... 24
Key DES contacts....................................................................................................................................................................... 24
DES Web site ............................................................................................................................................................................. 25
EDI data transfer ............................................................................................................................................................ 25
EDI contacts ................................................................................................................................................................................... 26
For more information ................................................................................................................................................................. 26
EDI Direct Access transaction sets ................................................................................................................................................. 26
Transaction set 810 - Billing ...................................................................................................................................................... 26
Transaction set 814 - Direct Access Service Request (DASR)................................................................................................... 26
Transaction set 820 - Payment and Remittance Order................................................................................................................ 27
867 - Meter Usage ...................................................................................................................................................................... 27
997 - Functional Acknowledgment ............................................................................................................................................ 27
Test the viability and accuracy of data transferred to PG&E using DES ........................................................................................ 27
CHAPTER 3 .......................................................................................................................................................................... 29
PROCESSING DIRECT ACCESS SERVICE REQUESTS (DASRS)............................................................................................... 29
Overview ......................................................................................................................................................................... 29
Definition of Terms ........................................................................................................................................................................ 29
Prerequisites ................................................................................................................................................................... 30
Checklist of key steps ...................................................................................................................................................... 31
Processing DASRs Illustrated ......................................................................................................................................... 31
Procedures ...................................................................................................................................................................... 33
1. Electric ESP obtains customer authorization to submit a DASR on its behalf .......................................................................... 33
2. Electric ESP obtains customer CTC Agreement, if required ..................................................................................................... 33
3. Electric ESP evaluates customer DA elections and obtains customer information required to complete DASR ...................... 33
5. Electric ESP submits DASR to PG&E through DES ................................................................................................................ 34
6. PG&E processes DASR ............................................................................................................................................................. 35
Electronic Validation ................................................................................................................................................................. 35
DASR Validation ....................................................................................................................................................................... 35
Account Validation .................................................................................................................................................................... 35
7. PG&E sends a confirmation, rejection, or pending notification to Electric ESP ....................................................................... 36
Acceptance notices ..................................................................................................................................................................... 36
Rejection DASR ......................................................................................................................................................................... 37
Additional DASR procedures performed by PG&E ....................................................................................................................... 37
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DASR for “New” Premises ........................................................................................................................................................ 37
Additional setup transaction procedures .................................................................................................................................... 37
Additional transaction procedures for newly established PG&E account numbers .................................................................... 38
Additional Shut Off (S/O) and Shut-off Non-Payment (SONP) transaction procedures ............................................................ 39
Additional Cancellation transaction procedures ......................................................................................................................... 39
Additional Customer Account Data Change transaction procedures .......................................................................................... 39
Additional procedures for Initial Customer Historical Usage Information................................................................................. 39
Seamless Move........................................................................................................................................................................... 40
Seamless Move Procedures ............................................................................................................................................................ 40
Canceling a Seamless Move ........................................................................................................................................................... 41
Limits to a Seamless Move Option ................................................................................................................................................. 41
CHAPTER 4 .......................................................................................................................................................................... 43
DA ELECTRONIC DATA EXCHANGE CONTINGENCY PLANS ................................................................................................. 43
Overview ......................................................................................................................................................................... 43
Behind the scenes look at the DASR process ................................................................................................................................. 43
DASR Server Communication Illustrated ....................................................................................................................................... 44
Risks ............................................................................................................................................................................................... 44
Event Scenario Back-up Plans ....................................................................................................................................... 44
Electric ESP unable to communicate with DES ............................................................................................................................. 45
Situation ..................................................................................................................................................................................... 45
Back-up Plan .............................................................................................................................................................................. 45
Failure of PG&E equipment (DASR Interface & CIS) ................................................................................................................... 46
Situation ..................................................................................................................................................................................... 46
Back-up Plan .............................................................................................................................................................................. 46
CHAPTER 5 .......................................................................................................................................................................... 47
METERING ........................................................................................................................................................................... 47
Overview ......................................................................................................................................................................... 47
Metering Services ........................................................................................................................................................................... 47
Meter Service Provider Responsibilities .................................................................................................................................... 48
Meter Installation Standards....................................................................................................................................................... 48
Effective Direct Access Date ...................................................................................................................................................... 48
Meter Maintenance..................................................................................................................................................................... 48
Meter Equipment Specifications ................................................................................................................................................ 48
Obtaining Meter Equipment Information for Existing Customer Accounts ................................................................................... 49
Web Site Test ............................................................................................................................................................................. 49
Selection of the Meter Installer .................................................................................................................................................. 49
Scheduling Meter Removal and Installations - PG&E as Meter Installer .................................................................................. 49
Meters Supplied by PG&E ......................................................................................................................................................... 50
Meters Supplied by Electric ESP ............................................................................................................................................... 50
DA Ready Meter ........................................................................................................................................................................ 50
Phone Service Notification - PG&E as Meter Installer .............................................................................................................. 50
Completed Meter Installs ........................................................................................................................................................... 51
Re-scheduling Meter Installations .............................................................................................................................................. 51
Scheduling Meter Removals and Installations - Electric ESP as Meter Installer ............................................................................ 51
Meter Installation/Removal Notification * ................................................................................................................................. 52
Return of PG&E Meters ............................................................................................................................................................. 52
Service Upgrades ............................................................................................................................................................................ 52
Return to Bundled Service from Direct Access and Meter Ownership ........................................................................................... 52
Electric ESP Inquiries..................................................................................................................................................................... 54
Wired Phone Line Requirements ............................................................................................................................................... 55
Wireless Phone Installation Requirements ................................................................................................................................. 56
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Responsibility - Phone Service Account Payment .......................................................................................................................... 57
Responsibility - Phone Service Operability and Maintenance ........................................................................................................ 57
Retention of Rights ......................................................................................................................................................................... 58
Meter Data Management Agent (MDMA) Requirements ............................................................................................... 58
MDMA Approval Process and Requirements ................................................................................................................................ 58
Application and Checklist .......................................................................................................................................................... 59
Written Requirements ................................................................................................................................................................ 59
Server Acceptance Test .............................................................................................................................................................. 60
Back-up Reading Process ........................................................................................................................................................... 60
Data Format ................................................................................................................................................................................ 60
Security and Confidentiality ....................................................................................................................................................... 60
Help Desk ................................................................................................................................................................................... 61
Validating and Editing Data ........................................................................................................................................................... 61
Interval Data ............................................................................................................................................................................... 61
Estimating Data .............................................................................................................................................................................. 62
Interval Data Estimation Rules ................................................................................................................................................... 62
Accuracy and Timeliness of Usage Data ........................................................................................................................................ 63
Interval Data ............................................................................................................................................................................... 63
Monthly Data ............................................................................................................................................................................. 63
Data retention period ...................................................................................................................................................................... 63
Electronic exchange of metering data ............................................................................................................................................. 64
Interval and Time-Of-Use (TOU) data ....................................................................................................................................... 64
Meter Reading ................................................................................................................................................................................ 65
Meter reading data obligations ................................................................................................................................................... 65
PG&E meter reading .................................................................................................................................................................. 66
Electric ESP meter reading......................................................................................................................................................... 66
Metered Usage Rates ...................................................................................................................................................... 66
Life Support Customers and Medical Baseline Quantities ............................................................................................................. 66
CHAPTER 6 .......................................................................................................................................................................... 69
DASR PROCESSES FOR METERING DATA ADJUSTMENTS AND CHANGES ............................................................................ 69
Overview ......................................................................................................................................................................... 69
DA Account Commodity Status Changes ........................................................................................................................ 70
DA Account Commodity Shut-Offs................................................................................................................................................ 70
Process ....................................................................................................................................................................................... 70
Matrix of PG&E-initiated Records Related to Shut-offs by Meter Type ................................................................................... 70
Example ..................................................................................................................................................................................... 72
Meter Change ................................................................................................................................................................................. 73
Matrix of PG&E-initiated Records Related to Meter Change .................................................................................................... 73
Example ..................................................................................................................................................................................... 76
New Meter Sets Which are not Concurrent with Old Meter Removals ...................................................................................... 76
Meter Configuration Data .......................................................................................................................................................... 77
Usage Adjustments ......................................................................................................................................................... 77
Usage Adjustments to Monthly Meter Data Due to Additional Validation Checking of Data when PG&E is the MDMA ....... 78
Matrix of PG&E-initiated Records Related to Usage Adjustments ............................................................................................ 78
Example ..................................................................................................................................................................................... 80
Stand Alone Rebate transactions (reversal only adjustment)...................................................................................................... 81
CHAPTER 7 .......................................................................................................................................................................... 83
ELECTRIC ESP ACCOUNT BILLING....................................................................................................................................... 83
Overview ......................................................................................................................................................................... 83
Bill Components and Billing Options ............................................................................................................................. 83
Summary of bill components .......................................................................................................................................................... 83
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About the California Energy Commission Tax ............................................................................................................................... 84
Billing options ................................................................................................................................................................................ 85
Consolidated UDC billing .......................................................................................................................................................... 85
Consolidated ESP billing ........................................................................................................................................................... 85
Partial Consolidated ESP Billing ............................................................................................................................................... 85
Full Consolidated ESP Billing ................................................................................................................................................... 85
Separate billing .......................................................................................................................................................................... 86
Read and Bill Serial Dates .............................................................................................................................................................. 86
Consolidated UDC Billing .............................................................................................................................................. 86
Pricing options................................................................................................................................................................................ 87
Flat ($/month) ............................................................................................................................................................................ 88
Single-tiered ($/kWh) ................................................................................................................................................................. 88
Double-Tiered ($/kWh, Electric ESP designates tiers) .............................................................................................................. 88
Time-of-Use - TOU ($/kWh, based on PG&E’s tiers) ............................................................................................................... 88
Custom pricing ........................................................................................................................................................................... 89
Submitting Rate-ready data to PG&E ........................................................................................................................................ 89
Deadlines for the submission of rate-ready data ......................................................................................................................... 89
Bill format ...................................................................................................................................................................................... 89
Bill preparation and processing ...................................................................................................................................................... 89
Bill Printing and Delivery............................................................................................................................................................... 90
Reports generated by PG&E ........................................................................................................................................................... 90
Utility User Tax Application .......................................................................................................................................................... 90
How PG&E calculates Electric ESP payments ............................................................................................................................... 91
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................................................................................................................................................... 91
Payments from Electric ESP to PG&E ....................................................................................................................................... 91
Consolidated ESP Billing ............................................................................................................................................... 91
Bill format requirements ............................................................................................................................................................ 91
Calculation of charges owed to PG&E ....................................................................................................................................... 92
Payment Processing.................................................................................................................................................................... 92
Electronic Data Interchange (EDI) ............................................................................................................................................. 92
Separate Billing Procedures ........................................................................................................................................... 92
CHAPTER 8 .......................................................................................................................................................................... 93
CUSTOMER INFORMATION RELEASES .................................................................................................................................. 93
Overview ......................................................................................................................................................................... 93
Confidential Customer Information Release .................................................................................................................. 93
GLOSSARY .......................................................................................................................................................................... 95
DIRECT ACCESS TERMS ....................................................................................................................................................... 95
APPENDIX A ...................................................................................................................................................................... 101
SERVICE TERRITORY CITY CODES ..................................................................................................................................... 101
APPENDIX B ...................................................................................................................................................................... 119
SERVICE CITY ZIP CODES .................................................................................................................................................. 119
APPENDIX C ...................................................................................................................................................................... 133
DA APPROVED METERS .................................................................................................................................................... 133
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PREFACE
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
Chapters 1 through 3, which describe sequential, step-by-step procedures, follow a consistent
organizational format as described below.
Overview
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
The prerequisites to the procedures covered in the chapter are detailed, ensuring that the Electric ESP is
ready for the steps to follow.
Checklist of Key Steps
Key process steps are briefly described within a checklist format which identifies critical elements.
The [Chapter Topic] Process Illustrated
Visuals are an effective way to convey process information. When appropriate conceptual-level flow
diagrams have been included to illustrate main process steps.
Procedures
This section provides a detailed discussion of items identified within the Checklist of Key Steps.
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CHAPTER 1
ELECTRIC ESP DIRECT ACCESS
PRELIMINARY PROCEDURES
Overview
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.
Prerequisites
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 demand-
metered 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 non-
demand 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 f or Direct Access
(DA) signup with PG&E
ESP submits completed DA startup
documentation to ESP Relations
ESP Relations Representativ e
contacts ESP upon receipt of DA
startup documentation
PG&E processes
Direct Access
PG&E rev iews and executes
Consolidated Billing
ESP Service Agreement and
Options Worksheet
conducts a quick rev iew of the
ESP Credit Application
PG&E processes
EDI Trading
Partner Agreement
PG&E rev iews startup
Does ESP plan to of f er
Y es documentation required f or
Consolidated ESP billing?
Consolidated ESP billing
PG&E processes
EDI Setup Form
No
PG&E inf orms
ESP is eligible to participate in DA
PG&E ev aluates ESP that it
and of f er Separate billing. Is ESP's credit
ESP Credit No cannot of f er
approv ed?
Application Consolidated
ESP billing
Y es
PG&E inf orms ESP
that it can of f er
ESP-Consolidated
billing option.
Activ ation pending
ESP's f ulf illment of
EDI sy stems
requirements
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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 This document specifies the roles and Always
Provider Service responsibilities of both the Electric ESP
Agreement (the “ESP and PG&E with respect to DA business
Service Agreement”) 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.
2. Energy Service Document which asks for detailed Always
Provider information information about the Electric ESP which
is not included within the ESP Service
Agreement.
3. ESP Credit Application PG&E uses the Electric ESP’s Credit Always
and Electric ESP’s Application and financial statements to
financial statements evaluate the credit worthiness of the
Electric ESP.
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# DOCUMENT DESCRIPTION WHEN REQUIRED
4. Direct Access This form specifies the services and other If the Electric ESP plans
Consolidated Billing information related to the selection of to offer Consolidated ESP
Options Worksheet billing options. The form also serves as and/or Consolidated UDC
an authorization for PG&E to commence billing
preparations which are necessary to
establish the billing options selected by
the Electric ESP.
5. EDI Trading Partner The primary purpose of the agreement is If the Electric ESP plans
Agreement to establish the binding nature of financial to offer the Consolidated
charge and payment data which is ESP billing option
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 If the Electric ESP plans
relevant to the electronic transmission of to offer the Consolidated
financial charge and payment data. ESP billing option
7. MDMA Approval Forms required to apply for approval as If the Electric ESP plans
Application and an MDMA. to provide MDMA
Checklist 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)
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.
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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
4. Guarantee, with the guarantor having a credit rating of
Baa2 or higher from Moody’s
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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.
1.3 – CORPORATE GUARANTEE (PAGE 1 OF 4)
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DIRECT ACCESS CONSOLIDATED BILLING OPTIONS WORKSHEET
The following shows the first page of the Direct Access Consolidated Billing Options Worksheet.
1.4 - DIRECT ACCESS CONSOLIDATED BILLING OPTIONS W ORKSHEET (PAGE 1 OF 2)
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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.
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.
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 12
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.
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 13
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.
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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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
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 15
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.
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 16
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.
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 18
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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10/5/05 Page 19
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 WWW .PGE.COM/ESP
Energy Service Provider)
Resource Center
Gas ESP (Gas Energy WWW .PGE.COM/CTA
Service Provider) Resource
Center
EDI WWW .PGE.COM/EDI
Web Tariff Book WWW .PGE.COM/TARIFFS
DES MADS.PGE.COM
CPUC WWW .CPUC.CA.GOV
California Independent WWW .CAISO.COM
Systems Operator (CAISO)
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CHAPTER 2
DIRECT ACCESS SETUP
Overview
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.
Prerequisites
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
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
Procedures
This section provides a detailed discussion of the process steps outlined within the Checklist of Key Steps.
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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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
Fire
PG&E DASR
Que Wall Interface
ESP
CIS
CS05 Switching Logic
ESP
2.1: DASR SUBMITTAL INFORMATION FLOW CHANNELS
DES implementation
KEY DES CONTACTS
Questions regarding DES protocol or systems implementation requirements related to DES should be
directed to:
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 24
CONTACT CONTACT INFO
LYNN MCELHATTON, USER ACCESS CONTROL PHONE: (415) 973-8080
AND DES ADMINISTRATOR
EMAIL: LDMJ@PGE.COM
DES WEB SITE
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
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.
EDI data transfer
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 computerized
data can be electronically transmitted between two companies and interpreted automatically.
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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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.
EDI contacts
Questions regarding EDI protocol or systems implementation requirements related to DES should be
directed to:
CONTACT FUNCTIONAL AREA CONTACT INFO
TOM ELDER BILLING PHONE: (415) 973-5119
SENIOR PROJECT MANAGER EMAIL: TXE6@pge.com
FOR MORE INFORMATION
For additional, detailed information on the EDI process, visit the EDI Web site.
EDI Direct Access transaction sets
TRANSACTION SET 810 - BILLING
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).
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.
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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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CHAPTER 3
PROCESSING DIRECT ACCESS
SERVICE REQUESTS (DASRS)
Overview
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.
Definition of Terms
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.
TRANSACTION # COMMUNICATION DESCRIPTION OF TRANSACTION
FLOW
1 (ELECTRIC ESP TO setup/establish direct access with customer
UDC)
2 (ELECTRIC ESP TO discontinue direct access with customer
UDC)
3 (UDC TO ELECTRIC acknowledge success of direct access request
ESP)
4 (UDC TO ELECTRIC acknowledge failure of direct access request
ESP)
5 (UDC TO ELECTRIC acknowledge actual switch of service provider
ESP)
6 (ELECTRIC ESP TO acknowledge receipt of switch notification
UDC)
7 (UDC TO ELECTRIC notify of shutoff or turn-on of service
ESP)
8 (ELECTRIC ESP TO account maintenance (i.e., customer rate schedule
UDC) OR (UDC TO change)
SP)
3.1 - FLOW OF DASR TRANSACTION INFORMATION
Prerequisites
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)
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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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:
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.
Checklist of key steps
# STEP
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.
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 31
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
PG&E sends rejection ESP resolves DASR
notice to ESP & customer issues
No-reject
Yes
Accept DASR
No-pending
Pending for
PG&E sends pending
more than 11
notice to ESP & customer
Yes days?
PG&E sends No
acceptance notice to
ESP & customer
performs DASR
transaction
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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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.
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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TRANSACTION # DESCRIPTION OF REQUIRED CUSTOMER INFORMATION
TRANSACTION
1 SETUP/ESTABLISH DIRECT Customer Name
ACCESS WITH CUSTOMER 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*
2 DISCONTINUE DIRECT UDC Customer Account Number
ACCESS WITH CUSTOMER Service Relationship Energy Provided (i.e.
electric, gas)
Customer Name
Service Account Address and current service
Zip
6 ACKNOWLEDGE RECEIPT Provide information contained in the
OF SWITCH NOTIFICATION acknowledgment of actual switch of service
provider
10 ACCOUNT MAINTENANCE UDC Customer Account Number
(I.E., CUSTOMER RATE Service Relationship Energy Provided (i.e.
SCHEDULE CHANGE) electric, gas)
Customer Name
Service Account Address
Account information the customer wants to
change
11 ACCOUNT UPDATE (I.E. Same as #10, Account Maintenance, above
METERING
RELATIONSHIPS, BILLING
OPTIONS)
5. Electric ESP submits DASR to PG&E through DES
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:
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.
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 34
6. PG&E processes DASR
The illustration below represents the timing associated with processing a DASR.
Day 0 Day 2 Day 7 Day 18
PG&E w ill provide, along
PG&E sends
PG&E sends w ith the confirmation
DASR
acknow ledgment notice, information
Does PG&E acceptance
to ESP that they Y es regarding w hen the DA
accept the DASR confirmation
have received the customer w ill begin
to ESP &
DASR receiving ESP services,
customer
unless a meter is required
PG&E
notifies ESP
No
& customer
PG&E w ill confirm or reject
of error
DASRs in error pending
pending
status
status or
rejected
DASR
3.1 - DASR PROCESSING TIMELINE
ELECTRONIC VALIDATION
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
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unique non-changing customer-commodity-location specific number called the External 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:
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.
Canceling a Seamless Move
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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CHAPTER 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
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
Fire
PG&E DASR
Que Wall Interface
ESP
CIS
CS05 Switching Logic
ESP
4.1 - INFORMATION FLOW BETWEEN QUE AND DASR INTERFACE
Risks
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.
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Electric ESP unable to communicate with DES
ESP
Fire
PG&E DASR
DES Wall Interface
ESP
CIS
CS05 Switching Logic
ESP
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
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, 19th Floor, San Francisco, CA 94105.
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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
Fire
PG&E DASR
Que Wall Interface
ESP
CIS
CS05 Switching Logic
ESP
4.3 - FAILURE OF PG&E EQUIPMENT
SITUATION
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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CHAPTER 5
METERING
Overview
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).
Metering Services
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 customer-
owned 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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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
Service Upgrades
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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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).
ESP Inquiries
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.
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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.
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.
Retention of Rights
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
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Validate, edit and estimate meter data
Format data
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.
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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.
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.
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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.
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
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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.
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).
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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.
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
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.
Data retention period
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
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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.
Meter
MV-90
ESP
VEE
Process
Firewall Internal
Data Exchange Server Server
5.1 - METERING CONFIGURATION CHANGES AND METERING CHANGE OUTS
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.
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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 .
Meter Reading
METER READING DATA OBLIGATIONS
1. Meter data for DA Customers shall be read, validated, edited, and transferred pursuant to CPUC-
approved 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.
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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.
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:
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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.
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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CHAPTER 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 ISSUE RECORD TO CURRENT ISSUE RECORD TO
CURRENT ELECTRIC ESP, ELECTRIC ESP AND BILL CURRENT ELECTRIC
PENDING ELECTRIC ESP, CALCULATOR ESP AND BILL
AND ALL ASSOCIATED CALCULATOR
ELECTRIC ESPS
RECORD TYPE MEPAD01 MEPMD01 MEPMD02
ISSUED
MONTHLY SINGLE- One MEPAD01 record: One MEPMD01 record: One MEPMD02
METERED record:
Operation Type field = Normal start/end read
“SVC” information record. Normal totalized
usage information
Reason field = record.
“DISCONNECT”
Effective End Date
Field = date the account
commodity was closed
MONTHLY MULTI- Same as above A MEPMD01 record for each A MEPMD02 record:
METERED meter:
Normal totalized
Normal start/end read usage information
information record record.
Meter field = “TOTAL”
INTERVAL SINGLE- Same as above 1. One or more MEPMD01 None
METERED 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.
INTERVAL MULTI- Same as above 1. One or more MEPMD01 None
METERED 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”
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ACTION ISSUE RECORD TO ISSUE RECORD TO CURRENT ISSUE RECORD TO
CURRENT ELECTRIC ESP, ELECTRIC ESP AND BILL CURRENT ELECTRIC
PENDING ELECTRIC ESP, CALCULATOR ESP AND BILL
AND ALL ASSOCIATED CALCULATOR
ELECTRIC ESPS
DEMAND METERED Same as above One MEPMD01 Record: 1. One MEPMD02
normal start/end red record: normal
information record 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 shut-
off 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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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.
Meter Change
A meter change should not cause an interruption of DA service. Monthly, interval, demand, and time-of-
use (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 ISSUE RECORD TO CURRENT ELECTRIC ESP
ESP AND BILL CALCULATOR AND BILL CALCULATOR
RECORD TYPE MEPMD01 MEPMD02
ISSUED
MONTHLY SINGLE- One MEPMD01 record for the old One MEPMD02 record:
METERED meter: normal start/end read
information Normal totalized usage information record
for both meters
Meter field = old meter number
Meter field = “TOTAL”
One MEPMD01 record for the
new meter: normal start/end read
information
Meter field = new meter number
MONTHLY MULTI- One MEPMD01 record for each One MEPMD02:
METERED old meter removed: normal
start/end read information Normal usage information record totalizing
usage for all meters.
Meter field = old meter number
Meter field = “TOTAL”
One MEPMD01 record for each
new meter installed: normal
start/end read information
Meter field = new meter number
INTERVAL SINGLE- One MEPMD01 record for the old None
METERED 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”
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ACTION ISSUE RECORD TO CURRENT ELECTRIC ISSUE RECORD TO CURRENT ELECTRIC ESP
ESP AND BILL CALCULATOR AND BILL CALCULATOR
INTERVAL MULTI- One MEPMD01 record for each None
METERED 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 One MEPMD02 record for the old
meter: normal start/end read meter: usage information (kwh)
information (kwhreg)
One MEPMD02 record for the new
Meter field = old meter number meter: usage information (kwh)
One MEPMD01 record for the One MEPMD02 record for the old
new meter: normal start/end read meter: demand usage information (kw)
information (kwhreg)
One MEPMD02 record for the new
Meter field = new meter number meter: demand usage information (kw)
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ACTION ISSUE RECORD TO CURRENT ELECTRIC ISSUE RECORD TO CURRENT ELECTRIC ESP
ESP AND BILL CALCULATOR AND BILL CALCULATOR
TOU METERED None One MEPMD02 records for the old
meter: start reads information
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”
EXAMPLE
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 ISSUE RECORD TO CURRENT ELECTRIC ESP
ESP AND BILL CALCULATOR AND BILL CALCULATOR
RECORD TYPE MEPMD01 MEPMD02
ISSUED
MONTHLY SINGLE- One MEPMD01 record with the One MEPMD02 record for each adjusted
METERED adjusted read in the Data field for period with the adjusted total usage
each adjusted period
Example for a two months adjustment:
Example for a two months
adjustment: Eff Start field = “199804150001”
Data field = “199804150001, Eff End field = “199805150001”
,750,199805150001,A,1300”
Data field = “TOTAL,A,550”
Data field = Eff Start field = “199805150001”
“199805150001,A,1300,19980615
0001,A ,1650” Eff End field = “199806150001”
Data field = “TOTAL,A,350”
MONTHLY MULTI- One MEPMD01 record for the One MEPMD02 record for each adjusted
METERED adjusted meter, with the adjusted period with the adjusted totalized usage for
reads in the Data field (similar to all the meters (similar to single-metered
monthly single-metered reads usage adjustment record).
adjustment record).
Meter field = “TOTAL”
Meter field = adjusted meter number
INTERVAL SINGLE- One or more MEPMD01 record(s) None
METERED 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).
INTERVAL MULTI- Same as above. None
METERED
DEMAND METERED One MEPMD01 record with the One MEPMD02 record with the
adjusted reads in the Data field adjusted total usage in the Data field
(similar to monthly single-metered (similar to monthly single-metered
reads adjustment record). usage adjustment record).
One MEPMD02 with the adjusted
demand usage information (similar to
the monthly single-metered usage
adjustment record).
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ACTION ISSUE RECORD TO CURRENT ELECTRIC ISSUE RECORD TO CURRENT ELECTRIC ESP
ESP AND BILL CALCULATOR AND BILL CALCULATOR
TOU METERED None One MEPMD02 record with the
adjusted start reads information
One MEPMD02 record with the
adjusted end reads information
One MEPMD02 record with the
adjusted totalized usage information
EXAMPLE
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 DATE MEPMD02 MEPMD01:
NAME USAGE START READ END READ
PG&E 2/15 -3/15 400 KW H 0 400
PG&E 3/15 - 4/15 350 KW H 400 750
ESP 4/15 - 5/15 500 KW H 750 1250
ESP 5/15 - 6/15 400 KW H 1250 1650
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 DATA INCLUDED IN RECORD
ISSUED
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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CHAPTER 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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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.
Billing options
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
conformance with PG&E’s specifications. The Electric ESP must obtain PG&E’s consent and approval
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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 W ORKSHEET
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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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 rate-
ready 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.
Bill format
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
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.
Daily Billing File
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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CHAPTER 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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GLOSSARY
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
Utilities Commission (PUC) or the CPUC.
COMPETITIVE TRANSITION Defined in Public Utilities Code Section 840 and by the Commission.
CHARGE (CTC)
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 The Public Utilities Commission of the State of California.
UTILITIES COMMISSION)
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 An application for Direct Access Service submitted to PG&E on behalf of a Customer by an
REQUEST (DASR) 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.
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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.
ELECTRIC SUPPLY OR Includes, but is not limited to, procurement of electric energy; all scheduling; settlement, and
PROCUREMENT SERVICES other interactions with Scheduling Coordinators, the ISO and the PX; all ancillary services and
congestion management.
ELECTRONIC DATA INTERCHANGE The electronic transmission and receipt of data and/or funds in agreed upon formats in
(EDI) accordance with PG&E’s specifications.
ENERGY SERVICE PROVIDER An entity who provides electric supply services to DA Customers within PG&E’s service
(ESP) territory. An ESP may also provide certain metering and billing services to its DA Customers as
provided for within these tariffs.
FIXED TRANSITION AMOUNT (FTA) A non-bypassable, separate charge that is authorized by the Commission to be charged to
CHARGE 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.
FULL SERVICE As defined in Rule 22.
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 The California Independent System Operator Corporation, a state chartered, non-profit
(ISO) 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 the entity that takes raw meter outputs, validates them using validation, editing, and estimating
AGENT (MDMA) rules, adds corollary information needed to characterize the customer, and makes complete
customer information available to others for use in various applications.
METER SERVICE PROVIDER The entity that installs, validates, registers, and maintains the physical meter required on a
(MSP) premise to measure the required variables.
METERING FACILITIES OR A meter, its associated current and potential transformers, test facilities, communication
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METERING EQUIPMENT interfaces, and other associated metering equipment required for the measurement of supply
deliveries to a Customer’s Account.
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-ampere-
hours 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 A non-bypassable surcharge imposed on all retail sales of electricity and electrical services to
CHARGES 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/ An applicant’s contractor or subcontractor who:
SUBCONTRACTOR (QC/S)
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 The date PG&E has scheduled a Customer’s meter to be read for the purposes of ending the
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DATE current billing cycle and beginning a new one. PG&E’s meter reading schedule is published
annually, but is subject to periodic change.
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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APPENDIX A
SERVICE TERRITORY CITY
CODES
CITY CODE LETTERS CORRESPOND TO THE SECOND AND THIRD CHARACTERS OF THE CUSTOMER ACCOUNT NUMBER.
CITY NAME CITY ALLEGHANY IU ANDRUS ISLAND PP
CODE
ALLENSWORTH AF ANGELS CAMP XB
ACADEMY TK
ALMANOR Q1 ANGWIN N2
ACAMPO AK
ALPAUGH AF ANNAPOLIS 1N
ADAMS SPRINGS ZH
ALTA H1 ANNAPOLIS 1N
AGNEW VP
ALTAVILLE XB ANTELOPE AN
AGUA CALIENTE NV
ALTO NK ANTIOCH JC
AHWAHNEE AE
ALTON KT APPLEGATE H2
ALAMEDA JP
ALVISO AV APTOS AP
ALAMO AL
AMADOR CITY QB ARBUCKLE DB
ALBANY AB
AMBOY T3 ARCATA AC
ALBION QA
AMERICAN CANYON NY ARGUS TD
ALDER SPRINGS FJ
ANCHOR BAY P2 ARNOLD XA
ALDER SPRINGS TK
ANDERSON AS AROMAS XK
ALDERPOINT G4
ANDERSON SPRINGS ZM AROMAS XK
ALEXANDER VALLEY NH
ARROYO GRANDE AG BANTA X2 BETHANY XV
ARROYO GRANDE AG BASS LAKE LD BETHEL ISLAND BI
ARROYO SECO GF BAXTER H3 BETTERAVIA BX
ARTOIS 9A BAY POINT DP BIEBER UQ
ARVIN AR BAYLISS FJ BIG BEND UD
ASTI 2N BAYSIDE YS BIG BEND H8
ATASCADERO WW BAYWOOD PARK LG BIG BEND VILLAGE DS
ATHERTON AT BEALE AFB BY BIG LAGOON LF
ATWATER AW BEAR VALLEY 9S BIG MEADOW TJ
AUBERRY AU BEAR VALLEY ZS BIG OAK FLAT EF
AUBURN HB BEAR VALLEY 2T BIG SPRINGS FP
AUBURN HB BEAR VALLEY TR BIG SUR ME
SPRING
AUCKLAND TJ BIGGS JM
BELDEN Q9
AUKUM XD BIOLA BA
BELL SPRINGS LM
AVENAL AZ BIRCHVILLE HM
BELLA VISTA VH
AVERY XY BIRDS LANDING P7
BELLA VISTA VH
AVILA BEACH AA BIRDS LANDING PP
BELMONT RN
AVON JG BITTERWATER BJ
BELVEDERE NU
BACHELOR VALLEY ZU BLACK POINT NM
BEN LOMOND BP
BADGER AD BLACKWELLS TX
BENBOW LM CORNER
BAKER RANCH GE
BEND FN BLAKES LANDING MM
BAKERSFIELD TC
BENICIA BE BLOCKSBURG KD
BAKERSFIELD TC
BERENDA TN BLOOMFIELD NN
BAKERSFIELD TC
BERKELEY JR BLUE CANYON H5
BALLARD B7
BERKELEY JR BLUE LAKE CQ
BALLICO BQ
BERRY CREEK IY BLUE LAKE CQ
BANGOR YB
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BODEGA BB BROWNS VALLEY BL CALWA TK
BODEGA BAY BB BROWNSVILLE IV CAMANCHE XD
BODEGA BAY BB BRUSH CREEK IH CAMBRIA KA
BOGARD STATION FF BRYTE WS CAMDEN TT
BOLINAS BZ BUCKINGHAM PARK ZK CAMERON PARK GS
BONNY DOON VT BUCKS LAKE FP CAMINO GP
BOONVILLE UF BUELLTON B9 CAMP CONNELL XA
BOOTJACK TS BUMBLEBEE XR CAMP MEEKER CR
BORON BO BURLINGAME BS CAMP MONTECITO TJ
BOULDER CREEK BC BURNEY FF CAMP SACRAMENTO HT
BOWLES TT BURNT RANCH L3 CAMPBELL CM
BOWMAN HB BURREL BF CAMPBELL CM
BOYES HOT 7N BURREL BF CAMPO SECO XE
SPRINGS
BURSON XI CAMPO SECO VS
BRADLEY DC
BURSON XI CAMPTONVILLE IQ
BRADLEY DC
BUTTE CITY ET CANTUA CREEK KK
BRANNAN ISLAND PP
BUTTE MEADOWS F1 CANYON J2
BRANSCOMB W9
BUTTONWILLOW BU CANYON DAM Q4
BRENTWOOD BW
BYRON BN CAPAY FJ
BRICELAND LM
CACHAGUA CY CAPAY 3P
BRIDGEPORT HM
CACHUMA 3B CAPITOLA CP
BRIDGEVILLE KE
CADIZ 2C CARBONA XV
BRIGHTON PS
CALAVERAS BIG XA CARIBOU FP
BRISBANE AH TREES
CARLOTTA KH
BROOKDALE BD CALIFORNIA VALLEY 3C
CARMEL CE
BROOKS 2P CALISTOGA N3
CARMEL HIGHLAND CE
BROWNS FLAT XR CALPELLA UG
CARMEL VALLEY CY
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CARMEL VALLEY CE CHALLENGE YQ CLINTON XD
CARMICHAEL CA CHAMBLESS TD CLIPPER GAP HB
CARRISA PLAINS T4 CHEROKEE FM CLIPPER MILLS IM
CARSON HILL XB CHESTER Y8 CLOVERDALE ND
CARUTHERS CB CHICAGO PARK JF CLOVIS CI
CARUTHERS CB CHICO FB CLYDE CD
CASMALIA B6 CHILES VALLEY N3 COALINGA TF
CASPAR QC CHINESE CAMP EJ COARSEGOLD GO
CASSEL UR CHOLAME DG COBB ZH
CASTLE GARDENS TR CHOWCHILLA TP COHASSET FB
CASTRO VALLEY CV CHOWCHILLA TP COLD CREEK NX
CASTROVILLE CT CHRISTIAN VALLEY HB COLD SPRINGS YU
CATHEYS VALLEY CZ CHROME FJ COLFAX HF
CAWELO TX CHUALAR CF COLLEGE CITY CC
CAYTON VALLEY FF CISCO GROVE H8 COLLINSVILLE PP
CAYUCOS KY CITRUS HEIGHTS CH COLMA AI
CAZADERO 4N CLARKSBURG CG COLOMA GQ
CEDAR FLAT LW CLARKSVILLE HT COLUMBIA YW
CEDAR GROVE TJ CLAY XF COLUSA PX
CEDAR RIDGE JE CLAYTON CL COMPTCHE UH
CEDARBROOK TJ CLEAR CREEK Q7 CONCORD JG
CENTERVILLE FB CLEARLAKE ZC CONCOW FM
CENTERVILLE KQ CLEARLAKE OAKS ZE CONEJO TT
CENTERVILLE TK CLEARLAKE PARK ZP CONFIDENCE XR
CENTRAL VALLEY VE CLEMENTS KM COOL GD
CERES AJ CLEONE NF COPPEROPOLIS XC
CERES AJ CLINGANS JUNCTION TJ CORCORAN TG
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CORDELIA PK CUYAMA VALLEY CJ DIGIORGIO TC
CORDELIA PJ DAGGETT TD DILLON BEACH ZD
CORNING WF DAIRYVILLE FN DINSMORE KE
CORRAL DE TIERRA BT DALY CITY RB DINUBA TJ
CORRALITOS VX DANA DY DINUBA TJ
CORTE MADERA CN DANVILLE DD DIXON PF
COTATI CO DAVENPORT DN DIXON PF
COTTONWOOD KO DAVIS PY DOBBINS DO
COTTONWOOD KO DAYTON FB DONNER SUMMITT H8
COULTERVILLE CX DE SABLA FM DORRINGTON XA
COULTERVILLE CX DEER PARK N4 DOS PALOS DZ
COVELO W7 DEHAVEN QW DOS PALOS (SOUTH) DT
COW CREEK SR DEL LOMA L1 DOS PALOS (SOUTH) TM
COYOTE VR DEL PASO HEIGHTS PS DOS PALOS Y TM
CRESCENT MILLS EY DEL REY DR DOS RIOS W6
CRESSEY CS DEL REY DR DOUGLAS FLAT XG
CRESSMAN AU DEL REY OAKS BT DOWNIEVILLE HJ
CRESTON DQ DELEVAN PX DRUM VALLEY TJ
CROCKETT CK DELFT COLONY TJ DRYTOWN QD
CROWS LANDING X6 DELHI 1X DUBLIN DU
CUMMINGS G5 DENAIR DK DUNCAN MILLS M1
CUNNINGHAM NR DENAIR DK DUNLAP DI
CUPERTINO VV DENVERTON FS DUNNIGAN DB
CUSHENBURY TD DERBY ACRES DE DUNNIGAN DB
SPRINGS
DIABLO DL DURHAM DH
CUTLER CW
DIAMOND SPRINGS GT DUSTIN ACRES DA
CUTTEN LF
DIBBLE CREEK FN DUTCH FLAT H4
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 105
EARLIMART EA ELK RIVER LF FEATHER FALLS IF
EAST NICOLAUS HP ELKHORN BT FELLOWS FW
EAST NICOLAUS NO ELMIRA EI FELTON FE
EAST OAKLAND JQ ELVERTA EV FERNBRIDGE KJ
EAST PALO ALTO EP ELVERTA EV FERNDALE KQ
EASTON TK ELVERTA EV FETTERS HOT NV
SPRINGS
ECHO LAKE HT EMERYVILLE EM
FIDDLETOWN QE
EDISON TC EMIGRANT GAP H5
FIELDBROOK OX
EDWARDS ED EMMET B6
FIELDS LANDING YL
EDWARDS (NORTH) ED EMPIRE ER
FINLEY ZF
EDWARDS AFB ED ENTERPRISE FQ
FIREBAUGH FG
EEL ROCK LM ESCALON X5
FISH CAMP YF
EL CAMINO WF ESCALON X5
FITCH MOUNTAIN NH
EL CERRITO EC ESHOM VALLEY TJ
FIVE POINTS FT
EL DORADO GV ESPARTO 4P
FLORIN PS
EL DORADO HILLS GW ETTERSBURG 1G
FLOURNOY OF
EL GRANADA VG EUREKA LF
FOLSOM FL
EL MACERO EO FAIR OAKS FO
FORBESTOWN IT
EL NIDO EN FAIR PLAY HT
FORD CITY TV
EL PORTAL EL FAIRFAX FX
FOREST IX
EL SOBRANTE ES FAIRFIELD PJ
FOREST GLEN 8F
EL VERANO NV FAIRHAVEN AM
FOREST KNOLLS FK
ELDERWOOD WJ FAIRMEAD TP
FOREST RANCH F9
ELDRIDGE NV FALL RIVER MILLS UE
FORESTHILL GE
ELK P3 FALLON ZB
FORESTVILLE FV
ELK CREEK 9E FAMOSO TX
FORESTVILLE FV
ELK GROVE EG FARMINGTON FA
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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FORT BRAGG NF FRUITLAND LM GONZALES GZ
FORT ORD SS FRUITVALE TC GOODYEARS BAR JD
FORT ORD MA FULTON FU GRAND ISLAND PP
FORT ROSS 5N GALT GA GRANITE BAY HS
FORT SEWARD 2G GALT GA GRANITE BAY KR
FORTUNA LJ GANNS MEADOW XA GRANITE STATION TC
FOSTER CITY FC GARBERVILLE LM GRAPEVINE TC
FOUR COURNERS TD GARDEN VALLEY GG GRASS VALLEY HM
FOWLER FI GARDENLAND PS GRATON GR
FRANKLIN PS GAREY BX GRAYSON X7
FRANZ VALLEY NL GENERAL GRANT TJ GREELEY HILL 7G
GROVE
FREEDOM XM GREENACRES TC
GENESEE EZ
FREEPORT PS GREENBRAE LK
GEORGETOWN GH
FREESTONE NR GREENFIELD GF
GERBER GB
FREMONT JJ GREENFIELD TC
GEYSERS ND
FRENCH CAMP FH GREENVILLE YG
GEYSERVILLE NC
FRENCH CAMP FH GREENWOOD GI
GILROY VF
FRENCH CORRAL JO GRIDLEY FD
GLEN ELLEN 6N
FRENCH CORRAL IJ GRIMES ZA
GLENBURN DX
FRENCH GULCH ZG GRIMES ZA
GLENCOE QV
FRESH POND HT GRIZZLEY BLUFF LJ
GLENHAVEN ZJ
FRESHWATER LF GRIZZLY FLATS GX
GLENN 9G
FRESNO TK GRIZZLY ISLAND FS
GOLD HILL HT
FRESNO TK GROVELAND YY
GOLD LAKE IG
FRIANT FR GROVER BEACH GC
GOLD RIVER RA
FRIANT FR GUADALUPE B8
GOLD RUN H6
FRIANT FR GUALALA P4
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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GUERNEVILLE NG HAYWARD JK HORSE CORAL FLAT TJ
GUERNSEY TG HEALDSBURG NH HUB TT
GUINDA 5P HEART MEADOW TJ HUGHSON HG
GUSTINE GU HELM HE HUGHSON HG
GUSTINE GU HENLEYVILLE WF HUMBOLDT HILL LF
HACIENDA FV HERCULES HR HUME LAKE HK
HALCYON AG HERITAGE RANCH BR HUMPHREYS TK
STATION
HALES GROVE LM HERNDON TK
HUNTER LIG RES JO
HALF MOON BAY RH HICKMAN HC
HURLETON FQ
HAMES VALLEY DC HIGHWAY CITY TK
HURON HU
HAMILTON CITY 9H HILLCREST FF
HYDESVILLE KV
HAMILTON FIELD NM HILLSBOROUGH HL
IGNACIO NM
HAMLET NN HILMAR HQ
IGO W1
HAMMONTON HP HILTON NG
INDIAN FALLS FP
HANFORD HA HOBERGS ZH
INVERNESS IN
HANFORD HA HOLLISTER BG
INYOKERN C9
HANFORD HA HOLLYDALE PARK NR
IONE QF
HARDON FLAT XR HOLMES LJ
IOOF PARK NG
HARDWICK TT HOLY CITY VJ
IRWIN XX
HARMONY T7 HOLY CITY VJ
ISLAND MOUNTAIN 3G
HARRIS 4G HONCUT FQ
ISLETON P8
HARTLAND TJ HONEYDEW KU
JACKASS HILL XR
HASTINGS ISLAND PP HONEYDEW KU
JACKSON XD
HAT CREEK US HOOPA L1
JACKSONVILLE XR
HATHAWAY PINES XO HOPETON TR
JACOBY CREEK LF
HAUSNA AG HOPLAND UI
JAMESTOWN YZ
HAWKINS BAR L8 HORNITOS HN
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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JARBO GAP FM KIRKWOOD WF LANARE TT
JEFFERSONVILLE XR KNEELAND KL LARGO UI
JENNER 5N KNIGHTS FERRY XN LARKFIELD NR
JENNY LIND XT KNIGHTS LANDING KS LARKSPUR LK
JOHNSON PARK TU KNIGHTSEN K3 LAS CRUCES 2B
JOLON JO KNOWLES TN LAS DELTA TM
JONESVILLE FB KORBEL KB LASSEN CAMP MW
JOYCE ISLAND FS KRAMER JUNCTION TD LATHROP LP
KEDDIE Y3 KYBURZ GY LATHROP LP
KELSEY G1 LA GRANGE LR LATHROP LP
KELSEYVILLE ZK LA HONDA LH LATON LX
KENSINGTON KN LA HONDA LH LATON LX
KENTFIELD KF LA PORTE IL LATROBE HT
KENWOOD KW LA PURISMA 2B LAYTONVILLE W8
KERMAN TH LA SELVA BEACH VX LAYTONVILLE W8
KETTENPOM LM LAFAYETTE LY LE GRAND LQ
KETTLEMAN CITY KC LAGUNITAS LU LEBEC LE
KEYES 2X LAKE ALMANOR Q2 LEESVILLE 9S
KEYES 2X LAKE BERRYESSA N7 LEGGETT 5G
KEYSTONE XR LAKE DON PEDRO SX LEMOORE TL
KING CITY BJ LAKE DON PEDRO CX LIBERTY FARMS PK
KING SALMON LF LAKE DON PEDRO LR LINCOLN HD
KINGS CANYON KG LAKE MADRONE FQ LINCOLN HD
NATIONAL PARK
LAKE OF THE PINES HM LINDA HP
KINGSBURG KI
LAKEHEAD LB LINDEN LI
KINGSBURG KI
LAKEPORT NJ LITTLE GRASS IL
KINGVALE H8 VALLEY
LAMONT LT
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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LITTLE NORWAY 8R LOS ALTOS HILLS LA MANTON MQ
LITTLE RIVER QL LOS BANOS TM MAPLE CREEK LF
LITTLE VALLEY W5 LOS BERROS AG MARICOPA MF
LIVE OAK LO LOS GATOS VJ MARICOPA HEIGHTS TV
LIVE OAK LO LOS GATOS VJ MARINA MA
LIVERMORE JN LOS MOLINOS OM MARINWOOD NQ
LIVINGSTON LV LOS OLIVOS B5 MARIPOSA TS
LOCH LOMOND ZO LOS OSOS LG MARSHALL MM
LOCKEFORD LC LOST HILLS LL MARSHALL MM
LOCKWOOD VW LOTUS 8S MARSHALL STATION TK
LODI XF LOVELOCK FM MARTELL QP
LODOGA FJ LOWER LAKE ZL MARTINEZ MR
LOLETA KX LUCERNE ZI MARTINS BEACH RH
LOLETA KX LUCERNE VALLEY T8 MARYSVILLE HP
LOMA MAR VM LYONSVILLE PC MATHER AFB MN
LOMA RICA HP LYTTON NC MAXWELL EU
LOMPICO FE MAD RIVER KZ MC ARTHUR UU
LOMPOC 2B MADERA TN MC CANN LM
LONDON TJ MADERA TN MC CLELLAN FIELD PS
LONE STAR TK MADISON 6P MC FARLAND MC
LONG BARN EB MAGALIA F3 MC KINLEYVILLE MV
LONGVALE NZ MAGUNDEN TC MC KITTRICK MK
LONOAK BJ MALAGA TK MEADOW LAKES TK
LOOMIS LZ MANCHESTER P1 MEADOW VALLEY EX
LOOMIS LZ MANILA LF MEADOW VISTA GJ
LOS ALAMOS B4 MANTECA XH MEADOWMONT XB
LOS ALTOS LA MANTECA XH MENDOCINO QM
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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MENDOTA MY MODESTO XJ MOUNT BULLION TS
MENLO PARK MP MOJAVE T5 MOUNT HAMILTON VP
MERCED TR MOKELUMNE HILL QT MOUNT HERMON MT
MERCED FALLS TR MOKELUMNE HILL QT MOUNTAIN RANCH XQ
MERIDIAN EK MOLINO NR MOUNTAIN REST TK
MERRITT ISLAND PP MONMOUTH TT MOUNTAIN VIEW VL
METTLER STATION MZ MONO PINES XR MUIR BEACH OW
MI WUK VILLAGE UW MONO VISTA XR MUROC TD
MICHIGAN BLUFF GE MONSON TJ MURPHYS XU
MIDDLETOWN ZM MONTA VISTA VV MYERS FLAT G6
MIDPINES TS MONTARA VD NAPA NL
MILL CREEK MX MONTE RIO ZR NASHVILLE HT
MILL VALLEY NK MONTE SERENO MS NAVARRO UJ
MILLBRAE MI MONTEREY BM NAVELENCIA RV
MILLVILLE MJ MONTGOMERY UT NELSON NA
CREEK
MILPITAS ML NEVADA CITY HH
MOONSTONE BEACH LF
MINERAL MW NEW CUYAMA 3N
MOOSE CAMP FF
MINKLER SR NEW IDRIA AY
MORAGA MG
MINTURN TN NEWARK NE
MORGAN HILL MH
MIRABLE PARK FV NEWBERRY C4
MORGAN HILL MH SPRINGS
MIRAMONTE MU
MORRO BAY MB NEWCASTLE GK
MIRANDA 6G
MOSS BEACH VK NEWMAN XL
MISSION DISTRICT SL
MOSS LANDING MD NEWVILLE FJ
MISSION HILLS 2B
MOUNT AUKUM GP NICASIO N8
MO TRIANGLE TV
MOUNT AUKUM 8P NICE ZN
MOCCASIN YY
MOUNT AUKUM 8P NICOLAUS NO
MODESTO XJ (NORTH)
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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NIMSHEW FM OCCIDENTAL OC OROVILLE FQ
NIPINNAWASEE TQ OCEANO OO ORRS HOT SPRINGS NX
NIPOMO B2 ODD FELLOWS EB OSWALD HP
NIPOMO B2 OIL CENTER TC OUTINGDALE HT
NORD FB OILDALE TC PACHECO PA
NORDEN H8 OLD CUYAMA TV PACIFIC GROVE PG
NORTH COLUMBIA HM OLD RIVER TC PACIFIC HOUSE HV
NORTH FORK NT OLD STATION UX PACIFICA RP
NORTH HIGHLANDS HI OLEANDER TK PAGES CORNER TK
NORTH SAN JUAN IO OLEMA OA PAICINES AY
NORTHWOOD ZR OLIVEHURST OL PALERMO IP
NOVATO NM OMO RANCH HX PALO CEDRO AO
NOYO NF ONO V3 PANOCHE VALLEY AY
NUBIEBER UV OPHIR HB PARADISE FM
O'BRIEN LB ORA VISTA FQ PARADISE PINES FM
O'NEALS ON ORANGE COVE OE PARKFIELD KP
OAK RUN OU ORANGEVALE OV PARLIER PE
OAK RUN OU ORCUTT 4B PASKENTA XP
OAK SHORES BR ORD BEND FJ PASO ROBLES BK
OAK SHORES DC OREGON CITY FM PATTERSON X8
OAKDALE XN OREGON HOUSE OH PAYNES CREEK PC
OAKHURST TQ ORICK OI PEACH TREE BJ
OAKLAND JQ ORINDA OR PEARDALE HM
OAKLAND JQ ORLAND FJ PEBBLE BEACH PB
OAKLEY OK ORLEANS L2 PENN VALLEY IJ
OAKVILLE OQ OROSI OS PENNGROVE 9P
OCCIDENTAL OC OROVILLE FQ PENNINGTON FQ
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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PENRYN GL PIONEER POINT TD PRATHER PR
PEPPERWOOD LF PISMO BEACH PW PRATTVILLE Q1
PESCADERO VO PITTSBURG JH PRESIDIO PT
PETALUMA NN PITTVILLE FF PRESTON NC
PETALUMA NN PLACERVILLE HT PRINCETON EQ
PETALUMA NN PLANADA PM PRINCETON VG
PETERS XT PLATINA 8A PROBERTA RW
PETROLIA JV PLEASANT GROVE PO PROJECT CITY WO
PETROLIA JV PLEASANT GROVE PO PRUNEDALE BT
PHILLIPSVILLE G9 PLEASANT HILL PH PULGA F6
PHILO UK PLEASANT VALLEY HT PUMPKIN CENTER TC
PIEDMONT PD PLEASANTON PL QUAIL FLAT TJ
PIEDRA SR PLEASANTON PL QUINCY FP
PIERCY G7 PLYMOUTH QS RACKERBY IK
PIKE CITY IZ POINT ARENA NP RAILROAD FLAT QX
PILOT HILL GN POINT REYES PQ RAINBOW TAVERN H8
PINE FLAT SR POINT REYES PQ RAISIN CITY RR
STATION
PINE GROVE QJ RANCHO CORDOVA RA
POLLOCK PINES HW
PINE MOUNTAIN XR RANCHO MURIETA RF
LAKE POND TX
RANCHO TEHAMA WF
PINE RIDGE AU PONDEROSA SKY PC
RANCH RAYMOND RY
PINECREST YU
PONDOSA 1W RAYMOND RY
PINEDALE PI
POPE VALLEY N5 RAYMOND RY
PINEHURST PU
PORT COSTA DF RED BANK FN
PINNACLES AY
PORTOLA VALLEY PV RED BANK WJ
PINOLE PN
POTTER VALLEY UM RED BLUFF FN
PIONEER QK
PRAIRIE CREEK LF RED MOUNTAIN TD
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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RED TOP C8 RIO LINDA RL RUTH JY
REDCREST JW RIO NIDO 9N RUTHERFORD N6
REDDING FY RIO OSO RO RYDE PP
REDWAY G2 RIO VISTA PP RYER ISLAND PP
REDWOOD CITY RC RIPON X4 SACRAMENTO PS
REDWOOD CREEK LW RIVER PINES QG SALIDA ID
REDWOOD ESTATES RE RIVERBANK RI SALINAS BT
REDWOOD ESTATES RE RIVERBANK RI SALMON CREEK BB
REDWOOD VALLEY UN RIVERDALE RZ SALYER L4
REDWOOD VALY L3 RIVERDALE RZ SAMOA AM
REEDLEY RV RIVERTON HT SAN ANDREAS ZT
REEDLEY RV ROBBINS ZQ SAN ANSELMO SW
RESCUE HY ROCKLIN RT SAN ARDO AQ
RHEEM RM ROCKPORT QR SAN BENANCIO BT
CANYON
RICHARDSON LM RODEO RQ
GROVE SAN BENITO BG
ROHNERT PARK RK
RICHARDSON FB SAN BRUNO RD
SPRINGS ROHNERT PARK RK
(SOUTH) SAN CARLOS SC
RICHFIELD WF
ROHNERVILLE LF SAN FRANCISCO RG
RICHMOND JT
ROLINDA TK SAN GERONIMO GM
RICHVALE IR
ROSEDALE TC SAN GREGORIO VQ
RIDGECREST TD
ROSEVILLE HS SAN JOAQUIN SJ
RIEGO HP
ROSEVILLE HS SAN JOSE VP
RIO BRAVO TC
ROSS RS SAN JOSE VP
RIO DELL NR
ROUGH & READY IW SAN JOSE VP
RIO DELL NR
ROUND MOUNTAIN UB SAN JUAN BAUTISTA B1
RIO DELL JX
RUMSEY 7P SAN JUAN BAUTISTA B1
RIO DELL JX
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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SAN LEANDRO SO SANTA YNEZ 3B SHEEP RANCH XS
SAN LORENZO SZ SARATOGA SG SHELL BEACH PW
SAN LUCAS AX SARATOGA SG SHERIDAN SH
SAN LUIS OBISPO BV SARATOGA SG SHERMAN ISLAND PP
SAN MARTIN UA SAUSALITO NS SHINGLE SPRINGS HZ
SAN MATEO SM SAWMILL FLAT XR SHINGLETOWN WQ
SAN MIGUEL KP SCHELLVILLE NV SHIVELY LF
SAN PABLO SB SCIOTS CAMP HT SIEGLER SPRINGS ZH
SAN QUENTIN QU SCOTIA JU SIERRA CITY IG
SAN RAFAEL NQ SCOTTS VALLEY SY SIERRA CITY HM
SAN RAMON SN SEACLIFF AP SIERRA VILLAGE UW
SAN SIMEON SP SEA RANCH P5 SILVER FORK HT
SAND CITY EW SEASIDE SS SISQUOC B3
SANGER SR SEAVIEW NG SITES PX
SANGER SR SEBASTOPOL SE SKAGGS SPRINGS NC
SANGER SR SEBASTOPOL SE SKY LONDA LH
SANTA BARBARA 5B SELBY JT SLOUGHHOUSE QQ
SANTA CLARA SA SELMA TT SLY PARK HT
SANTA CLARA SA SEQUOIA TJ SMARTVILLE SV
SANTA CRUZ VT SEVILLE VE SMARTVILLE SV
SANTA MARGARITA WZ SHAFTER TE SMITH CAMP FF
SANTA MARGARITA WZ SHANDON WY SNELLING SX
SANTA MARIA BX SHASTA W2 SO BEIRIDGE TV
SANTA NELLA GU SHASTA LAKE VE SODA SPRINGS H8
SANTA RITA PARK TM SHASTA LAKE CITY VE SOLEDAD SL
SANTA ROSA NR SHAVER LAKE SK SOLEDAD SL
SANTA VENTIA NQ SHAWS FLAT XR SOLVANG 1B
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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SOMERSET IC STONE CORRAL WJ SYCAMORE PX
SOMES BAR L6 STONE LAGOON LF TAFT TV
SONOMA NV STONYFORD 9S TAFT TV
SONOMA NV STORRIE F7 TAFT (SOUTH) TV
SONORA XR STOUT XR TAFT HEIGHTS TV
SOQUEL SQ STRATFORD RX TALMAGE UO
SOULSBYVILLE YR STRAWBERRY HT TAMARACK XA
SOUTH FORK TQ STRAWBERRY X1 TAMARACK PINES HT
SOUTH SAN RJ STRAWBERRY POINT NQ TAYLORSVILLE EZ
FRANCISCO
STRAWBERRY IS TEHACHAPI 2T
SPANISH FLAT N7 VALLEY
TEHAMA YT
SPANISH RANCH EX SUGAR PINE TQ
TEMPLETON BR
SPRECKELS SF SUGAR PINE UW
TEPUSQUET BX
SPRINGVILLE VU SUISUN FS
TERMINOUS XF
SPRUCE POINT LF SUISUN FS
TERRA LINDA NQ
SQUAW VALLEY VY SULTANA UL
THERMALITO FQ
SAINT HELENA NW SUMMERHOME PARK NR
THORNTON TW
STANDARD YR SUMMIT CITY FY
THREE ROCKS KK
STANFORD ST SUNNYBRAE LF
UNIVERSITY TIBURON OT
SUNNYVALE VB
STENT XR TIERRA BUENA HP
SUNOL SU
STEVINSON SI TIVY VALLEY SR
SUTTER SD
STEWARTS POINT P6 TOADTOWN FM
SUTTER SD
STINSON BEACH BH TOBIN F8
SUTTER CREEK QI
STIRLING CITY F2 TOCOLOMA LU
SUTTER HILL XD
STOCKTON XT TODD VALLEY GE
SUTTER ISLAND PP
STOCKTON XT TOLLHOUSE T1
SWAINS FLAT LF
STOCKTON XT TOMALES N1
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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TRACY XV VALLECITO XZ WASHINGTON II
TRANQUILLITY TI VALLEJO NY WATERFORD WT
TRAVER TZ VALLEJO NY WATERLOO XT
TRAVIS AFB EE VALLEY ACRES VA WATSONVILLE VX
TRES PINOS 6B VALLEY FORD BB WATSONVILLE VX
TRIMMER TK VALLEY HOME XN WAUKENA WG
TRINIDAD TB VALLEY SPRINGS VS WAWONA C6
TRONA TO VALLEY SPRINGS VS WEIMAR HF
TRONA (SOUTH) TO VAN ARSDALE VM WEIMAR H9
TUDOR HP VANDENBURG AFB 2B WEITCHPEC L7
TULARE TY VERNALIS X3 WEOTT JZ
TUOLUMNE YX VERONA HP WEST POINT QY
TUPMAN TA VICHY SPRINGS NX WEST SACRAMENTO WS
TURLOCK XX VICTOR VC WESTEND TD
TUTTLETOWN XR VICTORVILLE C5 WESTHAVEN LF
TWAIN Y6 VILLA GRANDE N9 WESTLEY X9
TWAIN HARTE YV VINA IA WESTPORT QW
TWIN BRIDGES IE VINEBURG 8N WESTWOOD Q7
TWITCHELL ISLAND PP VIRGILIA FP WHEATLAND WE
TWO ROCK NN VISALIA VI WHEELER RIDGE TV
TYLER HH VOLCANO QN WHISKEYTOWN WB
TYLER ISLAND PP VOLTA TM WHISPERING PINE ZH
UKIAH NX WALLACE WL WHITE HALL NN
UNION CITY UC WALNUT CREEK WC WHITE PINES XW
UPPER LAKE ZU WALNUT GROVE WV WHITETHORN G3
VACATION BEACH NG WALNUT GROVE WV WHITMORE W3
VACAVILLE PK WASCO TX WHITTAKER FOREST TJ
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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WILDWOOD 8W WINTON WN YOLO YO
WILLIAMS DV WISHON WU YORKVILLE UP
WILLITS NZ WITTER SPRINGS ZW YOSEMITE YX
WILLOW CREEK LW WONDER VALLEY SR YOSEMITE (WEST) T2
WILLOW SPRINGS XD WOODACRE WA YOUNTVILLE YN
WILLOW SPRINGS YR WOODBRIDGE WR YUBA CITY YC
WILLOWS 9W WOODEN VALLEY NL YUBA GAP HB
WILLOWS 9W WOODLAKE WJ YUBA GAP H5
WILSEYVILLE QZ WOODLAND PZ ZACA LAKE 3B
WILSONIA TJ WOODLEAF FQ ZAMORA PZ
WINDSOR WI WOODSIDE WD ZENIA G8
WINDSOR WI WYANDOTTE FQ
WINTERS 7W YANKEE HILL FM
WINTERS 7W YETTEM YE
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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APPENDIX B
SERVICE CITY ZIP CODES
City Zip Code ANDERSON 96007 ARROYO GRANDE 93401
ACAMPO 95220 ANGELS CAMP 95221 ARROYO GRANDE 93420
AHWAHNEE 93601 ANGELS CAMP 95222 ARROYO GRANDE 93421
AHWAHNEE 93601 ANGWIN 94508 ARROYO GRANDE 93444
ALAMEDA 94501 ANNAPOLIS 95412 ARROYO GRANDE 93445
ALAMEDA 94502 ANTELOPE 95843 ARTOIS 95913
ALAMO 94507 ANTIOCH 90212 ARTOIS 95913
ALBANY 94706 ANTIOCH 90406 ARVIN 93203
ALBANY 94707 ANTIOCH 92626 ATASCADERO 93422
ALBANY 94710 ANTIOCH 92806 ATASCADERO 93423
ALBION 95410 ANTIOCH 94507 ATASCADERO 93442
ALDERPOINT 95511 ANTIOCH 94509 ATASCADERO 93446
ALLEGHANY 95910 ANTIOCH 94509 ATHERTON 94027
ALLENSWORTH 93201 ANTIOCH 94523 ATWATER 95301
ALLENSWORTH 93219 ANTIOCH 94531 AUBERRY 93602
ALLENSWORTH 93219 ANTIOCH 94566 AUBURN 95602
ALMANOR 95947 ANTIOCH 97478 AUBURN 95602
ALPAUGH 93201 APPLEGATE 95703 AUBURN 95603
ALTA 95701 APTOS 95001 AUBURN 95603
ALTAVILLE 95221 APTOS 95003 AUBURN 95603
ALTON 95540 ARBUCKLE 95912 AUBURN 95604
ALVISO 95002 ARBUCKLE 95932 AVENAL 93204
AMADOR CITY 95601 ARCATA 95518 AVENAL 93204
AMBOY 92304 ARCATA 95519 AVERY 95224
AMERICAN CANYON 94503 ARCATA 95521 AVILA BEACH 93424
AMERICAN CANYON 94503 ARNOLD 95223 AVILA BEACH 93449
AMERICAN CANYON 94588 ARNOLD 95223 BADGER 93603
AMERICAN CANYON 94590 AROMAS 95004 BADGER 93603
ANDERSON 96007 AROMAS 95004 BAKERSFIELD 90404
BAKERSFIELD 90503 BEAR VALLEY 95223 BRADLEY 93426
BAKERSFIELD 91210 BEAR VALLEY 95223 BRADLEY 93426
BAKERSFIELD 92658 BELDEN 95915 BRADLEY 93426
BAKERSFIELD 92887 BELLA VISTA 96008 BRANSCOMB 95417
BAKERSFIELD 93203 BELMONT 94002 BRENTWOOD 94513
BAKERSFIELD 93206 BELMONT 94002 BRENTWOOD 94513
BAKERSFIELD 93220 BELVEDERE 94920 BRENTWOOD 94513
BAKERSFIELD 93280 BEN LOMOND 95005 BRENTWOOD 94513
BAKERSFIELD 93301 BENICIA 94510 BRENTWOOD 94513
BAKERSFIELD 93302 BENICIA 94553 BRENTWOOD 94514
BAKERSFIELD 93303 BERKELEY 94618 BRENTWOOD 94561
BAKERSFIELD 93303 BERKELEY 94701 BRENTWOOD 94566
BAKERSFIELD 93304 BERKELEY 94702 BRENTWOOD 94588
BAKERSFIELD 93305 BERKELEY 94703 BRIDGEVILLE 95526
BAKERSFIELD 93306 BERKELEY 94704 BRIDGEVILLE 95526
BAKERSFIELD 93307 BERKELEY 94704 BRISBANE 94005
BAKERSFIELD 93308 BERKELEY 94705 BROOKDALE 95007
BAKERSFIELD 93309 BERKELEY 94706 BROOKS 95606
BAKERSFIELD 93309 BERKELEY 94707 BROWNS VALLEY 95918
BAKERSFIELD 93311 BERKELEY 94707 BROWNSVILLE 95919
BAKERSFIELD 93312 BERKELEY 94708 BRUSH CREEK 95916
BAKERSFIELD 93313 BERKELEY 94708 BUELLTON 93101
BAKERSFIELD 93314 BERKELEY 94709 BUELLTON 93427
BAKERSFIELD 93380 BERKELEY 94710 BURLINGAME 94010
BAKERSFIELD 93381 BERKELEY 94720 BURLINGAME 94011
BAKERSFIELD 93383 BERRY CREEK 95916 BURNEY 96013
BAKERSFIELD 93384 BETHEL ISLAND 94511 BURNEY 96130
BAKERSFIELD 93387 BETHEL ISLAND 94513 BURNT RANCH 95527
BAKERSFIELD 93388 BIEBER 96009 BURNT RANCH 95546
BAKERSFIELD 93389 BIEBER 96130 BURREL 93607
BAKERSFIELD 93390 BIG BEND 96011 BURSON 95225
BALLARD 93463 BIG SUR 93920 BURSON 95225
BALLICO 95303 BIGGS 95917 BUTTE CITY 95920
BANGOR 95914 BIOLA 93606 BUTTE CITY 95920
BANGOR 95914 BIRDS LANDING 94512 BUTTE MEADOWS 95942
BANTA 95304 BLOCKSBURG 95514 BUTTONWILLOW 93206
BASS LAKE 93604 BLUE LAKE 95524 BUTTONWILLOW 93260
BASS LAKE 93669 BLUE LAKE 95525 BYRON 92626
BAXTER 95701 BODEGA 94922 BYRON 94513
BAXTER 95722 BODEGA BAY 94923 BYRON 94514
BAY POINT 94565 BOLINAS 94924 BYRON 94514
BAYSIDE 95524 BOONVILLE 95415 BYRON 94514
BEALE AFB 95903 BORON 93516 BYRON 94514
BEAR VALLEY 95222 BORON 93516 CALIFORNIA VALLEY 93453
BEAR VALLEY 95222 BOULDER CREEK 95006 CALIFORNIA VALLEY 93453
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CALISTOGA 94515 CATHEYS VALLEY 95306 COALINGA 93210
CALISTOGA 94515 CATHEYS VALLEY 95338 COALINGA 93210
CALPELLA 95418 CAYUCOS 93430 COARSEGOLD 93614
CAMBRIA 93428 CAZADERO 95421 COBB 95426
CAMERON PARK 95682 CEDAR RIDGE 95924 COHASSET 95973
CAMINO 95709 CERES 95307 COLFAX 95713
CAMP CONNELL 95223 CERES 95351 COLFAX 95736
CAMP MEEKER 95419 CHALLENGE 95925 COLLEGE CITY 95912
CAMPBELL 95008 CHALLENGE 95925 COLMA 94014
CAMPBELL 95008 CHESTER 96020 COLMA 94015
CAMPBELL 95008 CHICO 95926 COLOMA 95613
CAMPBELL 95008 CHICO 95927 COLUMBIA 95310
CAMPBELL 95009 CHICO 95928 COLUSA 95932
CAMPBELL 95009 CHICO 95929 COMPTCHE 95427
CAMPBELL 95009 CHICO 95973 CONCORD 94518
CAMPO SECO 95226 CHICO 95973 CONCORD 94519
CAMPTONVILLE 95922 CHINESE CAMP 95309 CONCORD 94520
CAMPTONVILLE 95922 CHOLAME 93431 CONCORD 94520
CANTUA CREEK 93608 CHOLAME 93461 CONCORD 94521
CANYON 94516 CHOWCHILLA 93610 CONCORD 94522
CANYON DAM 95923 CHOWCHILLA 93610 CONCORD 94523
CAPAY 95607 CHUALAR 93925 CONCORD 94524
CAPAY 95607 CITRUS HEIGHTS 95610 COOL 95614
CAPITOLA 95010 CITRUS HEIGHTS 95621 COPPEROPOLIS 95228
CARLOTTA 95528 CLARKSBURG 95612 CORCORAN 93212
CARMEL 93921 CLAYTON 94517 CORCORAN 93212
CARMEL 93922 CLAYTON 94566 CORCORAN 93212
CARMEL 93923 CLEARLAKE 95422 CORCORAN 93221
CARMEL 93924 CLEARLAKE OAKS 95423 CORCORAN 93230
CARMEL VALLEY 93924 CLEARLAKE PARK 95424 CORNING 96021
CARMICHAEL 95608 CLEMENTS 95220 CORNING 96021
CARMICHAEL 95609 CLEMENTS 95227 CORNING 96022
CARRISA PLAINS 93276 CLIPPER MILLS 95930 CORTE MADERA 94925
CARRISA PLAINS 93453 CLOVERDALE 95425 CORTE MADERA 94948
CARRISA PLAINS 93453 CLOVERDALE 95425 CORTE MADERA 94976
CARUTHERS 93609 CLOVIS 93611 COSTA MESA 92626
CASMALIA 93429 CLOVIS 93612 COTATI 94928
CASPAR 95420 CLOVIS 93613 COTATI 94931
CASSEL 96016 CLOVIS 93619 COTTONWOOD 96022
CASTRO VALLEY 94541 CLOVIS 93706 COTTONWOOD 96022
CASTRO VALLEY 94544 CLOVIS 93720 COULTERVILLE 95311
CASTRO VALLEY 94546 CLOVIS 93725 COULTERVILLE 95311
CASTRO VALLEY 94546 CLOVIS 95834 COURTLAND 95615
CASTRO VALLEY 94552 CLYDE 94520 COVELO 95428
CASTROVILLE 95012 COALINGA 93210 COYOTE 95013
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CRESCENT CITY 95531 DINUBA 93618 EL SOBRANTE 94803
CRESCENT MILLS 95934 DINUBA 93618 EL SOBRANTE 94806
CRESSEY 95312 DINUBA 93662 ELK 95432
CRESTON 93432 DISCOVERY BAY 94514 ELK CREEK 95939
CROCKETT 94525 DIXON 95615 ELK GROVE 95624
CROWS LANDING 95313 DIXON 95620 ELK GROVE 95757
CUMMINGS 95585 DIXON 95620 ELK GROVE 95758
CUPERTINO 95014 DIXON 95662 ELK GROVE 95828
CUPERTINO 95015 DIXON 95694 ELK GROVE 95829
CUPERTNIO 95014 DOBBINS 95935 ELMIRA 95625
CUTLER 93615 DOBBINS 95962 ELVERTA 95626
CUTTEN 95534 DORRINGTON 95223 ELVERTA 95626
CUYAMA 93252 DOS PALOS 93620 ELVERTA 95626
CUYAMA 93254 DOS PALOS 93620 EMERALD HILLS 94062
DAGGETT 92327 DOS PALOS 95340 EMERYVILLE 94601
DALY CITY 94014 DOS RIOS 95429 EMERYVILLE 94608
DALY CITY 94015 DOUGLAS FLAT 95229 EMIGRANT GAP 95715
DANVILLE 94005 DOWNIEVILLE 95936 EMIGRANT GAP 95715
DANVILLE 94506 DRYTOWN 95699 EMPIRE 95319
DANVILLE 94526 DUBLIN 94566 ESCALON 95320
DANVILLE 94526 DUBLIN 94568 ESPARTO 95607
DANVILLE 94526 DUBLIN 94568 ESPARTO 95627
DANVILLE 94526 DUBLIN 94568 EUREKA 90274
DAVENPORT 95017 DUBLIN 94568 EUREKA 95501
DAVIS 91789 DUNCANS MILLS 95430 EUREKA 95502
DAVIS 95616 DUNLAP 93621 EUREKA 95503
DAVIS 95616 DUNNIGAN 95937 EUREKA 95521
DAVIS 95617 DURHAM 95926 EUREKA 98101
DEER PARK 94576 DURHAM 95938 FAIR OAKS 95628
DEL REY 93616 DUSTIN ACRES 93268 FAIRFAX 94930
DEL REY 93657 DUTCH FLAT 95714 FAIRFIELD 94533
DELEVAN 95988 EARLIMART 93219 FAIRFIELD 94534
DELHI 95315 EAST NICOLAUS 95659 FAIRFIELD 94534
DENAIR 95316 EAST PALO ALTO 94303 FAIRFIELD 94535
DENAIR 95316 EAST PALO ALTO 94303 FAIRFIELD 94585
DERBY ACRES 93224 EDISON 93220 FAIRFIELD 95687
DERBY ACRES 93268 EDWARDS 93523 FALL RIVER MILLS 96028
DIABLO 94520 EL CERRITO 94530 FALLON 94952
DIABLO 94526 EL DORADO 95623 FARMINGTON 95230
DIABLO 94528 EL DORADO HILLS 95762 FARMINGTON 95230
DIAMOND SPRINGS 95619 EL DORADO HILLS 95762 FEATHER FALLS 95940
DIAMOND SPRINGS 95675 EL GRANADA 94018 FELLOWS 93224
DILLON BEACH 94929 EL MACERO 95618 FELTON 95018
DILLON BEACH 94929 EL NIDO 95317 FERNBRIDGE 95540
DINUBA 93271 EL PORTAL 95318 FERNDALE 95536
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FIDDLETOWN 95629 FRESNO 93657 GEYSERVILLE 95441
FIDDLETOWN 95629 FRESNO 93668 GILROY 95020
FIELDBROOK 95519 FRESNO 93701 GILROY 95021
FIELDBROOK 95521 FRESNO 93702 GLEN ELLEN 95442
FIELDBROOK 95525 FRESNO 93703 GLENCOE 95232
FIELDS LANDING 95537 FRESNO 93704 GLENHAVEN 95443
FINLEY 95435 FRESNO 93705 GLENN 95943
FIREBAUGH 93622 FRESNO 93706 GOLD RIVER 95670
FIREBAUGH 93622 FRESNO 93710 GOLD RUN 95717
FIREBAUGH 93622 FRESNO 93710 GONZALES 93926
FISH CAMP 93623 FRESNO 93711 GOODYEARS BAR 95944
FISH CAMP 93623 FRESNO 93720 GRANITE BAY 95746
FIVE POINTS 93624 FRESNO 93721 GRASS VALLEY 95945
FLOURNOY 96029 FRESNO 93722 GRASS VALLEY 95949
FOLSOM 95630 FRESNO 93722 GRASS VALLEY 95959
FOLSOM 95630 FRESNO 93725 GRASS VALLEY 95960
FOLSOM 95763 FRESNO 93726 GRATON 95444
FORBESTOWN 95941 FRESNO 93726 GRAYSON 95360
FORBESTOWN 95941 FRESNO 93727 GRAYSON 95363
FOREST GLEN 96041 FRESNO 93727 GRAYSON 95387
FOREST KNOLLS 94933 FRESNO 93728 GREENBRAE 94904
FOREST RANCH 95942 FRESNO 93729 GREENFIELD 93927
FORESTHILL 95631 FRESNO 93740 GREENVILLE 95947
FORESTVILLE 95436 FRESNO 93760 GREENWOOD 95635
FORT BRAGG 95437 FRESNO 93776 GRIDLEY 95948
FORT BRAGG 95456 FRESNO 93778 GRIMES 95950
FORT SEWARD 95542 FRESNO 93778 GRIZZLY FLATS 95636
FORTUNA 95540 FRESNO 93792 GRIZZLY FLATS 95684
FOSTER CITY 94403 FRESNO 95816 GROVELAND 95321
FOSTER CITY 94404 FRIANT 93626 GROVELAND 95321
FOWLER 93625 FRIANT 93626 GROVER BEACH 93433
FREEDOM 95019 FRIANT 93626 GROVER BEACH 93483
FREMONT 94536 FULTON 95439 GUADALUPE 93434
FREMONT 94537 GALT 95632 GUADALUPE 93434
FREMONT 94538 GALT 95632 GUALALA 95445
FREMONT 94538 GALT 95632 GUERNEVILLE 95446
FREMONT 94539 GARBERVILLE 95501 GUERNEVILLE 95471
FREMONT 94555 GARBERVILLE 95542 GUINDA 95637
FREMONT 94583 GARBERVILLE 95542 GUSTINE 95322
FRENCH CAMP 95231 GARBERVILLE 96127 GUSTINE 95322
FRENCH CAMP 95336 GARDEN VALLEY 95633 HALCYON 93420
FRENCH GULCH 96033 GEORGETOWN 95634 HALF MOON BAY 94019
FRESNO 90707 GEORGETOWN 95634 HAMILTON CITY 95951
FRESNO 93612 GERBER 96035 HANFORD 93230
FRESNO 93650 GEYSERVILLE 92081 HANFORD 93232
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HARMONY 93435 INYOKERN 93527 LA GRANGE 95329
HAT CREEK 96040 INYOKERN 93555 LA GRANGE 95329
HATHAWAY PINES 95233 IONE 95640 LA GRANGE 95329
HAWKINS BAR 95527 IRVINE 92612 LA HONDA 94020
HAWKINS BAR 95563 ISLETON 95641 LA HONDA 94020
HAYWARD 94540 JACKSON 92629 LA PORTE 95981
HAYWARD 94541 JACKSON 95642 LA SELVA BEACH 95076
HAYWARD 94542 JACKSON 95647 LAFAYETTE 94549
HAYWARD 94542 JACKSON 99210 LAGUNITAS 94938
HAYWARD 94543 JAMESTOWN 95327 LAKE ALMANOR 96020
HAYWARD 94544 JENNER 95450 LAKE ALMANOR 96137
HAYWARD 94544 JOHNSON PARK 96013 LAKE ALMANOR 96137
HAYWARD 94544 JOLON 93928 LAKE BERRYESSA 94558
HAYWARD 94545 KEDDIE 95971 LAKEHEAD 96051
HAYWARD 94545 KELSEY 95667 LAKEPORT 90267
HAYWARD 94545 KELSEYVILLE 95451 LAKEPORT 95453
HAYWARD 94546 KENSINGTON 94706 LAMONT 93241
HAYWARD 94552 KENSINGTON 94707 LARKSPUR 94904
HAYWARD 96064 KENSINGTON 94707 LARKSPUR 94939
HEALDSBURG 95448 KENSINGTON 94708 LARKSPUR 94977
HELM 93627 KENTFIELD 94901 LATHROP 95330
HERCULES 94547 KENTFIELD 94904 LATON 93242
HICKMAN 95323 KENWOOD 95409 LATON 93242
HIDDEN VALLEY LAKE 95467 KENWOOD 95452 LAYTONVILLE 95417
HILLSBOROUGH 94010 KERMAN 93630 LAYTONVILLE 95454
HILMAR 95324 KERMAN 93631 LAYTONVILLE 95490
HOLLISTER 95023 KETTLEMAN CITY 93234 LE GRAND 95333
HOLLISTER 95023 KETTLEMAN CITY 93239 LEBEC 93243
HOLLISTER 95024 KEYES 95328 LEBEC 93243
HOLT 95234 KING CITY 93930 LEGGETT 95585
HONEYDEW 95545 KING CITY 93930 LEMOORE 93245
HOOPA 95546 KING CITY 93930 LEMOORE 93656
HOOPA 95547 KINGS CANYON 93633 LINCOLN 95648
HOOPA 95573 KINGS CANYON 93633 LINCOLN 95648
HOPLAND 95449 KINGSBURG 93631 LINDEN 95236
HORNITOS 95325 KINGSBURG 93631 LINDEN 95236
HUGHSON 95326 KINGSBURG 93631 LITTLE NORWAY 95721
HUME 93628 KNEELAND 95549 LITTLE NORWAY 95735
HURON 93210 KNIGHTS FERRY 95361 LITTLE RIVER 95456
HURON 93234 KNIGHTS LANDING 95645 LITTLE VALLEY 96056
HURON 93245 KNIGHTS LANDING 95645 LIVE OAK 95816
HYDESVILLE 95547 KNIGHTS LANDING 95645 LIVE OAK 95953
IGO 96047 KNIGHTSEN 94548 LIVERMORE 92660
INVERNESS 94937 KORBEL 95550 LIVERMORE 94513
INYOKERN 93526 KYBURZ 95720 LIVERMORE 94550
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LIVERMORE 94550 LOS OSOS 93402 MCARTHUR 96056
LIVERMORE 94550 LOS OSOS 93405 MCARTHUR 96056
LIVERMORE 94551 LOS OSOS 93412 MCCLELLAN 95652
LIVERMORE 94551 LOST HILLS 93249 MCKINLEYVILLE 95519
LIVERMORE 94551 LOTUS 95651 MCKINLEYVILLE 95521
LIVERMORE 94551 LOWER LAKE 95457 MEADOW VALLEY 95656
LIVERMORE 94551 LUCERNE 95458 MEADOW VALLEY 95956
LIVERMORE 94588 LUCERNE VALLEY 92356 MEADOW VALLEY 95971
LIVINGSTON 95334 MAD RIVER 95552 MEADOW VISTA 95722
LOCH LOMOND 95426 MAD RIVER 95552 MENDOCINO 95460
LOCH LOMOND 95461 MADERA 93637 MENDOTA 93640
LOCKEFORD 95237 MADERA 93638 MENLO PARK 94025
LOCKWOOD 93932 MADERA 93638 MENLO PARK 94027
LODI 95240 MADERA 93639 MENLO PARK 94028
LODI 95241 MADISON 95653 MERCED 95329
LODI 95242 MAGALIA 95954 MERCED 95340
LOLETA 95551 MANCHESTER 95459 MERCED 95341
LOMA MAR 94021 MANTECA 95336 MERCED 95344
LOMPOC 93436 MANTECA 95337 MERCED 95348
LOMPOC 93437 MANTECA 95366 MERIDIAN 95957
LOMPOC 93438 MANTON 96059 MERIDIAN 95957
LONG BARN 95335 MANTON 96059 METTLER STATION 93301
LOOMIS 95650 MARICOPA 93252 METTLER STATION 93313
LOS ALAMOS 93440 MARICOPA 93252 MI WUK VILLAGE 95346
LOS ALAMOS 93441 MARINA 93933 MIDDLETOWN 95461
LOS ALTOS 94022 MARIPOSA 95338 MIDDLETOWN 95461
LOS ALTOS 94022 MARIPOSA 95338 MIDDLETOWN 95467
LOS ALTOS 94024 MARKLEEVILLE 96120 MIDPINES 95345
LOS ALTOS HILLS 94022 MARSHALL 94940 MILL CREEK 96061
LOS ALTOS HILLS 94024 MARTELL 95642 MILL VALLEY 94941
LOS BANOS 93635 MARTELL 95654 MILL VALLEY 94941
LOS BANOS 93635 MARTINEZ 94553 MILL VALLEY 94942
LOS GATOS 95030 MARTINEZ 94553 MILLBRAE 94030
LOS GATOS 95030 MARYSVILLE 95661 MILLVILLE 96062
LOS GATOS 95030 MARYSVILLE 95901 MILPITAS 94583
LOS GATOS 95031 MARYSVILLE 95901 MILPITAS 94583
LOS GATOS 95032 MARYSVILLE 95903 MILPITAS 95035
LOS GATOS 95032 MARYSVILLE 95991 MILPITAS 95035
LOS GATOS 95032 MARYSVILLE 95992 MILPITAS 95036
LOS GATOS 95033 MAXWELL 95955 MINERAL 96061
LOS GATOS 95033 MC ARTHUR 96056 MINERAL 96063
LOS GATOS 95033 MC FARLAND 93205 MIRAMONTE 93641
LOS MOLINOS 96055 MC FARLAND 93250 MIRANDA 95553
LOS OLIVOS 93441 MC FARLAND 93350 MODESTO 95350
LOS OSOS 93401 MC KITTRICK 93251 MODESTO 95351
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MODESTO 95352 NAPA 94558 OAKDALE 95361
MODESTO 95353 NAPA 94558 OAKHURST 93644
MODESTO 95354 NAPA 94559 OAKHURST 95389
MODESTO 95355 NAVARRO 95463 OAKLAND 94601
MODESTO 95355 NELSON 95958 OAKLAND 94602
MODESTO 95356 NEVADA CITY 95949 OAKLAND 94603
MODESTO 95357 NEVADA CITY 95959 OAKLAND 94604
MODESTO 95358 NEW CUYAMA 93254 OAKLAND 94605
MOJAVE 93502 NEWARK 94538 OAKLAND 94606
MOKELUMNE HILL 95245 NEWARK 94560 OAKLAND 94607
MONTARA 94037 NEWARK 94560 OAKLAND 94607
MONTE RIO 95462 NEWBERRY SPRINGS 92365 OAKLAND 94608
MONTE SERENO 95030 NEWCASTLE 95658 OAKLAND 94609
MONTEREY 93924 NEWMAN 95350 OAKLAND 94610
MONTEREY 93940 NEWMAN 95360 OAKLAND 94611
MONTEREY 93942 NEWMAN 95360 OAKLAND 94612
MONTEREY 93944 NICASIO 94946 OAKLAND 94612
MONTGOMERY NICE 95464 OAKLAND 94613
CREEK 96001 NICOLAUS 95659 OAKLAND 94614
MONTGOMERY NIPOMO 93420 OAKLAND 94615
CREEK 96065
NIPOMO 93444 OAKLAND 94618
MONTGOMERY
CREEK 96084 NIPOMO 93444 OAKLAND 94619
MORAGA 94556 NIPOMO 93454 OAKLAND 94621
MORGAN HILL 95037 NORDEN 95724 OAKLAND 94623
MORGAN HILL 95038 NORDEN 95724 OAKLAND 94623
MORRO BAY 93442 NORTH EDWARDS 93523 OAKLAND 94623
MORRO BAY 93443 NORTH FORK 93643 OAKLAND 94704
MOSS BEACH 94038 NORTH HIGHLANDS 95652 OAKLAND 94705
MOSS LANDING 93950 NORTH HIGHLANDS 95660 OAKLAND 95816
MOSS LANDING 95039 NORTH SAN JUAN 95960 OAKLEY 94513
MOUNT AUKUM 95656 NORTH SAN JUAN 95960 OAKLEY 94561
MOUNT HERMON 95018 NORTH SAN JUAN 95960 OAKVILLE 94562
MOUNT HERMON 95041 NOVATO 94945 OCCIDENTAL 95465
MOUNTAIN HOUSE 95391 NOVATO 94945 OCEANO 93445
MOUNTAIN RANCH 95246 NOVATO 94947 OLD STATION 96071
MOUNTAIN RANCH 95246 NOVATO 94947 OLEMA 94950
MOUNTAIN VIEW 94039 NOVATO 94948 OLIVEHURST 95901
MOUNTAIN VIEW 94040 NOVATO 94949 OLIVEHURST 95918
MOUNTAIN VIEW 94040 NOVATO 94954 OLIVEHURST 95961
MOUNTAIN VIEW 94041 NOVATO 94998 ORANGE COVE 93646
MOUNTAIN VIEW 94043 NUBIEBER 96068 ORANGE COVE 93646
MUIR BEACH 94965 O NEALS 93645 ORANGE COVE 93675
MURPHYS 95247 OAK RUN 96069 ORANGEVALE 95662
MYERS FLAT 95554 OAKDALE 95361 ORANGEVALE 95662
OAKDALE 95361 ORCUTT 93440
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ORCUTT 93454 PENRYN 95663 PLEASANTON 94566
ORCUTT 93455 PESCADERO 94060 PLEASANTON 94568
OREGON HOUSE 95962 PETALUMA 93003 PLEASANTON 94588
ORICK 95555 PETALUMA 94952 PLEASANTON 94588
ORINDA 94523 PETALUMA 94952 PLEASANTON 94588
ORINDA 94563 PETALUMA 94953 PLEASANTON 94588
ORLAND 95963 PETALUMA 94954 PLEASANTON 94588
ORLAND 95963 PETROLIA 95558 PLUMAS LAKE 95961
ORLAND 95963 PHILLIPSVILLE 95559 PLYMOUTH 95669
ORLAND 96130 PHILO 95466 POINT ARENA 95468
ORLEANS 95556 PIEDMONT 94602 POINT REYES 94956
OROSI 93647 PIEDMONT 94610 POINT REYES
OROVILLE 95965 PIEDMONT 94611 STATION 94956
OROVILLE 95966 PIEDMONT 94618 POLLOCK PINES 95726
OROVILLE 95966 PIERCY 95587 POPE VALLEY 94567
PACHECO 94553 PIERCY 95587 PORT COSTA 94569
PACIFIC GROVE 93950 PIKE CITY 95960 PORTOLA VALLEY 94028
PACIFIC HOUSE 95726 PILOT HILL 95664 POTTER VALLEY 95469
PACIFICA 94044 PILOT HILL 95664 PRATHER 93651
PAICINES 95043 PINE GROVE 95665 PRESIDIO 94129
PALERMO 95968 PINE GROVE 95666 PRINCETON 95970
PALO ALTO 94034 PINECREST 95314 PRINCETON 95970
PALO ALTO 94066 PINECREST 95364 PRINCETON 95970
PALO ALTO 94301 PINEDALE 93650 PROBERTA 96078
PALO ALTO 94303 PINEHURST 93641 PULGA 95965
PALO ALTO 94303 PINOLE 94564 QUINCY 95971
PALO ALTO 94304 PINOLE 94803 RACKERBY 95972
PALO ALTO 94304 PIONEER 95666 RAIL ROAD FLAT 95232
PALO ALTO 94305 PISMO BEACH 93448 RAIL ROAD FLAT 95245
PALO ALTO 94306 PISMO BEACH 93449 RAIL ROAD FLAT 95248
PALO CEDRO 96073 PITTSBURG 94553 RAIL ROAD FLAT 95248
PARADISE 95967 PITTSBURG 94565 RAISIN 93652
PARADISE 95969 PLACERVILLE 95667 RAISIN CITY 93652
PARLIER 93648 PLANADA 95365 RANCHO CORDOVA 95655
PARLIER 93727 PLATINA 96076 RANCHO CORDOVA 95670
PASKENTA 96074 PLATINA 96076 RANCHO CORDOVA 95742
PASO ROBLES 93446 PLEASANT GROVE 95668 RAYMOND 93653
PASO ROBLES 93447 PLEASANT GROVE 95668 RAYMOND 93653
PASO ROBLES 93465 PLEASANT HILL 94523 RED BLUFF 96080
PATTERSON 95363 PLEASANTON 94538 RED BLUFF 96080
PAYNES CREEK 96075 PLEASANTON 94566 RED TOP 95340
PEBBLE BEACH 93953 PLEASANTON 94566 REDCREST 95569
PENN VALLEY 95946 PLEASANTON 94566 REDDING 96001
PENN VALLEY 95946 PLEASANTON 94566 REDDING 96002
PENNGROVE 94951 PLEASANTON 94566 REDDING 96003
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REDDING 96049 RIVERBANK 95361 SACRAMENTO 95816
REDDING 96099 RIVERBANK 95363 SACRAMENTO 95816
REDDING 97405 RIVERBANK 95367 SACRAMENTO 95817
REDWAY 95560 RIVERBANK 95367 SACRAMENTO 95818
REDWOOD CITY 94061 RIVERDALE 93656 SACRAMENTO 95818
REDWOOD CITY 94062 RIVERDALE 93656 SACRAMENTO 95819
REDWOOD CITY 94063 ROBBINS 95676 SACRAMENTO 95820
REDWOOD CITY 94063 ROBBINS 95676 SACRAMENTO 95821
REDWOOD CITY 94064 Rocklin 95677 SACRAMENTO 95822
REDWOOD CITY 94065 ROCKLIN 95677 SACRAMENTO 95823
REDWOOD ESTATES 95044 ROCKLIN 95765 SACRAMENTO 95824
REDWOOD ESTATES 95044 ROCKLIN 95775 SACRAMENTO 95825
REDWOOD VALLEY 95470 RODEO 94572 SACRAMENTO 95825
REEDLEY 93654 RODEO 94577 SACRAMENTO 95826
REEDLEY 93654 ROHNERT PARK 94927 SACRAMENTO 95827
REEDLEY 93654 ROHNERT PARK 94928 SACRAMENTO 95828
REEDLEY 99999 ROHNERT PARK 94931 SACRAMENTO 95829
RESCUE 95672 ROSEVILLE 95661 SACRAMENTO 95830
RESCUE 95682 ROSEVILLE 95678 SACRAMENTO 95831
RICHMOND 90221 ROSEVILLE 95678 SACRAMENTO 95832
RICHMOND 94530 ROSEVILLE 95678 SACRAMENTO 95833
RICHMOND 94801 ROSEVILLE 95746 SACRAMENTO 95834
RICHMOND 94802 ROSEVILLE 95747 SACRAMENTO 95834
RICHMOND 94803 ROSEVILLE 95841 SACRAMENTO 95834
RICHMOND 94804 ROSS 94957 SACRAMENTO 95834
RICHMOND 94805 ROUGH AND READY 95975 SACRAMENTO 95834
RICHMOND 94806 ROUND MOUNTAIN 96084 SACRAMENTO 95835
RICHMOND 94806 RUMSEY 95679 SACRAMENTO 95836
RICHMOND 94807 RUTH 95526 SACRAMENTO 95837
RICHMOND 94808 RUTH 95526 SACRAMENTO 95837
RICHMOND 94850 RUTH 95551 SACRAMENTO 95838
RICHVALE 95974 RUTHERFORD 94573 SACRAMENTO 95841
RIDGECREST 93555 RYDE 95680 SACRAMENTO 95842
RIDGECREST 93555 SACRAMENTO 94298 SACRAMENTO 95843
RIO DELL 95562 SACRAMENTO 95628 SACRAMENTO 95864
RIO LINDA 95661 SACRAMENTO 95758 SAINT HELENA 94574
RIO LINDA 95673 SACRAMENTO 95812 SAINT HELENA 94574
RIO NIDO 95471 SACRAMENTO 95814 SALIDA 95368
RIO OSO 95674 SACRAMENTO 95814 SALINAS 93901
RIO VISTA 94520 SACRAMENTO 95815 SALINAS 93902
RIO VISTA 94571 SACRAMENTO 95816 SALINAS 93905
RIO VISTA 94571 SACRAMENTO 95816 SALINAS 93905
RIPON 95366 SACRAMENTO 95816 SALINAS 93906
RIPON 95366 SACRAMENTO 95816 SALINAS 93907
RIVER PINES 95675 SACRAMENTO 95816 SALINAS 93908
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SALINAS 93912 SAN FRANCISCO 94133 SAN JOSE 95129
SALINAS 93915 SAN FRANCISCO 94133 SAN JOSE 95130
SALYER 95563 SAN FRANCISCO 94134 SAN JOSE 95131
SAMOA 95564 SAN FRANCISCO 94143 SAN JOSE 95132
SAN ANDREAS 95249 SAN FRANCISCO 94158 SAN JOSE 95133
SAN ANSELMO 94960 SAN GERONIMO 94963 SAN JOSE 95133
SAN ARDO 93450 SAN GREGORIO 94074 SAN JOSE 95134
SAN BRUNO 94066 SAN JOAQUIN 93660 SAN JOSE 95135
SAN CARLOS 94070 SAN JOSE 94538 SAN JOSE 95136
SAN CARLOS 94070 SAN JOSE 95002 SAN JOSE 95138
SAN CARLOS 94303 SAN JOSE 95008 SAN JOSE 95139
SAN FRANCISCO 94080 SAN JOSE 95013 SAN JOSE 95140
SAN FRANCISCO 94101 SAN JOSE 95035 SAN JOSE 95141
SAN FRANCISCO 94102 SAN JOSE 95037 SAN JOSE 95148
SAN FRANCISCO 94103 SAN JOSE 95101 SAN JOSE 95150
SAN FRANCISCO 94104 SAN JOSE 95102 SAN JOSE 95151
SAN FRANCISCO 94105 SAN JOSE 95110 SAN JOSE 95153
SAN FRANCISCO 94105 SAN JOSE 95110 SAN JOSE 95153
SAN FRANCISCO 94105 SAN JOSE 95110 SAN JOSE 95154
SAN FRANCISCO 94106 SAN JOSE 95111 SAN JOSE 95160
SAN FRANCISCO 94106 SAN JOSE 95112 SAN JOSE 95160
SAN FRANCISCO 94107 SAN JOSE 95113 SAN JOSE 95161
SAN FRANCISCO 94108 SAN JOSE 95113 SAN JOSE 95192
SAN FRANCISCO 94108 SAN JOSE 95116 SAN JUAN BAUTISTA 95045
SAN FRANCISCO 94109 SAN JOSE 95117 SAN LEANDRO 94577
SAN FRANCISCO 94110 SAN JOSE 95118 SAN LEANDRO 94577
SAN FRANCISCO 94111 SAN JOSE 95119 SAN LEANDRO 94578
SAN FRANCISCO 94111 SAN JOSE 95119 SAN LEANDRO 94579
SAN FRANCISCO 94112 SAN JOSE 95119 SAN LEANDRO 94580
SAN FRANCISCO 94114 SAN JOSE 95120 SAN LORENZO 94580
SAN FRANCISCO 94115 SAN JOSE 95121 SAN LUCAS 93930
SAN FRANCISCO 94116 SAN JOSE 95122 SAN LUCAS 93954
SAN FRANCISCO 94117 SAN JOSE 95123 SAN LUIS OBISPO 90071
SAN FRANCISCO 94118 SAN JOSE 95124 SAN LUIS OBISPO 90603
SAN FRANCISCO 94119 SAN JOSE 95124 SAN LUIS OBISPO 93401
SAN FRANCISCO 94121 SAN JOSE 95125 SAN LUIS OBISPO 93402
SAN FRANCISCO 94122 SAN JOSE 95125 SAN LUIS OBISPO 93403
SAN FRANCISCO 94123 SAN JOSE 95125 SAN LUIS OBISPO 93405
SAN FRANCISCO 94123 SAN JOSE 95126 SAN LUIS OBISPO 93406
SAN FRANCISCO 94124 SAN JOSE 95126 SAN LUIS OBISPO 93408
SAN FRANCISCO 94127 SAN JOSE 95126 SAN LUIS OBISPO 93420
SAN FRANCISCO 94128 SAN JOSE 95126 SAN LUIS OBISPO 93433
SAN FRANCISCO 94129 SAN JOSE 95127 SAN LUIS OBISPO 93449
SAN FRANCISCO 94131 SAN JOSE 95128 SAN MARTIN 95046
SAN FRANCISCO 94132 SAN JOSE 95129 SAN MATEO 94025
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
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SAN MATEO 94062 SANTA CLARA 95053 SEBASTOPOL 95401
SAN MATEO 94401 SANTA CLARA 95054 SEBASTOPOL 95472
SAN MATEO 94401 SANTA CRUZ 95060 SEBASTOPOL 95473
SAN MATEO 94402 SANTA CRUZ 95062 SELMA 90720
SAN MATEO 94403 SANTA CRUZ 95062 SELMA 93622
SAN MATEO 94404 SANTA CRUZ 95062 SELMA 93622
SAN MATEO 94404 SANTA CRUZ 95062 SELMA 93657
SAN MATEO 94404 SANTA CRUZ 95064 SELMA 93662
SAN MIGUEL 93446 SANTA CRUZ 95065 SELMA 93706
SAN MIGUEL 93451 SANTA CRUZ 95066 SELMA 93721
SAN MIGUEL 93451 SANTA MARGARITA 93422 SEVILLE 93292
SAN MIGUEL 93451 SANTA MARGARITA 93453 SHAFTER 93263
SAN MIGUEL 93451 SANTA MARIA 92674 SHANDON 93451
SAN PABLO 94806 SANTA MARIA 92693 SHANDON 93461
SAN QUENTIN 94964 SANTA MARIA 93454 SHASTA 96087
SAN RAFAEL 92264 SANTA MARIA 93454 SHASTA LAKE 96003
SAN RAFAEL 94901 SANTA MARIA 93455 SHASTA LAKE 96019
SAN RAFAEL 94901 SANTA MARIA 93456 SHASTA LAKE 96089
SAN RAFAEL 94903 SANTA MARIA 93457 SHAVER LAKE 93602
SAN RAFAEL 94904 SANTA MARIA 93458 SHAVER LAKE 93664
SAN RAFAEL 94912 SANTA NELLA 95322 SHEEP RANCH 95250
SAN RAFAEL 94913 SANTA ROSA 95401 SHELL BEACH 93449
SAN RAFAEL 94915 SANTA ROSA 95402 SHERIDAN 95681
SAN RAFAEL 94915 SANTA ROSA 95403 SHINGLE SPRINGS 95682
SAN RAFAEL 94956 SANTA ROSA 95404 SHINGLE SPRINGS 95682
SAN RAFAEL 95816 SANTA ROSA 95405 SHINGLETOWN 96088
SAN RAMON 94506 SANTA ROSA 95406 SIERRA CITY 96125
SAN RAMON 94582 SANTA ROSA 95407 SISQUOC 93454
SAN RAMON 94583 SANTA ROSA 95407 SISQUOC 93455
SAN RAMON 94583 SANTA ROSA 95409 SITES 95979
SAN RAMON 94583 SANTA ROSA 95492 SMARTVILLE 95977
SAN RAMON 94583 SANTA YNEZ 93460 SMARTVILLE 95977
SAN RAMON 94583 SARATOGA 95070 SNELLING 95369
SAN SIMEON 93452 SARATOGA 95070 SNELLING 95369
SAND CITY 93955 SARATOGA 95071 SODA SPRINGS 95724
SANGER 93657 SAUSALITO 94965 SODA SPRINGS 95724
SANGER 93711 SAUSALITO 94966 SODA SPRINGS 95728
SANTA BARBARA 93101 SCOTIA 95565 SODA SPRINGS 95728
SANTA BARBARA 93103 SCOTTS VALLEY 95060 SOLEDAD 93960
SANTA BARBARA 93105 SCOTTS VALLEY 95065 SOLVANG 93463
SANTA BARBARA 93110 SCOTTS VALLEY 95066 SOLVANG 93464
SANTA CLARA 95050 SEA RANCH 95445 SOMERSET 95684
SANTA CLARA 95050 SEA RANCH 95497 SOMES BAR 95568
SANTA CLARA 95050 SEA RANCH 95497 SONOMA 95476
SANTA CLARA 95051 SEASIDE 93955 SONOMA 95476
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SONORA 92651 STOCKTON 95219 TRACY 92691
SONORA 95370 STOCKTON 95219 TRACY 92707
SONORA 95379 STOCKTON 95234 TRACY 94520
SOQUEL 95073 STOCKTON 95236 TRACY 94550
SOULSBYVILLE 95372 STOCKTON 95240 TRACY 94577
SOUTH DOS PALOS 93665 STOCKTON 95267 TRACY 94588
SOUTH SAN STOCKTON 95336 TRACY 95201
FRANCISCO 94080 STONYFORD 95979 TRACY 95206
SOUTH SAN STONYFORD 95979 TRACY 95304
FRANCISCO 94083
STORRIE 95980 TRACY 95304
SOUTH SAN
FRANCISCO 94112 STRATFORD 93266 TRACY 95304
SPRECKELS 93962 STRAWBERRY 95375 TRACY 95376
STRAWBERRY TRACY 95376
SQUAW VALLEY 93646
VALLEY 95981 TRACY 95376
SQUAW VALLEY 93675
SUISUN 94533 TRACY 95377
STANDARD 95373
SUISUN 94534 TRACY 95377
STANFORD 94305
SUISUN 94585 TRACY 95378
STEVINSON 95374
SUISUN 95685 TRACY 95378
STEWARTS POINT 95480
SUISUN CITY 94534 TRACY 95385
STINSON BEACH 94970
SUISUN CITY 94585 TRACY 95385
STIRLING CITY 95978
SUISUN CITY 94585 TRACY 95391
STOCKTON 90212
SUISUN CITY 94585 TRACY 95391
STOCKTON 90404
SULTANA 93666 TRANQUILLITY 93668
STOCKTON 94545
SUNNYVALE 94085 TRAVER 93673
STOCKTON 95201
SUNNYVALE 94086 TRAVIS AFB 94535
STOCKTON 95202
SUNNYVALE 94087 TRES PINOS 95075
STOCKTON 95202
SUNNYVALE 94088 TRINIDAD 95570
STOCKTON 95203
SUNNYVALE 94089 TRONA 93562
STOCKTON 95204
SUNNYVALE 95014 TULARE 93274
STOCKTON 95204
SUNOL 94586 TUOLUMNE 95379
STOCKTON 95204
SUTTER 95982 TUPMAN 93276
STOCKTON 95205
SUTTER CREEK 95685 TURLOCK 95380
STOCKTON 95206
TAFT 92647 TURLOCK 95380
STOCKTON 95206
TAFT 93268 TURLOCK 95382
STOCKTON 95207
TAFT 93453 TWAIN 95984
STOCKTON 95207
TAYLORSVILLE 95934 TWAIN HARTE 95383
STOCKTON 95208
TAYLORSVILLE 95983 TWIN BRIDGES 95735
STOCKTON 95209
TEHACHAPI 93561 UKIAH 95482
STOCKTON 95209
TEHAMA 96090 UKIAH 95482
STOCKTON 95210
TEMPLETON 93465 UNION CITY 94587
STOCKTON 95211
THORNTON 95686 UNION CITY 94587
STOCKTON 95212
TIBURON 94920 UPPER LAKE 95485
STOCKTON 95213
TOLLHOUSE 93667 UPPER LAKE 95493
STOCKTON 95213
TOMALES 94971 VACAVILLE 95687
STOCKTON 95215
TRACY 92110 VACAVILLE 95688
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VACAVILLE 95696 WALNUT GROVE 95690 WILLOW CREEK 96039
VALLECITO 95229 WASCO 93280 WILLOWS 95988
VALLECITO 95251 WASHINGTON 95986 WILLOWS 95988
VALLEJO 94503 WATERFORD 95386 WILSEYVILLE 95257
VALLEJO 94503 WATSONVILLE 95019 WILSEYVILLE 95257
VALLEJO 94583 WATSONVILLE 95076 WINDSOR 95492
VALLEJO 94589 WATSONVILLE 95076 WINTERS 95694
VALLEJO 94590 WATSONVILLE 95076 WINTERS 95694
Vallejo 94590 WATSONVILLE 95077 WINTERS 95695
VALLEJO 94590 WAUKENA 93274 WINTON 95301
VALLEJO 94591 WAUKENA 93282 WINTON 95388
Vallejo 94591 WAWONA 95389 WISHON 93669
VALLEJO 94592 WEIMAR 95713 WITTER SPRINGS 95493
VALLEY ACRES 93268 WEIMAR 95736 WOODACRE 94973
VALLEY FORD 94972 WEITCHPEC 95546 WOODBRIDGE 95258
VALLEY FORD 94972 WEOTT 95571 WOODBRIDGE 95258
VALLEY HOME 95361 WEST POINT 95255 WOODLAKE 93286
VALLEY SPRINGS 95252 WEST POINT 95255 WOODLAND 95695
VALLEY SPRINGS 95255 WEST POINT 95404 WOODLAND 95695
VERNALIS 95385 WEST SACRAMENTO 95605 WOODLAND 95776
VERNALIS 95385 WEST SACRAMENTO 95691 WOODSIDE 94026
VICTOR 95253 WEST SACRAMENTO 95691 WOODSIDE 94061
VICTORVILLE 92394 West Sacramento 95691 WOODSIDE 94062
VILLA GRANDE 95486 WEST SACRAMENTO 95695 YETTEM 93670
VINA 96092 WEST SACRAMENTO 95695 YOLO 95697
VISALIA 93277 WEST SACRAMENTO 95798 YORKVILLE 95494
VISALIA 93279 WEST SACRAMENTO 95828 YOSEMITE NATIONAL
VISALIA 93291 WEST SACRAMENTO 95961 PARK 95389
VISALIA 93292 WESTLEY 95387 YOSEMITE NATIONAL
PARK 95389
VOLCANO 95689 WESTPORT 95488
YOUNTVILLE 94599
WALLACE 95254 WESTWOOD 96137
YUBA CITY 95661
WALNUT CREEK 94595 WESTWOOD 96137
YUBA CITY 95901
WALNUT CREEK 94595 WHEATLAND 95692
YUBA CITY 95991
WALNUT CREEK 94596 WHEATLAND 95692
YUBA CITY 95992
WALNUT CREEK 94596 WHISKEYTOWN 96095
YUBA CITY 95993
WALNUT CREEK 94597 WHITE PINES 95223
YUBA CITY 95994
WALNUT CREEK 94597 WHITETHORN 95589
ZAMORA 95698
WALNUT CREEK 94597 WHITETHORN 95589
ZENIA 95595
WALNUT CREEK 94598 WHITMORE 96096
WALNUT CREEK 94598 WILDWOOD 96076
WALNUT GROVE 95690 WILLIAMS 95987
WALNUT GROVE 95690 WILLITS 95490
WALNUT GROVE 95690 WILLOW CREEK 95573
Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only
10/5/05 Page 132
APPENDIX 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
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