The Electric ESP Handbook - PG&E, Pacific Gas and ElectricThe Electric ESP Handbook A GUIDE TO PACIFIC GAS &ELECTRIC COMPANY’S DIRECT ACCESS PROCEDURES FOR ELECTRIC ENERGY SERVICE

The Electric ESP Handbook

A GUIDE TO PACIFIC GAS &ELECTRIC COMPANY’S DIRECT ACCESS PROCEDURES FOR ELECTRIC ENERGY SERVICE PROVIDERS

Pacific Gas and Electric Company - ESP Services

February 25, 2009

Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only Page ii

TABLE OF CONTENTS

PREFACE ............................................................................................................................................................................... 1 ABOUT THIS GUIDE............................................................................................................................................................... 1

Overview........................................................................................................................................................................... 1 Disclaimer and Warning .................................................................................................................................................. 1 Summary of Chapters and Contents ................................................................................................................................. 2 Chapter Organization....................................................................................................................................................... 2

Overview .......................................................................................................................................................................................... 2 Prerequisites ..................................................................................................................................................................................... 3 Checklist of Key Steps ..................................................................................................................................................................... 3 The [Chapter Topic] Process Illustrated ........................................................................................................................................... 3 Procedures ........................................................................................................................................................................................ 3

CHAPTER 1 ........................................................................................................................................................................... 1 ELECTRIC ESP DIRECT ACCESS PRELIMINARY PROCEDURES................................................................................................ 1

Overview........................................................................................................................................................................... 1 Prerequisites..................................................................................................................................................................... 1 Checklist of key steps ........................................................................................................................................................ 2 Electric ESP Direct Access Preliminary Procedures Illustrated...................................................................................... 3 Procedures........................................................................................................................................................................ 4

1. Electric ESP obtains required documentation for Direct Access (DA) signup with PG&E ........................................................ 4 ESP Service Agreement ............................................................................................................................................................... 6 About Section 22, Billing Options ............................................................................................................................................... 6 About Section 23, Metering and Meter Reading Options ............................................................................................................ 7 Energy Service Provider Information Form ................................................................................................................................. 7 ESP Credit Application and Financial Statements ....................................................................................................................... 8 ESP creditworthiness requirements.............................................................................................................................................. 9 Credit evaluation parameters........................................................................................................................................................ 9 Primary credit requirements ......................................................................................................................................................... 9 Alternate credit requirements ....................................................................................................................................................... 9 Direct access consolidated billing options worksheet ................................................................................................................ 11 Instructions for completing the Direct Access Consolidated Billing Options Worksheet .......................................................... 12 Required format for the PG&E bill detail page included on Consolidated Electric ESP bills ................................................... 13 EDI Trading Partner Agreement ................................................................................................................................................ 13 Main Agreement ........................................................................................................................................................................ 13 Appendix.................................................................................................................................................................................... 14 EDI Setup Form ......................................................................................................................................................................... 16 Meter Data Management Agent (MDMA) qualification/approval ............................................................................................. 17

2. Electric ESP submits completed DA startup documentation to ESP Services........................................................................... 17 3. ESP Services Representative contacts Electric ESP upon receipt of DA startup documents .................................................... 17 4. PG&E reviews all submitted DA startup documentation .......................................................................................................... 17

DA startup Documentation Review Timeline ............................................................................................................................ 18 ESP Service Agreement Processing ........................................................................................................................................... 18 ESP Credit Application processing ............................................................................................................................................ 18 Credit Acceptance ...................................................................................................................................................................... 19 Credit Denial .............................................................................................................................................................................. 19

Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only Page iii

Direct Access Consolidated Billing Options Worksheet............................................................................................................ 19 EDI Trading Partner Agreement processing .............................................................................................................................. 19 EDI Setup Form ......................................................................................................................................................................... 19 MDMA Application and Checklist ............................................................................................................................................ 19

5. ESP Services Representative informs the Electric ESP of the type of DA participation for which it is eligible....................... 19 Information Websites...................................................................................................................................................... 21

CHAPTER 2 ......................................................................................................................................................................... 23 DIRECT ACCESS SETUP........................................................................................................................................................ 23

Overview......................................................................................................................................................................... 23 Prerequisites................................................................................................................................................................... 23 Checklist of key steps ...................................................................................................................................................... 24 Direct Access Setup Illustrated....................................................................................................................................... 24 Procedures...................................................................................................................................................................... 24

Electronic data exchange synopsis ................................................................................................................................................. 25 1. Prepare systems setup for electronic data exchange .................................................................................................................. 25 2. Review electronic transfer procedures and rules as designated by PG&E for DES and EDI (if applicable). ............................ 25

Data transfer specifics: How DES is used to exchange DA information ................................................................................... 26 DES implementation....................................................................................................................................................................... 26

Key DES contacts ...................................................................................................................................................................... 26 DES Web site ............................................................................................................................................................................. 27

EDI data transfer............................................................................................................................................................ 27 EDI contacts ................................................................................................................................................................................... 28

For more information ................................................................................................................................................................. 28 EDI Direct Access transaction sets................................................................................................................................................. 28

Transaction set 810 - Billing ...................................................................................................................................................... 28 Transaction set 814 - Direct Access Service Request (DASR) .................................................................................................. 28 Transaction set 820 - Payment and Remittance Order ............................................................................................................... 29 867 - Meter Usage...................................................................................................................................................................... 29 997 - Functional Acknowledgment ............................................................................................................................................ 29

Test the viability and accuracy of data transferred to PG&E using DES ....................................................................................... 29 CHAPTER 3 ......................................................................................................................................................................... 31

PROCESSING DIRECT ACCESS SERVICE REQUESTS (DASRS) .............................................................................................. 31 Overview......................................................................................................................................................................... 31

Definition of Terms ........................................................................................................................................................................ 31 Prerequisites................................................................................................................................................................... 32 Checklist of key steps ...................................................................................................................................................... 33 Processing DASRs Illustrated ........................................................................................................................................ 33 Procedures...................................................................................................................................................................... 35

1. Electric ESP obtains customer authorization to submit a DASR on its behalf .......................................................................... 35 2. Electric ESP obtains customer CTC Agreement, if required ..................................................................................................... 35 3. Electric ESP evaluates customer DA elections and obtains customer information required to complete DASR ...................... 35 5. Electric ESP submits DASR to PG&E through DES................................................................................................................. 36 6. PG&E processes DASR............................................................................................................................................................. 36

Electronic Validation ................................................................................................................................................................. 37 DASR Validation ....................................................................................................................................................................... 37 Account Validation .................................................................................................................................................................... 37

7. PG&E sends a confirmation, rejection, or pending notification to Electric ESP....................................................................... 38 Acceptance notices..................................................................................................................................................................... 38 Rejection DASR......................................................................................................................................................................... 39

Additional DASR procedures performed by PG&E ....................................................................................................................... 39

Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only Page iv

DASR for “New” Premises ........................................................................................................................................................ 39 Additional setup transaction procedures .................................................................................................................................... 39 Additional transaction procedures for newly established PG&E account numbers ................................................................... 40 Additional Shut Off (S/O) and Shut-off Non-Payment (SONP) transaction procedures............................................................ 41 Additional Cancellation transaction procedures......................................................................................................................... 41 Additional Customer Account Data Change transaction procedures ......................................................................................... 41 Additional procedures for Initial Customer Historical Usage Information ................................................................................ 41 Seamless Move .......................................................................................................................................................................... 42

Seamless Move Procedures ............................................................................................................................................................ 42 Canceling a Seamless Move ........................................................................................................................................................... 43 Limits to a Seamless Move Option................................................................................................................................................. 43

CHAPTER 4 ......................................................................................................................................................................... 45 DA ELECTRONIC DATA EXCHANGE CONTINGENCY PLANS................................................................................................. 45

Overview......................................................................................................................................................................... 45 Behind the scenes look at the DASR process ................................................................................................................................. 45 DASR Server Communication Illustrated ...................................................................................................................................... 46 Risks ............................................................................................................................................................................................... 46

Event Scenario Back-up Plans ....................................................................................................................................... 46 Electric ESP unable to communicate with DES ............................................................................................................................. 47

Situation ..................................................................................................................................................................................... 47 Back-up Plan .............................................................................................................................................................................. 47

Failure of PG&E equipment (DASR Interface & CIS)................................................................................................................... 48 Situation ..................................................................................................................................................................................... 48 Back-up Plan .............................................................................................................................................................................. 48

CHAPTER 5 ......................................................................................................................................................................... 49 METERING........................................................................................................................................................................... 49

Overview......................................................................................................................................................................... 49 Metering Services........................................................................................................................................................................... 49

Meter Service Provider Responsibilities .................................................................................................................................... 50 Meter Installation Standards....................................................................................................................................................... 50 Effective Direct Access Date ..................................................................................................................................................... 50 Meter Maintenance .................................................................................................................................................................... 50 Meter Equipment Specifications ................................................................................................................................................ 50

Obtaining Meter Equipment Information for Existing Customer Accounts ................................................................................... 51 Web Site Test ............................................................................................................................................................................. 51 Selection of the Meter Installer .................................................................................................................................................. 51 Scheduling Meter Removal and Installations - PG&E as Meter Installer .................................................................................. 51 Meters Supplied by PG&E......................................................................................................................................................... 52 Meters Supplied by Electric ESP ............................................................................................................................................... 52 DA Ready Meter ........................................................................................................................................................................ 52 Phone Service Notification - PG&E as Meter Installer .............................................................................................................. 52 Completed Meter Installs ........................................................................................................................................................... 53 Re-scheduling Meter Installations.............................................................................................................................................. 53

Scheduling Meter Removals and Installations - Electric ESP as Meter Installer............................................................................ 53 Meter Installation/Removal Notification *................................................................................................................................. 54 Return of PG&E Meters............................................................................................................................................................. 54

Service Upgrades............................................................................................................................................................................ 54 Return to Bundled Service from Direct Access and Meter Ownership .......................................................................................... 54 Electric ESP Inquiries..................................................................................................................................................................... 56

Wired Phone Line Requirements ............................................................................................................................................... 57 Wireless Phone Installation Requirements ................................................................................................................................. 58

Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only Page v

Responsibility - Phone Service Account Payment.......................................................................................................................... 59 Responsibility - Phone Service Operability and Maintenance........................................................................................................ 59 Retention of Rights......................................................................................................................................................................... 60

Meter Data Management Agent (MDMA) Requirements ............................................................................................... 60 MDMA Approval Process and Requirements ................................................................................................................................ 60

Application and Checklist .......................................................................................................................................................... 61 Written Requirements ................................................................................................................................................................ 61 Server Acceptance Test.............................................................................................................................................................. 61 Back-up Reading Process........................................................................................................................................................... 62 Data Format................................................................................................................................................................................ 62 Security and Confidentiality ...................................................................................................................................................... 62 Help Desk................................................................................................................................................................................... 62

Validating and Editing Data ........................................................................................................................................................... 63 Interval Data............................................................................................................................................................................... 63

Estimating Data .............................................................................................................................................................................. 64 Interval Data Estimation Rules .................................................................................................................................................. 64

Accuracy and Timeliness of Usage Data........................................................................................................................................ 64 Interval Data............................................................................................................................................................................... 65 Monthly Data ............................................................................................................................................................................. 65

Data retention period ...................................................................................................................................................................... 65 Electronic exchange of metering data............................................................................................................................................. 65

Interval and Time-Of-Use (TOU) data....................................................................................................................................... 66 Meter Reading ................................................................................................................................................................................ 67

Meter reading data obligations................................................................................................................................................... 67 PG&E meter reading .................................................................................................................................................................. 67 Electric ESP meter reading ........................................................................................................................................................ 68

Metered Usage Rates...................................................................................................................................................... 68 Life Support Customers and Medical Baseline Quantities ............................................................................................................. 68

CHAPTER 6 ......................................................................................................................................................................... 71 DASR PROCESSES FOR METERING DATA ADJUSTMENTS AND CHANGES............................................................................ 71

Overview......................................................................................................................................................................... 71 DA Account Commodity Status Changes........................................................................................................................ 72

DA Account Commodity Shut-Offs ............................................................................................................................................... 72 Process ....................................................................................................................................................................................... 72 Matrix of PG&E-initiated Records Related to Shut-offs by Meter Type ................................................................................... 72 Example ..................................................................................................................................................................................... 74

Meter Change ................................................................................................................................................................................. 75 Matrix of PG&E-initiated Records Related to Meter Change.................................................................................................... 75 Example ..................................................................................................................................................................................... 78 New Meter Sets Which are not Concurrent with Old Meter Removals...................................................................................... 78 Meter Configuration Data .......................................................................................................................................................... 79

Usage Adjustments ......................................................................................................................................................... 79 Usage Adjustments to Monthly Meter Data Due to Additional Validation Checking of Data when PG&E is the MDMA ...... 80 Matrix of PG&E-initiated Records Related to Usage Adjustments............................................................................................ 80 Example ..................................................................................................................................................................................... 82 Stand Alone Rebate transactions (reversal only adjustment) ..................................................................................................... 83

CHAPTER 7 ......................................................................................................................................................................... 85 ELECTRIC ESP ACCOUNT BILLING ...................................................................................................................................... 85

Overview......................................................................................................................................................................... 85 Bill Components and Billing Options ............................................................................................................................. 85

Summary of bill components.......................................................................................................................................................... 85

Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only Page vi

About the California Energy Commission Tax .............................................................................................................................. 86 Billing options ................................................................................................................................................................................ 87

Consolidated UDC billing.......................................................................................................................................................... 87 Consolidated ESP billing ........................................................................................................................................................... 87 Partial Consolidated ESP Billing ............................................................................................................................................... 87 Full Consolidated ESP Billing ................................................................................................................................................... 87 Separate billing .......................................................................................................................................................................... 88

Read and Bill Serial Dates.............................................................................................................................................................. 88 Consolidated UDC Billing.............................................................................................................................................. 88

Pricing options................................................................................................................................................................................ 89 Flat ($/month) ............................................................................................................................................................................ 90 Single-tiered ($/kWh)................................................................................................................................................................. 90 Double-Tiered ($/kWh, Electric ESP designates tiers) .............................................................................................................. 90 Time-of-Use - TOU ($/kWh, based on PG&E’s tiers) ............................................................................................................... 90 Custom pricing........................................................................................................................................................................... 91 Submitting Rate-ready data to PG&E ........................................................................................................................................ 91 Deadlines for the submission of rate-ready data ........................................................................................................................ 91

Bill format ...................................................................................................................................................................................... 91 Bill preparation and processing ...................................................................................................................................................... 91 Bill Printing and Delivery .............................................................................................................................................................. 92 Reports generated by PG&E........................................................................................................................................................... 92 Utility User Tax Application .......................................................................................................................................................... 92 How PG&E calculates Electric ESP payments............................................................................................................................... 93

When PG&E pays the Electric ESP ........................................................................................................................................... 91 I. PG&E payments to Electric ESP and supporting reports: ..................................................................................................... 91 II. When PG&E makes payment to Electric ESP....................................................................................................................... 91 III. Reserve against collections .................................................................................................................................................. 93 Payments from Electric ESP to PG&E....................................................................................................................................... 93

Consolidated ESP Billing ............................................................................................................................................... 93 Bill format requirements ............................................................................................................................................................ 93 Calculation of charges owed to PG&E....................................................................................................................................... 94 Payment Processing ................................................................................................................................................................... 94 Electronic Data Interchange (EDI)............................................................................................................................................. 94

Separate Billing Procedures........................................................................................................................................... 94 CHAPTER 8 ......................................................................................................................................................................... 95

CUSTOMER INFORMATION RELEASES .................................................................................................................................. 95 Overview......................................................................................................................................................................... 95 Confidential Customer Information Release .................................................................................................................. 95

GLOSSARY .......................................................................................................................................................................... 97 DIRECT ACCESS TERMS....................................................................................................................................................... 97

APPENDIX A ..................................................................................................................................................................... 103 SERVICE TERRITORY CITY CODES..................................................................................................................................... 103

APPENDIX B...................................................................................................................................................................... 121 SERVICE CITY ZIP CODES.................................................................................................................................................. 121

APPENDIX C ..................................................................................................................................................................... 135 DA APPROVED METERS .................................................................................................................................................... 135

Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only Page 1

P R E F A C E

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.

Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only 10/5/05 Page 2

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.

Pacific Gas and Electric Company, CONFIDENTIAL – For Internal Use by Authorized Personnel Only Page 3

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.

C H A P T E R 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


Electric ESP Direct Access Preliminary Procedures Illustrated

ESP submits completed DA startupdocumentation to ESP Relations

Is ESP's creditapproved? No

PG&E informsESP that itcannot offerConsolidatedESP billing

PG&E reviews startupdocumentation required forConsolidated ESP billing

ESP is eligible to participate in DAand offer Separate billing.

ESP obtains requireddocumentation for Direct Access

(DA) signup with PG&E

ESP Relations Representativecontacts ESP upon receipt of DA

startup documentation

No

Yes

PG&E informs ESPthat it can offer

ESP-Consolidatedbilling option.

Activation pendingESP's fulfillment of

EDI systemsrequirements

PG&E reviews and executesESP Service Agreement andconducts a quick review of the

ESP Credit Application

PG&E processesEDI Trading

Partner Agreement

PG&E processesEDI Setup Form

PG&E evaluatesESP CreditApplication

PG&E processesDirect Access

Consolidated BillingOptions Worksheet

Does ESP plan to offerConsolidated ESP billing? Yes


Procedures

This section provides a detailed discussion of the process steps outlined within the Checklist of Key Steps.

1. Electric ESP obtains required documentation for Direct Access (DA) signup with PG&E

Electric ESPs interested in participating in DA with PG&E will need to complete and execute the forms indicated in the DA Forms Table below. Information on filling out the DA forms is provided in the sections following the DA Forms Table.

DA startup forms can either be downloaded from the “DA Documents” link on the ESP Resource Center website (see Information Websites at the end of Chapter 1 in this handbook) or obtained from PG&E’s ESP Services.

Electric ESPs may also contact ESP Services via the ESP Services hotline at 415-973-1666, should they have any questions regarding the DA forms.

DA FORMS TABLE

# DOCUMENT DESCRIPTION WHEN REQUIRED

1. Energy Service Provider Service Agreement (the “ESP Service Agreement”)

This document specifies the roles and responsibilities of both the Electric ESP and PG&E with respect to DA business transactions and interactions which transpire between the two parties. Note that the content of the ESP Service Agreement may be amended from time to time at the direction of the CPUC.

Always

2. Energy Service Provider information

Document which asks for detailed information about the Electric ESP which is not included within the ESP Service Agreement.

Always

3. ESP Credit Application and Electric ESP’s financial statements

PG&E uses the Electric ESP’s Credit Application and financial statements to evaluate the credit worthiness of the Electric ESP.

Always


# DOCUMENT DESCRIPTION WHEN REQUIRED

4. Direct Access Consolidated Billing Options Worksheet

This form specifies the services and other information related to the selection of billing options. The form also serves as an authorization for PG&E to commence preparations which are necessary to establish the billing options selected by the Electric ESP.

If the Electric ESP plans to offer Consolidated ESP and/or Consolidated UDC billing

5. EDI Trading Partner Agreement

The primary purpose of the agreement is to establish the binding nature of financial charge and payment data which is transmitted electronically between the Electric ESP and PG&E. The agreement also specifies that data be exchanged in accordance with the American National Standards Institute (ANSI) Business Interchange Standards, which is currently ANSI X12.

If the Electric ESP plans to offer the Consolidated ESP billing option

6. EDI Setup Form This form specifies EDI systems details relevant to the electronic transmission of financial charge and payment data.

If the Electric ESP plans to offer the Consolidated ESP billing option

7. MDMA Approval Application and Checklist

Forms required to apply for approval as an MDMA.

If the Electric ESP plans to provide MDMA services.


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


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.


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.

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

• 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)

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 WORKSHEET (PAGE 1 OF 2)

INSTRUCTIONS FOR COMPLETING THE DIRECT ACCESS CONSOLIDATED BILLING OPTIONS WORKSHEET

Specifications made by the Electric ESP on this worksheet will determine the bill format that is generated for Consolidated ESP and Consolidated UDC invoices to end-use customers.

1. Electric ESPs will need to mark the checkbox(es) for the consolidated billing option(s) that it plans to provide.

2. For each consolidated billing option section, the Electric ESP indicates the additional options that it would like PG&E to provide.


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.


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.


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.


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


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.


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.


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.


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.


Information Websites

Electric ESPs may wish to add the following sites as “favorite” links on their web browsers for easy access to information about PG&E’s Direct Access program.

NAME ADDRESS

PG&E Corporation WWW.PGE.COM

Electric ESP (Electric Energy Service Provider) Resource Center

WWW.PGE.COM/ESP

Gas ESP (Gas Energy Service Provider) Resource Center

WWW.PGE.COM/CTA

EDI WWW.PGE.COM/EDI

Web Tariff Book WWW.PGE.COM/TARIFFS

DES MADS.PGE.COM

CPUC WWW.CPUC.CA.GOV

California Independent Systems Operator (CAISO)

WWW.CAISO.COM

C H A P T E R 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)



# 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 systemssetup for

electronic dataexchange

Review electronictransfer procedures

and rules asdesignated by PG&Efor DES and EDI (if

applicable

Review electronictransfer procedures

and rules asdesignated by PG&Efor DES and EDI (if

applicable

Procedures



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.


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.

Que PG&E DASRInterface

ESP

ESP

Fire

Wall

CISCS05 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:


CONTACT CONTACT INFO

LYNN MCELHATTON, USER ACCESS CONTROL AND DES ADMINISTRATOR

PHONE: (415) 973-8080 EMAIL: [email protected]

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.

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 SENIOR PROJECT MANAGER

BILLING PHONE: (415) 973-5119 EMAIL: [email protected]

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.

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.

C H A P T E R 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 FLOW

DESCRIPTION OF TRANSACTION

1 (ELECTRIC ESP TO UDC)

setup/establish direct access with customer


discontinue direct access with customer

3 (UDC TO ELECTRIC ESP)

acknowledge success of direct access request


acknowledge failure of direct access request


acknowledge actual switch of service provider


acknowledge receipt of switch notification


notify of shutoff or turn-on of service

8 (ELECTRIC ESP TO UDC) OR (UDC TO SP)

account maintenance (i.e., customer rate schedule change)

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)


• 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.


# 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.


ESP obtainscustomer CTCagreement, if

required

ESP obtainscustomer

authorization tosubmit a DASR

ESP evaluatescustomer DA

elections and obtainsappropriate data

ESP submits DASRthrough DES

PG&E evaluatesDASR

Accept DASR

PG&E sends rejectionnotice to ESP & customer

ESP resolves DASRissues

Yes

PG&E sendsacceptance notice to

ESP & customerperforms DASR

transaction

ESP completesDASR

PG&E sends pendingnotice to ESP & customer

Pending formore than 11

days?

YesNo-reject

No-pending

No


Procedures


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.


TRANSACTION # DESCRIPTION OF TRANSACTION

REQUIRED CUSTOMER INFORMATION

1 SETUP/ESTABLISH DIRECT ACCESS WITH CUSTOMER

• Customer Name • Service Account Address and current service Zip • UDC Customer Account Number • Service Relationship Provided • Provider (Electric ESP, UTC) • Commodity (i.e. electric, gas) • Billing Option (i.e. UDC-consolidated,

Consolidated ESP, dual) • Renewable Energy Provider Requested • Life Support Customer status*

2 DISCONTINUE DIRECT ACCESS WITH CUSTOMER

• UDC Customer Account Number • Service Relationship Energy Provided (i.e.

electric, gas) • Customer Name • Service Account Address and current service Zip

6 ACKNOWLEDGE RECEIPT OF SWITCH NOTIFICATION

• Provide information contained in the acknowledgment of actual switch of service provider

10 ACCOUNT MAINTENANCE (I.E., CUSTOMER RATE SCHEDULE CHANGE)

• UDC Customer Account Number • Service Relationship Energy Provided (i.e.

electric, gas) • Customer Name • Service Account Address • Account information the customer wants to

change

11 ACCOUNT UPDATE (I.E. METERING RELATIONSHIPS, BILLING OPTIONS)

• Same as #10, Account Maintenance, above

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.

6. PG&E processes DASR The illustration below represents the timing associated with processing a DASR.


Day 18

PG&E sendsacknowledgmentto ESP that they

have received theDASR

Day 0 Day 7

Does PG&Eaccept the DASR

PG&E sendsDASR

acceptanceconfirmation

to ESP &customer

PG&Enotifies ESP& customer

of errorpendingstatus orrejectedDASR

No

Yes

PG&E will confirm or rejectDASRs in error pending

status

PG&E will provide, alongwith the confirmationnotice, information

regarding when the DAcustomer will begin

receiving ESP services,unless a meter is required

Day 2

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 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.”


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.


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.


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.


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.


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.


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.

C H A P T E R 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

ESP

Fire

Wall


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.


Electric ESP unable to communicate with DES

DES PG&E DASRInterface

ESP

ESP

Fire

Wall


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.


4. PG&E will send a confirmation file back to the Electric ESP containing confirmation or rejection data for each DASR.

Failure of PG&E equipment (DASR Interface & CIS)


ESP

ESP

Fire

Wall


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.

C H A P T E R 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:


• 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


• 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.


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


• 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:


• 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.


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


• 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”


• 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


• Ring voltage, 25Hz, 60 VRMs 150Vp-p

• 350 Hz/440 Hz square wave dial tone

2. RJ45 jack for cellular handset programming and testing

3. The power supply for cellular telemetry system shall be outside any sealed section and on the load side of the meter. The power supply should further be on a dedicated circuit or otherwise connected so that it is energized at all times.

4. Mounting of the cellular telemetry system shall be the same requirement as the installation of NIU as described above.

5. The ESP shall ensure that any accessories to the cellular telemetry system, such as an antenna and a mounting bracket, are properly installed or attached.

6. The ESP shall have the system activated and functionally tested prior to notifying PG&E that the site is ready.

7. The cellular telemetry system unit shall be labeled to read, “For Electric Meter Use Only.”

8. The unit shall be further labeled to show:

• Telephone number

• Maintenance and repair telephone number, and

• Cellular telephone service provider’s name

The ESP is responsible for the maintenance, repair and replacement of the cellular telemetry unit.

Responsibility - Phone Service Account Payment If an active phone line exists for a PG&E interval data meter and the ESP chooses to remove the meter and install its own, PG&E will advise the phone service provider to cancel the account.

Or in those cases where the ESP is installing phone-read technology, PG&E will change billing from PG&E to the ESP. Some review of phone account responsibility may be required for those sites where PG&E uses the data for load research.

Responsibility - Phone Service Operability and Maintenance When PG&E is the ESP’s MDMA, the ESP is ultimately responsible for the on-going phone line operability.

The ESP must ensure that phone service is not turned off due to late or lack of payments to the phone service provider. Monthly payments should be made directly to the phone service provider.


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

• 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.

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.

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 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).

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 1st 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 2nd 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 5th 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 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

VEEProcess

InternalServer

FirewallData Exchange Server

ESP

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.

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.

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:

• 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.

C H A P T E R 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.


ACTION ISSUE RECORD TO CURRENT ELECTRIC ESP, PENDING ELECTRIC ESP, AND ALL ASSOCIATED ELECTRIC ESPS

ISSUE RECORD TO CURRENT ELECTRIC ESP AND BILL CALCULATOR


RECORD TYPE ISSUED

MEPAD01 MEPMD01 MEPMD02

MONTHLY SINGLE-METERED

One MEPAD01 record:

Operation Type field = “SVC”

Reason field = “DISCONNECT”

Effective End Date Field = date the account commodity was closed

One MEPMD01 record:

Normal start/end read information record.

One MEPMD02 record:

Normal totalized usage information record.

MONTHLY MULTI-METERED

Same as above A MEPMD01 record for each meter:

Normal start/end read information record

A MEPMD02 record:

Normal totalized usage information record.

Meter field = “TOTAL”

INTERVAL SINGLE-METERED

Same as above 1. One or more MEPMD01 record(s), depending upon interval and period reported: normal (monthly, not interval) start/end read information record.

2. One or more MEPMD01 record(s): normal usage information record by interval.

None

INTERVAL MULTI-METERED

Same as above 1. One or more MEPMD01 record(s), depending upon interval and period reported: normal (monthly, not interval) start/end read information record.

2. One or more MEPMD01 record(s): normal usage information record by interval.


None


ACTION ISSUE RECORD TO CURRENT ELECTRIC ESP, PENDING ELECTRIC ESP, AND ALL ASSOCIATED ELECTRIC ESPS



DEMAND METERED Same as above One MEPMD01 Record: normal start/end red information record

1. One MEPMD02 record: normal usage information record

2. One MEPMD02 Record: normal demand usage information

TOU METERED Same as above None 1. One MEPMD02 record: normal start read information

2. One MEPMD02 record: normal end read information

3. One MEPMD02 record: normal usage information record

EXAMPLE

Scenario: An interval meter customer has been billed from 5/15 to 6/15. The customer requests a 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.


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.


ACTION ISSUE RECORD TO CURRENT ELECTRIC ESP AND BILL CALCULATOR


RECORD TYPE ISSUED

MEPMD01 MEPMD02


• One MEPMD01 record for the old meter: normal start/end read information

Meter field = old meter number

• One MEPMD01 record for the new meter: normal start/end read information

Meter field = new meter number

One MEPMD02 record:

Normal totalized usage information record for both meters



• One MEPMD01 record for each old meter removed: normal start/end read information


• One MEPMD01 record for each new meter installed: normal start/end read information


One MEPMD02:

Normal usage information record totalizing usage for all meters.



• One MEPMD01 record for the old meter: normal monthly (not interval)start/end read information


• One MEPMD01 record for the new meter: normal monthly (not interval) start/end read information


• One MEPMD01 record: normal totalized usage record


None





• One MEPMD01 record for each old meter: normal start/end read information


• One MEPMD01 record for each new meter: normal start/end read information


• One MEPMD01 record: totalized usage record


None

DEMAND METERED • One MEPMD01 record for the old meter: normal start/end read information (kwhreg)


• One MEPMD01 record for the new meter: normal start/end read information (kwhreg)


• One MEPMD02 record for the old meter: usage information (kwh)

• One MEPMD02 record for the new meter: usage information (kwh)

• One MEPMD02 record for the old meter: demand usage information (kw)

• One MEPMD02 record for the new meter: demand usage information (kw)




TOU METERED None • One MEPMD02 records for the old meter: start reads information


• One MEPMD02 records for the new meter: start reads information


• One MEPMD02 records for the old meter: end reads information


• One MEPMD02 records for the new meter: end reads information


• One MEPMD02 record for the old and new meters’ totalized usage information


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


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.


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.




RECORD TYPE ISSUED

MEPMD01 MEPMD02


• One MEPMD01 record with the adjusted read in the Data field for each adjusted period

Example for a two months adjustment:

Data field = “199804150001, ,750,199805150001,A,1300”

Data field = “199805150001,A,1300,199806150001,A ,1650”

One MEPMD02 record for each adjusted period with the adjusted total usage

Example for a two months adjustment:

Eff Start field = “199804150001”

Eff End field = “199805150001”

Data field = “TOTAL,A,550”

Eff Start field = “199805150001”

Eff End field = “199806150001”

Data field = “TOTAL,A,350”


• One MEPMD01 record for the adjusted meter, with the adjusted reads in the Data field (similar to monthly single-metered reads adjustment record).

Meter field = adjusted meter number

One MEPMD02 record for each adjusted period with the adjusted totalized usage for all the meters (similar to single-metered usage adjustment record).



• One or more MEPMD01 record(s) with adjusted start/end reads information record (similar to monthly single-metered reads adjustment record).

• One or more MEPMD01 record(s) with adjusted totalized usage (similar to monthly single-metered usage adjustment record).

None


Same as above. None

DEMAND METERED • One MEPMD01 record with the adjusted reads in the Data field (similar to monthly single-metered reads adjustment record).

• One MEPMD02 record with the adjusted total usage in the Data field (similar to monthly single-metered usage adjustment record).

• One MEPMD02 with the adjusted demand usage information (similar to the monthly single-metered usage adjustment record).




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 NAME

DATE MEPMD02 USAGE

MEPMD01: START READ

END READ

PG&E 2/15 -3/15 400 KWH 0 400

PG&E 3/15 - 4/15 350 KWH 400 750

ESP 4/15 - 5/15 500 KWH 750 1250

ESP 5/15 - 6/15 400 KWH 1250 1650

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.


TIMING ORDER RECORD TYPE ISSUED

DATA INCLUDED IN RECORD

1. MEPMD01 Data field = 199804150001, ,750,199805150001,A,1300

2. MEPMD02 Eff Start field = 199804150001

Eff Stop field = 199805150001

Data field = TOTAL,A,550

3. MEPMD01 Data field = 199805150001,A,1300,199806150001,A,1650

4. MEPMD02 Eff Start field = 199805150001

Eff Stop field = 199806150001

Data field = TOTAL,A,350

Records for items 1 and 2 will be sent on the same day (6/23) when the bill period 4/14 - 5/15 is adjusted. Then the records for items 3 and 4 will be sent on the same day (6/26) when the bill period 5/15 - 6/15 is adjusted. The timing between the sending of the two sets of records will be around 3 days and based on when each adjustment transaction is processed.

STAND ALONE REBATE TRANSACTIONS (REVERSAL ONLY ADJUSTMENT)

Under some circumstances only a rebate transaction will need to be made to the account. A rebate is a reversal of what was originally billed. This business scenario may occur when PG&E needs to reverse a bill and then wait for the next on cycle bill to rebill the account. In this situation, PG&E’s system will wait for three (3) processing days after a rebill transaction is processed by the biller. If the rebill transaction does not occur within three (3) processing days of the rebate, the system will interpret the rebill as an reversal only adjustment and send the rebate as a meter adjustment record reversing the reads, and with 0 usage. When the rebill transaction is eventually processed through the system, then the rebill transaction will be sent to the Electric ESP’s as adjusted reads/usage records.

Using the same scenario as the previous example, adjust the billing for the bill period of 5/15 - 6/15. The adjustment is to just reverse the bill and let next month’s on cycle read generate the rebill. So, on 6/20, a reversal is processed. On 6/23, the system did not receive the rebill for 5/15 to 6/15, so it assumed the biller wanted to do just a reversal only adjustment. The system will send to the Electric ESP the following records on 6/23:

MEPMD01 - DATA field = 199805150001,A,1250,199805150001,A,1250

MEPMD02 - Eff Start field = 199805150001 Eff Stop field = 199805150001 DATA field = TOTAL, A,0

On 7/15 - the next on cycle billing, the following records will be sent. Note that since the billing period includes the bill period that was reversed, the quality code will be A to indicate an adjustment to a previously sent metering data record.


MEPMD01 - DATA field = 199805150001, ,1250,199807150001,A,1850

MEPMD02 - Eff Start field = 199805150001 Eff Stop field = 199807150001 DATA field = TOTAL,A,600

C H A P T E R 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


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 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.


Pricing options Electric ESPs communicate Rate-ready pricing options by completing the PG&E Consolidated Billing Pricing Worksheet. The following exhibit is an example of the worksheet.

7.1 - PG&E CONSOLIDATED BILLING PRICING WORKSHEET

The Electric ESP must complete and submit the PG&EConsolidated Billing Pricing Worksheet for every pricing change that it wants to make. The worksheet can be downloaded from the “DA Documents” link on the PG&E’s ESP Resource Center Web site or obtained by contacting ESP Services at 415-973-1666. Completed worksheets should be faxed to ESP Services at 415-973-2194.


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.


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 PG&E will include the Electric ESP’s logo on the page of the customer’s bill which details Electric ESP charges. However, the Electric ESP must provide ESPBS with the company information that must appear on the bill (i.e. Electric ESP’s name, address, telephone number) as well as the Electric ESP’s company logo. The logo should be provided in the form of a bitmap image file. All details regarding the Electric ESP bill page format are addressed in the Direct Access Consolidated Billing Options Worksheet which can be located and downloaded from the “DA Documents” link on the ESP Resource Center Web site.

Bill preparation and processing PG&E will prepare the consolidated bill according to the procedures outlined below.

1. PG&E will calculate the Electric ESP’s energy cost charges. The Electric ESP’s rate schedule is used to calculate the energy cost component. Information regarding the submission of rate schedule information by the Electric ESP is covered within Chapter 3: Processing DASRs.


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.


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.


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.

C H A P T E R 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 [email protected].

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 [email protected].

G L O S S A R Y

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 CHARGE (CTC)

Defined in Public Utilities Code Section 840 and by the Commission.

CONNECTED LOAD The sum of the rated capacities of all the customer’s equipment that can be connected to PG&E’s lines at any one time as more completely described in the rate schedules.

CPUC (CALIFORNIA PUBLIC UTILITIES COMMISSION)

The Public Utilities Commission of the State of California.

CURTAILMENT The temporary reduction or interruption of service to customers because of projected or actual supply or capacity constraints, as further defined in Rule 14 and PG&E’s Electrical Emergency Plan. PG&E may also request such load reduction under the provisions of its nonfirm programs.

CUSTOMER The person, group of persons, firm, corporation, institution, municipality, or other civic body, in whose name service is rendered, as evidenced by the signature on the application, contract, or agreement for that service, or in the absence of a signed instrument, by the receipt and payment of bills regularly issued in that name, regardless of the identity of the actual user of the service. a customer may take Full Service or Direct Access Service, but must take final delivery of electrical power, and not resell that power.

DEMAND The amount of energy drawn by a Customer at a specific time. Typically expressed in kilowatts or kW.

DEMAND CHARGE One component of an electric customer’s bill (along with, but not limited to, the customer charge, meter charge, and the energy charge). This charge recovers some of the costs PG&E incurs in providing sufficient operating capacity to meet that customer’s maximum demand. The demand charge is based on the highest level of kW required by the customer during a billing period.

DIRECT ACCESS METER A meter meeting the Commission’s requirements to support Direct Access Service to a Direct Access Customer not eligible for a Load Profile.

DIRECT ACCESS SERVICE Defined in Rule 22.

DIRECT ACCESS SERVICE REQUEST (DASR)

An application for Direct Access Service submitted to PG&E on behalf of a Customer by an Electric ESP, as described in Rule 22.

DISTRIBUTION LOSS FACTORS The loss of energy over distribution lines are categorized into two distinct loss factor types: Distribution Line Losses and Total Distribution System Losses.

Distribution Line Losses consist of:

• losses due to resistance in the distribution lines • transformer core losses

Total Distribution System Losses consist of:

• distribution line losses • metering error - the difference between the actual electric usage at the meter and

the recorded meter read plus any differences due to malfunctioning meters • energy theft - the deliberate and unauthorized use of energy

DISTRIBUTION SERVICES The delivery of electrical supply and related services by PG&E to a customer over PG&E’s Distribution System.

DISTRIBUTION SYSTEM Those non-ISO transmission and distribution facilities owned, controlled, and operated by PG&E that are used to provide Distribution Service under these tariffs.


ELECTRIC SUPPLY OR PROCUREMENT SERVICES

Includes, but is not limited to, procurement of electric energy; all scheduling; settlement, and other interactions with Scheduling Coordinators, the ISO and the PX; all ancillary services and congestion management.

ELECTRONIC DATA INTERCHANGE (EDI)

The electronic transmission and receipt of data and/or funds in agreed upon formats in accordance with PG&E’s specifications.

ENERGY SERVICE PROVIDER (ESP)

An entity who provides electric supply services to DA Customers within PG&E’s service territory. An ESP may also provide certain metering and billing services to its DA Customers as provided for within these tariffs.

FIXED TRANSITION AMOUNT (FTA) CHARGE

A non-bypassable, separate charge that is authorized by the Commission to be charged to residential and small commercial customers to allow PG&E to recover financed transition costs and the costs of providing, recovering, financing or refinancing transition costs, including the costs of issuing, servicing, and retiring Rate Reduction Bonds.

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 (ISO)

The California Independent System Operator Corporation, a state chartered, non-profit corporation that controls the transmission facilities of all participating transmission owners and dispatches certain generating units and loads. The ISO is responsible for the operation and control of the statewide transmission grid.

KILOWATT 1,000 watts; a watt is a unit of electrical power equal to a current of one ampere under one volt of pressure.

KILOWATT-HOUR 1,000 watts, or one (1) kilowatt of electricity used for one hour.

LOAD PROFILES An approximation of a Customer’s electric usage pattern as approved by the Commission for certain purposes set forth in PG&E’s tariffs.

MASTER-METERED CUSTOMER A PG&E Customer who takes Full or Direct Access Service at a single “master meter” and distributes electric supply, by its own means, to tenants within its own premises. The availability of master metering is limited by Rule 18 and the P.U. Code.

MASTER-METERING Where PG&E installs one service and meter supply more than one residence, apartment dwelling unit, mobile home space, store, office, etc.

METER The instrument that is used for measuring the electricity delivered to the Customer. In certain circumstances, the terms “meter” or “metering” also include related metering facilities or equipment.

METER DATA MANAGEMENT AGENT (MDMA)

the entity that takes raw meter outputs, validates them using validation, editing, and estimating rules, adds corollary information needed to characterize the customer, and makes complete customer information available to others for use in various applications.

METER SERVICE PROVIDER (MSP)

The entity that installs, validates, registers, and maintains the physical meter required on a premise to measure the required variables.

METERING FACILITIES OR METERING EQUIPMENT

A meter, its associated current and potential transformers, test facilities, communication interfaces, and other associated metering equipment required for the measurement of supply deliveries to a Customer’s Account.


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 CHARGES

A non-bypassable surcharge imposed on all retail sales of electricity and electrical services to fund public goods research, development and demonstration, energy efficient activities, and low income assistance programs.

PUBLIC UTILITIES COMMISSION The Public Utilities Commission of the State of California.

QUALIFIED CONTRACTOR/ SUBCONTRACTOR (QC/S)

An applicant’s contractor or subcontractor who:

• is licensed in California for the appropriate type of work such as, but not limited to, electrical and general;

• employs electric workmen properly qualified (Qualified Electrical Worker, Qualified Person, etc.) as defined in State of California High Voltage Safety Orders (Title 8, Chapter 4, Subchapter 5, Group 2); and

• complies with applicable laws such as but not limited to, Equal Opportunity Regulations, OSHA, and EPA

RATE SCHEDULE One or more tariff sheet(s) setting forth the charges and conditions for a particular class or type of service in a given area or location. A rate schedule includes all of the wording on the applicable tariff sheet(s), such as Schedule number, title, class of service, applicability, territory, rates, conditions, and references to rules.

RULES Tariff sheets which cover the application of all rates, charges, and services when such applicability is not set forth in and as part of the rate schedules.

SCHEDULED METER READING DATE

The date PG&E has scheduled a Customer’s meter to be read for the purposes of ending the current billing cycle and beginning a new one. PG&E’s meter reading schedule is published annually, but is subject to periodic change.


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.

A P P E N D I X A

SERVICE TERRITORY CITY CODES

CITY CODE LETTERS CORRESPOND TO THE SECOND AND THIRD CHARACTERS OF THE CUSTOMER ACCOUNT NUMBER.

CITY NAME CITY CODE

ACADEMY TK

ACAMPO AK

ADAMS SPRINGS ZH

AGNEW VP

AGUA CALIENTE NV

AHWAHNEE AE

ALAMEDA JP

ALAMO AL

ALBANY AB

ALBION QA

ALDER SPRINGS FJ

ALDER SPRINGS TK

ALDERPOINT G4

ALEXANDER VALLEY NH

ALLEGHANY IU

ALLENSWORTH AF

ALMANOR Q1

ALPAUGH AF

ALTA H1

ALTAVILLE XB

ALTO NK

ALTON KT

ALVISO AV

AMADOR CITY QB

AMBOY T3

AMERICAN CANYON NY

ANCHOR BAY P2

ANDERSON AS

ANDERSON SPRINGS ZM

ANDRUS ISLAND PP

ANGELS CAMP XB

ANGWIN N2

ANNAPOLIS 1N

ANNAPOLIS 1N

ANTELOPE AN

ANTIOCH JC

APPLEGATE H2

APTOS AP

ARBUCKLE DB

ARCATA AC

ARGUS TD

ARNOLD XA

AROMAS XK

AROMAS XK


ARROYO GRANDE AG

ARROYO GRANDE AG

ARROYO SECO GF

ARTOIS 9A

ARVIN AR

ASTI 2N

ATASCADERO WW

ATHERTON AT

ATWATER AW

AUBERRY AU

AUBURN HB

AUBURN HB

AUCKLAND TJ

AUKUM XD

AVENAL AZ

AVERY XY

AVILA BEACH AA

AVON JG

BACHELOR VALLEY ZU

BADGER AD

BAKER RANCH GE

BAKERSFIELD TC

BAKERSFIELD TC

BAKERSFIELD TC

BALLARD B7

BALLICO BQ

BANGOR YB

BANTA X2

BASS LAKE LD

BAXTER H3

BAY POINT DP

BAYLISS FJ

BAYSIDE YS

BAYWOOD PARK LG

BEALE AFB BY

BEAR VALLEY 9S

BEAR VALLEY ZS

BEAR VALLEY 2T

BEAR VALLEY SPRING

TR

BELDEN Q9

BELL SPRINGS LM

BELLA VISTA VH

BELLA VISTA VH

BELMONT RN

BELVEDERE NU

BEN LOMOND BP

BENBOW LM

BEND FN

BENICIA BE

BERENDA TN

BERKELEY JR

BERKELEY JR

BERRY CREEK IY

BETHANY XV

BETHEL ISLAND BI

BETTERAVIA BX

BIEBER UQ

BIG BEND UD

BIG BEND H8

BIG BEND VILLAGE DS

BIG LAGOON LF

BIG MEADOW TJ

BIG OAK FLAT EF

BIG SPRINGS FP

BIG SUR ME

BIGGS JM

BIOLA BA

BIRCHVILLE HM

BIRDS LANDING P7

BIRDS LANDING PP

BITTERWATER BJ

BLACK POINT NM

BLACKWELLS CORNER

TX

BLAKES LANDING MM

BLOCKSBURG KD

BLOOMFIELD NN

BLUE CANYON H5

BLUE LAKE CQ

BLUE LAKE CQ


BODEGA BB

BODEGA BAY BB

BODEGA BAY BB

BOGARD STATION FF

BOLINAS BZ

BONNY DOON VT

BOONVILLE UF

BOOTJACK TS

BORON BO

BOULDER CREEK BC

BOWLES TT

BOWMAN HB

BOYES HOT SPRINGS 7N

BRADLEY DC

BRADLEY DC

BRANNAN ISLAND PP

BRANSCOMB W9

BRENTWOOD BW

BRICELAND LM

BRIDGEPORT HM

BRIDGEVILLE KE

BRIGHTON PS

BRISBANE AH

BROOKDALE BD

BROOKS 2P

BROWNS FLAT XR

BROWNS VALLEY BL

BROWNSVILLE IV

BRUSH CREEK IH

BRYTE WS

BUCKINGHAM PARK ZK

BUCKS LAKE FP

BUELLTON B9

BUMBLEBEE XR

BURLINGAME BS

BURNEY FF

BURNT RANCH L3

BURREL BF

BURREL BF

BURSON XI

BURSON XI

BUTTE CITY ET

BUTTE MEADOWS F1

BUTTONWILLOW BU

BYRON BN

CACHAGUA CY

CACHUMA 3B

CADIZ 2C

CALAVERAS BIG TREES

XA

CALIFORNIA VALLEY 3C

CALISTOGA N3

CALPELLA UG

CALWA TK

CAMANCHE XD

CAMBRIA KA

CAMDEN TT

CAMERON PARK GS

CAMINO GP

CAMP CONNELL XA

CAMP MEEKER CR

CAMP MONTECITO TJ

CAMP SACRAMENTO HT

CAMPBELL CM

CAMPBELL CM

CAMPO SECO XE

CAMPO SECO VS

CAMPTONVILLE IQ

CANTUA CREEK KK

CANYON J2

CANYON DAM Q4

CAPAY FJ

CAPAY 3P

CAPITOLA CP

CARBONA XV

CARIBOU FP

CARLOTTA KH

CARMEL CE

CARMEL HIGHLAND CE

CARMEL VALLEY CY

CARMEL VALLEY CE


CARMICHAEL CA

CARRISA PLAINS T4

CARSON HILL XB

CARUTHERS CB

CARUTHERS CB

CASMALIA B6

CASPAR QC

CASSEL UR

CASTLE GARDENS TR

CASTRO VALLEY CV

CASTROVILLE CT

CATHEYS VALLEY CZ

CAWELO TX

CAYTON VALLEY FF

CAYUCOS KY

CAZADERO 4N

CEDAR FLAT LW

CEDAR GROVE TJ

CEDAR RIDGE JE

CEDARBROOK TJ

CENTERVILLE FB

CENTERVILLE KQ

CENTERVILLE TK

CENTRAL VALLEY VE

CERES AJ

CERES AJ

CHALLENGE YQ

CHAMBLESS TD

CHEROKEE FM

CHESTER Y8

CHICAGO PARK JF

CHICO FB

CHILES VALLEY N3

CHINESE CAMP EJ

CHOLAME DG

CHOWCHILLA TP

CHOWCHILLA TP

CHRISTIAN VALLEY HB

CHROME FJ

CHUALAR CF

CISCO GROVE H8

CITRUS HEIGHTS CH

CLARKSBURG CG

CLARKSVILLE HT

CLAY XF

CLAYTON CL

CLEAR CREEK Q7

CLEARLAKE ZC

CLEARLAKE OAKS ZE

CLEARLAKE PARK ZP

CLEMENTS KM

CLEONE NF

CLINGANS JUNCTION TJ

CLINTON XD

CLIPPER GAP HB

CLIPPER MILLS IM

CLOVERDALE ND

CLOVIS CI

CLYDE CD

COALINGA TF

COARSEGOLD GO

COBB ZH

COHASSET FB

COLD CREEK NX

COLD SPRINGS YU

COLFAX HF

COLLEGE CITY CC

COLLINSVILLE PP

COLMA AI

COLOMA GQ

COLUMBIA YW

COLUSA PX

COMPTCHE UH

CONCORD JG

CONCOW FM

CONEJO TT

CONFIDENCE XR

COOL GD

COPPEROPOLIS XC

CORCORAN TG

CORDELIA PK


CORDELIA PJ

CORNING WF

CORRAL DE TIERRA BT

CORRALITOS VX

CORTE MADERA CN

COTATI CO

COTTONWOOD KO

COTTONWOOD KO

COULTERVILLE CX

COULTERVILLE CX

COVELO W7

COW CREEK SR

COYOTE VR

CRESCENT MILLS EY

CRESSEY CS

CRESSMAN AU

CRESTON DQ

CROCKETT CK

CROWS LANDING X6

CUMMINGS G5

CUNNINGHAM NR

CUPERTINO VV

CUSHENBURY SPRINGS

TD

CUTLER CW

CUTTEN LF

CUYAMA VALLEY CJ

DAGGETT TD

DAIRYVILLE FN

DALY CITY RB

DANA DY

DANVILLE DD

DAVENPORT DN

DAVIS PY

DAYTON FB

DE SABLA FM

DEER PARK N4

DEHAVEN QW

DEL LOMA L1

DEL PASO HEIGHTS PS

DEL REY DR

DEL REY DR

DEL REY OAKS BT

DELEVAN PX

DELFT COLONY TJ

DELHI 1X

DENAIR DK

DENAIR DK

DENVERTON FS

DERBY ACRES DE

DIABLO DL

DIAMOND SPRINGS GT

DIBBLE CREEK FN

DIGIORGIO TC

DILLON BEACH ZD

DINSMORE KE

DINUBA TJ

DINUBA TJ

DIXON PF

DIXON PF

DOBBINS DO

DONNER SUMMITT H8

DORRINGTON XA

DOS PALOS DZ

DOS PALOS (SOUTH) DT

DOS PALOS (SOUTH) TM

DOS PALOS Y TM

DOS RIOS W6

DOUGLAS FLAT XG

DOWNIEVILLE HJ

DRUM VALLEY TJ

DRYTOWN QD

DUBLIN DU

DUNCAN MILLS M1

DUNLAP DI

DUNNIGAN DB

DUNNIGAN DB

DURHAM DH

DUSTIN ACRES DA

DUTCH FLAT H4

EARLIMART EA


EAST NICOLAUS HP

EAST NICOLAUS NO

EAST OAKLAND JQ

EAST PALO ALTO EP

EASTON TK

ECHO LAKE HT

EDISON TC

EDWARDS ED

EDWARDS (NORTH) ED

EDWARDS AFB ED

EEL ROCK LM

EL CAMINO WF

EL CERRITO EC

EL DORADO GV

EL DORADO HILLS GW

EL GRANADA VG

EL MACERO EO

EL NIDO EN

EL PORTAL EL

EL SOBRANTE ES

EL VERANO NV

ELDERWOOD WJ

ELDRIDGE NV

ELK P3

ELK CREEK 9E

ELK GROVE EG

ELK RIVER LF

ELKHORN BT

ELMIRA EI

ELVERTA EV

ELVERTA EV

ELVERTA EV

EMERYVILLE EM

EMIGRANT GAP H5

EMMET B6

EMPIRE ER

ENTERPRISE FQ

ESCALON X5

ESCALON X5

ESHOM VALLEY TJ

ESPARTO 4P

ETTERSBURG 1G

EUREKA LF

FAIR OAKS FO

FAIR PLAY HT

FAIRFAX FX

FAIRFIELD PJ

FAIRHAVEN AM

FAIRMEAD TP

FALL RIVER MILLS UE

FALLON ZB

FAMOSO TX

FARMINGTON FA

FEATHER FALLS IF

FELLOWS FW

FELTON FE

FERNBRIDGE KJ

FERNDALE KQ

FETTERS HOT SPRINGS

NV

FIDDLETOWN QE

FIELDBROOK OX

FIELDS LANDING YL

FINLEY ZF

FIREBAUGH FG

FISH CAMP YF

FITCH MOUNTAIN NH

FIVE POINTS FT

FLORIN PS

FLOURNOY OF

FOLSOM FL

FORBESTOWN IT

FORD CITY TV

FOREST IX

FOREST GLEN 8F

FOREST KNOLLS FK

FOREST RANCH F9

FORESTHILL GE

FORESTVILLE FV

FORESTVILLE FV

FORT BRAGG NF


FORT ORD SS

FORT ORD MA

FORT ROSS 5N

FORT SEWARD 2G

FORTUNA LJ

FOSTER CITY FC

FOUR COURNERS TD

FOWLER FI

FRANKLIN PS

FRANZ VALLEY NL

FREEDOM XM

FREEPORT PS

FREESTONE NR

FREMONT JJ

FRENCH CAMP FH

FRENCH CAMP FH

FRENCH CORRAL JO

FRENCH CORRAL IJ

FRENCH GULCH ZG

FRESH POND HT

FRESHWATER LF

FRESNO TK

FRESNO TK

FRIANT FR

FRIANT FR

FRIANT FR

FRUITLAND LM

FRUITVALE TC

FULTON FU

GALT GA

GALT GA

GANNS MEADOW XA

GARBERVILLE LM

GARDEN VALLEY GG

GARDENLAND PS

GAREY BX

GENERAL GRANT GROVE

TJ

GENESEE EZ

GEORGETOWN GH

GERBER GB

GEYSERS ND

GEYSERVILLE NC

GILROY VF

GLEN ELLEN 6N

GLENBURN DX

GLENCOE QV

GLENHAVEN ZJ

GLENN 9G

GOLD HILL HT

GOLD LAKE IG

GOLD RIVER RA

GOLD RUN H6

GONZALES GZ

GOODYEARS BAR JD

GRAND ISLAND PP

GRANITE BAY HS

GRANITE BAY KR

GRANITE STATION TC

GRAPEVINE TC

GRASS VALLEY HM

GRATON GR

GRAYSON X7

GREELEY HILL 7G

GREENACRES TC

GREENBRAE LK

GREENFIELD GF

GREENFIELD TC

GREENVILLE YG

GREENWOOD GI

GRIDLEY FD

GRIMES ZA

GRIMES ZA

GRIZZLEY BLUFF LJ

GRIZZLY FLATS GX

GRIZZLY ISLAND FS

GROVELAND YY

GROVER BEACH GC

GUADALUPE B8

GUALALA P4

GUERNEVILLE NG


GUERNSEY TG

GUINDA 5P

GUSTINE GU

GUSTINE GU

HACIENDA FV

HALCYON AG

HALES GROVE LM

HALF MOON BAY RH

HAMES VALLEY DC

HAMILTON CITY 9H

HAMILTON FIELD NM

HAMLET NN

HAMMONTON HP

HANFORD HA

HANFORD HA

HANFORD HA

HARDON FLAT XR

HARDWICK TT

HARMONY T7

HARRIS 4G

HARTLAND TJ

HASTINGS ISLAND PP

HAT CREEK US

HATHAWAY PINES XO

HAUSNA AG

HAWKINS BAR L8

HAYWARD JK

HEALDSBURG NH

HEART MEADOW TJ

HELM HE

HENLEYVILLE WF

HERCULES HR

HERITAGE RANCH BR

HERNDON TK

HICKMAN HC

HIGHWAY CITY TK

HILLCREST FF

HILLSBOROUGH HL

HILMAR HQ

HILTON NG

HOBERGS ZH

HOLLISTER BG

HOLLYDALE PARK NR

HOLMES LJ

HOLY CITY VJ

HOLY CITY VJ

HONCUT FQ

HONEYDEW KU

HONEYDEW KU

HOOPA L1

HOPETON TR

HOPLAND UI

HORNITOS HN

HORSE CORAL FLAT TJ

HUB TT

HUGHSON HG

HUGHSON HG

HUMBOLDT HILL LF

HUME LAKE HK

HUMPHREYS STATION

TK

HUNTER LIG RES JO

HURLETON FQ

HURON HU

HYDESVILLE KV

IGNACIO NM

IGO W1

INDIAN FALLS FP

INVERNESS IN

INYOKERN C9

IONE QF

IOOF PARK NG

IRWIN XX

ISLAND MOUNTAIN 3G

ISLETON P8

JACKASS HILL XR

JACKSON XD

JACKSONVILLE XR

JACOBY CREEK LF

JAMESTOWN YZ

JARBO GAP FM


JEFFERSONVILLE XR

JENNER 5N

JENNY LIND XT

JOHNSON PARK TU

JOLON JO

JONESVILLE FB

JOYCE ISLAND FS

KEDDIE Y3

KELSEY G1

KELSEYVILLE ZK

KENSINGTON KN

KENTFIELD KF

KENWOOD KW

KERMAN TH

KETTENPOM LM

KETTLEMAN CITY KC

KEYES 2X

KEYES 2X

KEYSTONE XR

KING CITY BJ

KING SALMON LF

KINGS CANYON NATIONAL PARK

KG

KINGSBURG KI

KINGSBURG KI

KINGVALE H8

KIRKWOOD WF

KNEELAND KL

KNIGHTS FERRY XN

KNIGHTS LANDING KS

KNIGHTSEN K3

KNOWLES TN

KORBEL KB

KRAMER JUNCTION TD

KYBURZ GY

LA GRANGE LR

LA HONDA LH

LA HONDA LH

LA PORTE IL

LA PURISMA 2B

LA SELVA BEACH VX

LAFAYETTE LY

LAGUNITAS LU

LAKE ALMANOR Q2

LAKE BERRYESSA N7

LAKE DON PEDRO SX

LAKE DON PEDRO CX

LAKE DON PEDRO LR

LAKE MADRONE FQ

LAKE OF THE PINES HM

LAKEHEAD LB

LAKEPORT NJ

LAMONT LT

LANARE TT

LARGO UI

LARKFIELD NR

LARKSPUR LK

LAS CRUCES 2B

LAS DELTA TM

LASSEN CAMP MW

LATHROP LP

LATHROP LP

LATHROP LP

LATON LX

LATON LX

LATROBE HT

LAYTONVILLE W8

LAYTONVILLE W8

LE GRAND LQ

LEBEC LE

LEESVILLE 9S

LEGGETT 5G

LEMOORE TL

LIBERTY FARMS PK

LINCOLN HD

LINCOLN HD

LINDA HP

LINDEN LI

LITTLE GRASS VALLEY

IL

LITTLE NORWAY 8R


LITTLE RIVER QL

LITTLE VALLEY W5

LIVE OAK LO

LIVE OAK LO

LIVERMORE JN

LIVINGSTON LV

LOCH LOMOND ZO

LOCKEFORD LC

LOCKWOOD VW

LODI XF

LODOGA FJ

LOLETA KX

LOLETA KX

LOMA MAR VM

LOMA RICA HP

LOMPICO FE

LOMPOC 2B

LONDON TJ

LONE STAR TK

LONG BARN EB

LONGVALE NZ

LONOAK BJ

LOOMIS LZ

LOOMIS LZ

LOS ALAMOS B4

LOS ALTOS LA

LOS ALTOS HILLS LA

LOS BANOS TM

LOS BERROS AG

LOS GATOS VJ

LOS GATOS VJ

LOS MOLINOS OM

LOS OLIVOS B5

LOS OSOS LG

LOST HILLS LL

LOTUS 8S

LOVELOCK FM

LOWER LAKE ZL

LUCERNE ZI

LUCERNE VALLEY T8

LYONSVILLE PC

LYTTON NC

MAD RIVER KZ

MADERA TN

MADERA TN

MADISON 6P

MAGALIA F3

MAGUNDEN TC

MALAGA TK

MANCHESTER P1

MANILA LF

MANTECA XH

MANTECA XH

MANTON MQ

MAPLE CREEK LF

MARICOPA MF

MARICOPA HEIGHTS TV

MARINA MA

MARINWOOD NQ

MARIPOSA TS

MARSHALL MM

MARSHALL MM

MARSHALL STATION TK

MARTELL QP

MARTINEZ MR

MARTINS BEACH RH

MARYSVILLE HP

MATHER AFB MN

MAXWELL EU

MC ARTHUR UU

MC CANN LM

MC CLELLAN FIELD PS

MC FARLAND MC

MC KINLEYVILLE MV

MC KITTRICK MK

MEADOW LAKES TK

MEADOW VALLEY EX

MEADOW VISTA GJ

MEADOWMONT XB

MENDOCINO QM

MENDOTA MY


MENLO PARK MP

MERCED TR

MERCED FALLS TR

MERIDIAN EK

MERRITT ISLAND PP

METTLER STATION MZ

MI WUK VILLAGE UW

MICHIGAN BLUFF GE

MIDDLETOWN ZM

MIDPINES TS

MILL CREEK MX

MILL VALLEY NK

MILLBRAE MI

MILLVILLE MJ

MILPITAS ML

MINERAL MW

MINKLER SR

MINTURN TN

MIRABLE PARK FV

MIRAMONTE MU

MIRANDA 6G

MISSION DISTRICT SL

MISSION HILLS 2B

MO TRIANGLE TV

MOCCASIN YY

MODESTO XJ

MODESTO XJ

MOJAVE T5

MOKELUMNE HILL QT

MOKELUMNE HILL QT

MOLINO NR

MONMOUTH TT

MONO PINES XR

MONO VISTA XR

MONSON TJ

MONTA VISTA VV

MONTARA VD

MONTE RIO ZR

MONTE SERENO MS

MONTEREY BM

MONTGOMERY CREEK

UT

MOONSTONE BEACH LF

MOOSE CAMP FF

MORAGA MG

MORGAN HILL MH

MORGAN HILL MH

MORRO BAY MB

MOSS BEACH VK

MOSS LANDING MD

MOUNT AUKUM GP

MOUNT AUKUM 8P

MOUNT AUKUM (NORTH)

8P

MOUNT BULLION TS

MOUNT HAMILTON VP

MOUNT HERMON MT

MOUNTAIN RANCH XQ

MOUNTAIN REST TK

MOUNTAIN VIEW VL

MUIR BEACH OW

MUROC TD

MURPHYS XU

MYERS FLAT G6

NAPA NL

NASHVILLE HT

NAVARRO UJ

NAVELENCIA RV

NELSON NA

NEVADA CITY HH

NEW CUYAMA 3N

NEW IDRIA AY

NEWARK NE

NEWBERRY SPRINGS C4

NEWCASTLE GK

NEWMAN XL

NEWVILLE FJ

NICASIO N8

NICE ZN

NICOLAUS NO

NIMSHEW FM

NIPINNAWASEE TQ


NIPOMO B2

NIPOMO B2

NORD FB

NORDEN H8

NORTH COLUMBIA HM

NORTH FORK NT

NORTH HIGHLANDS HI

NORTH SAN JUAN IO

NORTHWOOD ZR

NOVATO NM

NOYO NF

NUBIEBER UV

O'BRIEN LB

O'NEALS ON

OAK RUN OU

OAK RUN OU

OAK SHORES BR

OAK SHORES DC

OAKDALE XN

OAKHURST TQ

OAKLAND JQ

OAKLAND JQ

OAKLEY OK

OAKVILLE OQ

OCCIDENTAL OC

OCCIDENTAL OC

OCEANO OO

ODD FELLOWS EB

OIL CENTER TC

OILDALE TC

OLD CUYAMA TV

OLD RIVER TC

OLD STATION UX

OLEANDER TK

OLEMA OA

OLIVEHURST OL

OMO RANCH HX

ONO V3

OPHIR HB

ORA VISTA FQ

ORANGE COVE OE

ORANGEVALE OV

ORCUTT 4B

ORD BEND FJ

OREGON CITY FM

OREGON HOUSE OH

ORICK OI

ORINDA OR

ORLAND FJ

ORLEANS L2

OROSI OS

OROVILLE FQ

OROVILLE FQ

ORRS HOT SPRINGS NX

OSWALD HP

OUTINGDALE HT

PACHECO PA

PACIFIC GROVE PG

PACIFIC HOUSE HV

PACIFICA RP

PAGES CORNER TK

PAICINES AY

PALERMO IP

PALO CEDRO AO

PANOCHE VALLEY AY

PARADISE FM

PARADISE PINES FM

PARKFIELD KP

PARLIER PE

PASKENTA XP

PASO ROBLES BK

PATTERSON X8

PAYNES CREEK PC

PEACH TREE BJ

PEARDALE HM

PEBBLE BEACH PB

PENN VALLEY IJ

PENNGROVE 9P

PENNINGTON FQ

PENRYN GL

PEPPERWOOD LF


PESCADERO VO

PETALUMA NN

PETALUMA NN

PETALUMA NN

PETERS XT

PETROLIA JV

PETROLIA JV

PHILLIPSVILLE G9

PHILO UK

PIEDMONT PD

PIEDRA SR

PIERCY G7

PIKE CITY IZ

PILOT HILL GN

PINE FLAT SR

PINE GROVE QJ

PINE MOUNTAIN LAKE

XR

PINE RIDGE AU

PINECREST YU

PINEDALE PI

PINEHURST PU

PINNACLES AY

PINOLE PN

PIONEER QK

PIONEER POINT TD

PISMO BEACH PW

PITTSBURG JH

PITTVILLE FF

PLACERVILLE HT

PLANADA PM

PLATINA 8A

PLEASANT GROVE PO

PLEASANT GROVE PO

PLEASANT HILL PH

PLEASANT VALLEY HT

PLEASANTON PL

PLEASANTON PL

PLYMOUTH QS

POINT ARENA NP

POINT REYES PQ

POINT REYES STATION

PQ

POLLOCK PINES HW

POND TX

PONDEROSA SKY RANCH

PC

PONDOSA 1W

POPE VALLEY N5

PORT COSTA DF

PORTOLA VALLEY PV

POTTER VALLEY UM

PRAIRIE CREEK LF

PRATHER PR

PRATTVILLE Q1

PRESIDIO PT

PRESTON NC

PRINCETON EQ

PRINCETON VG

PROBERTA RW

PROJECT CITY WO

PRUNEDALE BT

PULGA F6

PUMPKIN CENTER TC

QUAIL FLAT TJ

QUINCY FP

RACKERBY IK

RAILROAD FLAT QX

RAINBOW TAVERN H8

RAISIN CITY RR

RANCHO CORDOVA RA

RANCHO MURIETA RF

RANCHO TEHAMA WF

RAYMOND RY

RAYMOND RY

RAYMOND RY

RED BANK FN

RED BANK WJ

RED BLUFF FN

RED MOUNTAIN TD

RED TOP C8

REDCREST JW


REDDING FY

REDWAY G2

REDWOOD CITY RC

REDWOOD CREEK LW

REDWOOD ESTATES RE

REDWOOD ESTATES RE

REDWOOD VALLEY UN

REDWOOD VALY L3

REEDLEY RV

REEDLEY RV

RESCUE HY

RHEEM RM

RICHARDSON GROVE

LM

RICHARDSON SPRINGS

FB

RICHFIELD WF

RICHMOND JT

RICHVALE IR

RIDGECREST TD

RIEGO HP

RIO BRAVO TC

RIO DELL NR

RIO DELL NR

RIO DELL JX

RIO DELL JX

RIO LINDA RL

RIO NIDO 9N

RIO OSO RO

RIO VISTA PP

RIPON X4

RIVER PINES QG

RIVERBANK RI

RIVERBANK RI

RIVERDALE RZ

RIVERDALE RZ

RIVERTON HT

ROBBINS ZQ

ROCKLIN RT

ROCKPORT QR

RODEO RQ

ROHNERT PARK RK

ROHNERT PARK (SOUTH)

RK

ROHNERVILLE LF

ROLINDA TK

ROSEDALE TC

ROSEVILLE HS

ROSEVILLE HS

ROSS RS

ROUGH & READY IW

ROUND MOUNTAIN UB

RUMSEY 7P

RUTH JY

RUTHERFORD N6

RYDE PP

RYER ISLAND PP

SACRAMENTO PS

SALIDA ID

SALINAS BT

SALMON CREEK BB

SALYER L4

SAMOA AM

SAN ANDREAS ZT

SAN ANSELMO SW

SAN ARDO AQ

SAN BENANCIO CANYON

BT

SAN BENITO BG

SAN BRUNO RD

SAN CARLOS SC

SAN FRANCISCO RG

SAN GERONIMO GM

SAN GREGORIO VQ

SAN JOAQUIN SJ

SAN JOSE VP

SAN JOSE VP

SAN JOSE VP

SAN JUAN BAUTISTA B1

SAN JUAN BAUTISTA B1

SAN LEANDRO SO

SAN LORENZO SZ


SAN LUCAS AX

SAN LUIS OBISPO BV

SAN MARTIN UA

SAN MATEO SM

SAN MIGUEL KP

SAN PABLO SB

SAN QUENTIN QU

SAN RAFAEL NQ

SAN RAMON SN

SAN SIMEON SP

SAND CITY EW

SANGER SR

SANGER SR

SANGER SR

SANTA BARBARA 5B

SANTA CLARA SA

SANTA CLARA SA

SANTA CRUZ VT

SANTA MARGARITA WZ

SANTA MARGARITA WZ

SANTA MARIA BX

SANTA NELLA GU

SANTA RITA PARK TM

SANTA ROSA NR

SANTA VENTIA NQ

SANTA YNEZ 3B

SARATOGA SG

SARATOGA SG

SARATOGA SG

SAUSALITO NS

SAWMILL FLAT XR

SCHELLVILLE NV

SCIOTS CAMP HT

SCOTIA JU

SCOTTS VALLEY SY

SEACLIFF AP

SEA RANCH P5

SEASIDE SS

SEAVIEW NG

SEBASTOPOL SE

SEBASTOPOL SE

SELBY JT

SELMA TT

SEQUOIA TJ

SEVILLE VE

SHAFTER TE

SHANDON WY

SHASTA W2

SHASTA LAKE VE

SHASTA LAKE CITY VE

SHAVER LAKE SK

SHAWS FLAT XR

SHEEP RANCH XS

SHELL BEACH PW

SHERIDAN SH

SHERMAN ISLAND PP

SHINGLE SPRINGS HZ

SHINGLETOWN WQ

SHIVELY LF

SIEGLER SPRINGS ZH

SIERRA CITY IG

SIERRA CITY HM

SIERRA VILLAGE UW

SILVER FORK HT

SISQUOC B3

SITES PX

SKAGGS SPRINGS NC

SKY LONDA LH

SLOUGHHOUSE QQ

SLY PARK HT

SMARTVILLE SV

SMARTVILLE SV

SMITH CAMP FF

SNELLING SX

SO BEIRIDGE TV

SODA SPRINGS H8

SOLEDAD SL

SOLEDAD SL

SOLVANG 1B

SOMERSET IC

SOMES BAR L6


SONOMA NV

SONOMA NV

SONORA XR

SOQUEL SQ

SOULSBYVILLE YR

SOUTH FORK TQ

SOUTH SAN FRANCISCO

RJ

SPANISH FLAT N7

SPANISH RANCH EX

SPRECKELS SF

SPRINGVILLE VU

SPRUCE POINT LF

SQUAW VALLEY VY

SAINT HELENA NW

STANDARD YR

STANFORD UNIVERSITY

ST

STENT XR

STEVINSON SI

STEWARTS POINT P6

STINSON BEACH BH

STIRLING CITY F2

STOCKTON XT

STOCKTON XT

STOCKTON XT

STONE CORRAL WJ

STONE LAGOON LF

STONYFORD 9S

STORRIE F7

STOUT XR

STRATFORD RX

STRAWBERRY HT

STRAWBERRY X1

STRAWBERRY POINT NQ

STRAWBERRY VALLEY

IS

SUGAR PINE TQ

SUGAR PINE UW

SUISUN FS

SUISUN FS

SULTANA UL

SUMMERHOME PARK NR

SUMMIT CITY FY

SUNNYBRAE LF

SUNNYVALE VB

SUNOL SU

SUTTER SD

SUTTER SD

SUTTER CREEK QI

SUTTER HILL XD

SUTTER ISLAND PP

SWAINS FLAT LF

SYCAMORE PX

TAFT TV

TAFT TV

TAFT (SOUTH) TV

TAFT HEIGHTS TV

TALMAGE UO

TAMARACK XA

TAMARACK PINES HT

TAYLORSVILLE EZ

TEHACHAPI 2T

TEHAMA YT

TEMPLETON BR

TEPUSQUET BX

TERMINOUS XF

TERRA LINDA NQ

THERMALITO FQ

THORNTON TW

THREE ROCKS KK

TIBURON OT

TIERRA BUENA HP

TIVY VALLEY SR

TOADTOWN FM

TOBIN F8

TOCOLOMA LU

TODD VALLEY GE

TOLLHOUSE T1

TOMALES N1

TRACY XV

TRANQUILLITY TI


TRAVER TZ

TRAVIS AFB EE

TRES PINOS 6B

TRIMMER TK

TRINIDAD TB

TRONA TO

TRONA (SOUTH) TO

TUDOR HP

TULARE TY

TUOLUMNE YX

TUPMAN TA

TURLOCK XX

TUTTLETOWN XR

TWAIN Y6

TWAIN HARTE YV

TWIN BRIDGES IE

TWITCHELL ISLAND PP

TWO ROCK NN

TYLER HH

TYLER ISLAND PP

UKIAH NX

UNION CITY UC

UPPER LAKE ZU

VACATION BEACH NG

VACAVILLE PK

VALLECITO XZ

VALLEJO NY

VALLEJO NY

VALLEY ACRES VA

VALLEY FORD BB

VALLEY HOME XN

VALLEY SPRINGS VS

VALLEY SPRINGS VS

VAN ARSDALE VM

VANDENBURG AFB 2B

VERNALIS X3

VERONA HP

VICHY SPRINGS NX

VICTOR VC

VICTORVILLE C5

VILLA GRANDE N9

VINA IA

VINEBURG 8N

VIRGILIA FP

VISALIA VI

VOLCANO QN

VOLTA TM

WALLACE WL

WALNUT CREEK WC

WALNUT GROVE WV

WALNUT GROVE WV

WASCO TX

WASHINGTON II

WATERFORD WT

WATERLOO XT

WATSONVILLE VX

WATSONVILLE VX

WAUKENA WG

WAWONA C6

WEIMAR HF

WEIMAR H9

WEITCHPEC L7

WEOTT JZ

WEST POINT QY

WEST SACRAMENTO WS

WESTEND TD

WESTHAVEN LF

WESTLEY X9

WESTPORT QW

WESTWOOD Q7

WHEATLAND WE

WHEELER RIDGE TV

WHISKEYTOWN WB

WHISPERING PINE ZH

WHITE HALL NN

WHITE PINES XW

WHITETHORN G3

WHITMORE W3

WHITTAKER FOREST TJ

WILDWOOD 8W

WILLIAMS DV


WILLITS NZ

WILLOW CREEK LW

WILLOW SPRINGS XD

WILLOW SPRINGS YR

WILLOWS 9W

WILLOWS 9W

WILSEYVILLE QZ

WILSONIA TJ

WINDSOR WI

WINDSOR WI

WINTERS 7W

WINTERS 7W

WINTON WN

WISHON WU

WITTER SPRINGS ZW

WONDER VALLEY SR

WOODACRE WA

WOODBRIDGE WR

WOODEN VALLEY NL

WOODLAKE WJ

WOODLAND PZ

WOODLEAF FQ

WOODSIDE WD

WYANDOTTE FQ

YANKEE HILL FM

YETTEM YE

YOLO YO

YORKVILLE UP

YOSEMITE YX

YOSEMITE (WEST) T2

YOUNTVILLE YN

YUBA CITY YC

YUBA GAP HB

YUBA GAP H5

ZACA LAKE 3B

ZAMORA PZ

ZENIA G8

A P P E N D I X B

SERVICE CITY ZIP CODES

City Zip Code ACAMPO 95220 AHWAHNEE 93601 AHWAHNEE 93601 ALAMEDA 94501 ALAMEDA 94502 ALAMO 94507 ALBANY 94706 ALBANY 94707 ALBANY 94710 ALBION 95410 ALDERPOINT 95511 ALLEGHANY 95910 ALLENSWORTH 93201 ALLENSWORTH 93219 ALLENSWORTH 93219 ALMANOR 95947 ALPAUGH 93201 ALTA 95701 ALTAVILLE 95221 ALTON 95540 ALVISO 95002 AMADOR CITY 95601 AMBOY 92304 AMERICAN CANYON 94503 AMERICAN CANYON 94503 AMERICAN CANYON 94588 AMERICAN CANYON 94590 ANDERSON 96007

ANDERSON 96007 ANGELS CAMP 95221 ANGELS CAMP 95222 ANGWIN 94508 ANNAPOLIS 95412 ANTELOPE 95843 ANTIOCH 90212 ANTIOCH 90406 ANTIOCH 92626 ANTIOCH 92806 ANTIOCH 94507 ANTIOCH 94509 ANTIOCH 94509 ANTIOCH 94523 ANTIOCH 94531 ANTIOCH 94566 ANTIOCH 97478 APPLEGATE 95703 APTOS 95001 APTOS 95003 ARBUCKLE 95912 ARBUCKLE 95932 ARCATA 95518 ARCATA 95519 ARCATA 95521 ARNOLD 95223 ARNOLD 95223 AROMAS 95004 AROMAS 95004

ARROYO GRANDE 93401 ARROYO GRANDE 93420 ARROYO GRANDE 93421 ARROYO GRANDE 93444 ARROYO GRANDE 93445 ARTOIS 95913 ARTOIS 95913 ARVIN 93203 ATASCADERO 93422 ATASCADERO 93423 ATASCADERO 93442 ATASCADERO 93446 ATHERTON 94027 ATWATER 95301 AUBERRY 93602 AUBURN 95602 AUBURN 95602 AUBURN 95603 AUBURN 95603 AUBURN 95603 AUBURN 95604 AVENAL 93204 AVENAL 93204 AVERY 95224 AVILA BEACH 93424 AVILA BEACH 93449 BADGER 93603 BADGER 93603 BAKERSFIELD 90404


BAKERSFIELD 90503 BAKERSFIELD 91210 BAKERSFIELD 92658 BAKERSFIELD 92887 BAKERSFIELD 93203 BAKERSFIELD 93206 BAKERSFIELD 93220 BAKERSFIELD 93280 BAKERSFIELD 93301 BAKERSFIELD 93302 BAKERSFIELD 93303 BAKERSFIELD 93303 BAKERSFIELD 93304 BAKERSFIELD 93305 BAKERSFIELD 93306 BAKERSFIELD 93307 BAKERSFIELD 93308 BAKERSFIELD 93309 BAKERSFIELD 93309 BAKERSFIELD 93311 BAKERSFIELD 93312 BAKERSFIELD 93313 BAKERSFIELD 93314 BAKERSFIELD 93380 BAKERSFIELD 93381 BAKERSFIELD 93383 BAKERSFIELD 93384 BAKERSFIELD 93387 BAKERSFIELD 93388 BAKERSFIELD 93389 BAKERSFIELD 93390 BALLARD 93463 BALLICO 95303 BANGOR 95914 BANGOR 95914 BANTA 95304 BASS LAKE 93604 BASS LAKE 93669 BAXTER 95701 BAXTER 95722 BAY POINT 94565 BAYSIDE 95524 BEALE AFB 95903 BEAR VALLEY 95222 BEAR VALLEY 95222

BEAR VALLEY 95223 BEAR VALLEY 95223 BELDEN 95915 BELLA VISTA 96008 BELMONT 94002 BELMONT 94002 BELVEDERE 94920 BEN LOMOND 95005 BENICIA 94510 BENICIA 94553 BERKELEY 94618 BERKELEY 94701 BERKELEY 94702 BERKELEY 94703 BERKELEY 94704 BERKELEY 94704 BERKELEY 94705 BERKELEY 94706 BERKELEY 94707 BERKELEY 94707 BERKELEY 94708 BERKELEY 94708 BERKELEY 94709 BERKELEY 94710 BERKELEY 94720 BERRY CREEK 95916 BETHEL ISLAND 94511 BETHEL ISLAND 94513 BIEBER 96009 BIEBER 96130 BIG BEND 96011 BIG SUR 93920 BIGGS 95917 BIOLA 93606 BIRDS LANDING 94512 BLOCKSBURG 95514 BLUE LAKE 95524 BLUE LAKE 95525 BODEGA 94922 BODEGA BAY 94923 BOLINAS 94924 BOONVILLE 95415 BORON 93516 BORON 93516 BOULDER CREEK 95006

BRADLEY 93426 BRADLEY 93426 BRADLEY 93426 BRANSCOMB 95417 BRENTWOOD 94513 BRENTWOOD 94513 BRENTWOOD 94513 BRENTWOOD 94513 BRENTWOOD 94513 BRENTWOOD 94514 BRENTWOOD 94561 BRENTWOOD 94566 BRENTWOOD 94588 BRIDGEVILLE 95526 BRIDGEVILLE 95526 BRISBANE 94005 BROOKDALE 95007 BROOKS 95606 BROWNS VALLEY 95918 BROWNSVILLE 95919 BRUSH CREEK 95916 BUELLTON 93101 BUELLTON 93427 BURLINGAME 94010 BURLINGAME 94011 BURNEY 96013 BURNEY 96130 BURNT RANCH 95527 BURNT RANCH 95546 BURREL 93607 BURSON 95225 BURSON 95225 BUTTE CITY 95920 BUTTE CITY 95920 BUTTE MEADOWS 95942 BUTTONWILLOW 93206 BUTTONWILLOW 93260 BYRON 92626 BYRON 94513 BYRON 94514 BYRON 94514 BYRON 94514 BYRON 94514 CALIFORNIA VALLEY 93453 CALIFORNIA VALLEY 93453


CALISTOGA 94515 CALISTOGA 94515 CALPELLA 95418 CAMBRIA 93428 CAMERON PARK 95682 CAMINO 95709 CAMP CONNELL 95223 CAMP MEEKER 95419 CAMPBELL 95008 CAMPBELL 95008 CAMPBELL 95008 CAMPBELL 95008 CAMPBELL 95009 CAMPBELL 95009 CAMPBELL 95009 CAMPO SECO 95226 CAMPTONVILLE 95922 CAMPTONVILLE 95922 CANTUA CREEK 93608 CANYON 94516 CANYON DAM 95923 CAPAY 95607 CAPAY 95607 CAPITOLA 95010 CARLOTTA 95528 CARMEL 93921 CARMEL 93922 CARMEL 93923 CARMEL 93924 CARMEL VALLEY 93924 CARMICHAEL 95608 CARMICHAEL 95609 CARRISA PLAINS 93276 CARRISA PLAINS 93453 CARRISA PLAINS 93453 CARUTHERS 93609 CASMALIA 93429 CASPAR 95420 CASSEL 96016 CASTRO VALLEY 94541 CASTRO VALLEY 94544 CASTRO VALLEY 94546 CASTRO VALLEY 94546 CASTRO VALLEY 94552 CASTROVILLE 95012

CATHEYS VALLEY 95306 CATHEYS VALLEY 95338 CAYUCOS 93430 CAZADERO 95421 CEDAR RIDGE 95924 CERES 95307 CERES 95351 CHALLENGE 95925 CHALLENGE 95925 CHESTER 96020 CHICO 95926 CHICO 95927 CHICO 95928 CHICO 95929 CHICO 95973 CHICO 95973 CHINESE CAMP 95309 CHOLAME 93431 CHOLAME 93461 CHOWCHILLA 93610 CHOWCHILLA 93610 CHUALAR 93925 CITRUS HEIGHTS 95610 CITRUS HEIGHTS 95621 CLARKSBURG 95612 CLAYTON 94517 CLAYTON 94566 CLEARLAKE 95422 CLEARLAKE OAKS 95423 CLEARLAKE PARK 95424 CLEMENTS 95220 CLEMENTS 95227 CLIPPER MILLS 95930 CLOVERDALE 95425 CLOVERDALE 95425 CLOVIS 93611 CLOVIS 93612 CLOVIS 93613 CLOVIS 93619 CLOVIS 93706 CLOVIS 93720 CLOVIS 93725 CLOVIS 95834 CLYDE 94520 COALINGA 93210

COALINGA 93210 COALINGA 93210 COARSEGOLD 93614 COBB 95426 COHASSET 95973 COLFAX 95713 COLFAX 95736 COLLEGE CITY 95912 COLMA 94014 COLMA 94015 COLOMA 95613 COLUMBIA 95310 COLUSA 95932 COMPTCHE 95427 CONCORD 94518 CONCORD 94519 CONCORD 94520 CONCORD 94520 CONCORD 94521 CONCORD 94522 CONCORD 94523 CONCORD 94524 COOL 95614 COPPEROPOLIS 95228 CORCORAN 93212 CORCORAN 93212 CORCORAN 93212 CORCORAN 93221 CORCORAN 93230 CORNING 96021 CORNING 96021 CORNING 96022 CORTE MADERA 94925 CORTE MADERA 94948 CORTE MADERA 94976 COSTA MESA 92626 COTATI 94928 COTATI 94931 COTTONWOOD 96022 COTTONWOOD 96022 COULTERVILLE 95311 COULTERVILLE 95311 COURTLAND 95615 COVELO 95428 COYOTE 95013


CRESCENT CITY 95531 CRESCENT MILLS 95934 CRESSEY 95312 CRESTON 93432 CROCKETT 94525 CROWS LANDING 95313 CUMMINGS 95585 CUPERTINO 95014 CUPERTINO 95015 CUPERTNIO 95014 CUTLER 93615 CUTTEN 95534 CUYAMA 93252 CUYAMA 93254 DAGGETT 92327 DALY CITY 94014 DALY CITY 94015 DANVILLE 94005 DANVILLE 94506 DANVILLE 94526 DANVILLE 94526 DANVILLE 94526 DANVILLE 94526 DAVENPORT 95017 DAVIS 91789 DAVIS 95616 DAVIS 95616 DAVIS 95617 DEER PARK 94576 DEL REY 93616 DEL REY 93657 DELEVAN 95988 DELHI 95315 DENAIR 95316 DENAIR 95316 DERBY ACRES 93224 DERBY ACRES 93268 DIABLO 94520 DIABLO 94526 DIABLO 94528 DIAMOND SPRINGS 95619 DIAMOND SPRINGS 95675 DILLON BEACH 94929 DILLON BEACH 94929 DINUBA 93271

DINUBA 93618 DINUBA 93618 DINUBA 93662 DISCOVERY BAY 94514 DIXON 95615 DIXON 95620 DIXON 95620 DIXON 95662 DIXON 95694 DOBBINS 95935 DOBBINS 95962 DORRINGTON 95223 DOS PALOS 93620 DOS PALOS 93620 DOS PALOS 95340 DOS RIOS 95429 DOUGLAS FLAT 95229 DOWNIEVILLE 95936 DRYTOWN 95699 DUBLIN 94566 DUBLIN 94568 DUBLIN 94568 DUBLIN 94568 DUBLIN 94568 DUNCANS MILLS 95430 DUNLAP 93621 DUNNIGAN 95937 DURHAM 95926 DURHAM 95938 DUSTIN ACRES 93268 DUTCH FLAT 95714 EARLIMART 93219 EAST NICOLAUS 95659 EAST PALO ALTO 94303 EAST PALO ALTO 94303 EDISON 93220 EDWARDS 93523 EL CERRITO 94530 EL DORADO 95623 EL DORADO HILLS 95762 EL DORADO HILLS 95762 EL GRANADA 94018 EL MACERO 95618 EL NIDO 95317 EL PORTAL 95318

EL SOBRANTE 94803 EL SOBRANTE 94806 ELK 95432 ELK CREEK 95939 ELK GROVE 95624 ELK GROVE 95757 ELK GROVE 95758 ELK GROVE 95828 ELK GROVE 95829 ELMIRA 95625 ELVERTA 95626 ELVERTA 95626 ELVERTA 95626 EMERALD HILLS 94062 EMERYVILLE 94601 EMERYVILLE 94608 EMIGRANT GAP 95715 EMIGRANT GAP 95715 EMPIRE 95319 ESCALON 95320 ESPARTO 95607 ESPARTO 95627 EUREKA 90274 EUREKA 95501 EUREKA 95502 EUREKA 95503 EUREKA 95521 EUREKA 98101 FAIR OAKS 95628 FAIRFAX 94930 FAIRFIELD 94533 FAIRFIELD 94534 FAIRFIELD 94534 FAIRFIELD 94535 FAIRFIELD 94585 FAIRFIELD 95687 FALL RIVER MILLS 96028 FALLON 94952 FARMINGTON 95230 FARMINGTON 95230 FEATHER FALLS 95940 FELLOWS 93224 FELTON 95018 FERNBRIDGE 95540 FERNDALE 95536


FIDDLETOWN 95629 FIDDLETOWN 95629 FIELDBROOK 95519 FIELDBROOK 95521 FIELDBROOK 95525 FIELDS LANDING 95537 FINLEY 95435 FIREBAUGH 93622 FIREBAUGH 93622 FIREBAUGH 93622 FISH CAMP 93623 FISH CAMP 93623 FIVE POINTS 93624 FLOURNOY 96029 FOLSOM 95630 FOLSOM 95630 FOLSOM 95763 FORBESTOWN 95941 FORBESTOWN 95941 FOREST GLEN 96041 FOREST KNOLLS 94933 FOREST RANCH 95942 FORESTHILL 95631 FORESTVILLE 95436 FORT BRAGG 95437 FORT BRAGG 95456 FORT SEWARD 95542 FORTUNA 95540 FOSTER CITY 94403 FOSTER CITY 94404 FOWLER 93625 FREEDOM 95019 FREMONT 94536 FREMONT 94537 FREMONT 94538 FREMONT 94538 FREMONT 94539 FREMONT 94555 FREMONT 94583 FRENCH CAMP 95231 FRENCH CAMP 95336 FRENCH GULCH 96033 FRESNO 90707 FRESNO 93612 FRESNO 93650

FRESNO 93657 FRESNO 93668 FRESNO 93701 FRESNO 93702 FRESNO 93703 FRESNO 93704 FRESNO 93705 FRESNO 93706 FRESNO 93710 FRESNO 93710 FRESNO 93711 FRESNO 93720 FRESNO 93721 FRESNO 93722 FRESNO 93722 FRESNO 93725 FRESNO 93726 FRESNO 93726 FRESNO 93727 FRESNO 93727 FRESNO 93728 FRESNO 93729 FRESNO 93740 FRESNO 93760 FRESNO 93776 FRESNO 93778 FRESNO 93778 FRESNO 93792 FRESNO 95816 FRIANT 93626 FRIANT 93626 FRIANT 93626 FULTON 95439 GALT 95632 GALT 95632 GALT 95632 GARBERVILLE 95501 GARBERVILLE 95542 GARBERVILLE 95542 GARBERVILLE 96127 GARDEN VALLEY 95633 GEORGETOWN 95634 GEORGETOWN 95634 GERBER 96035 GEYSERVILLE 92081

GEYSERVILLE 95441 GILROY 95020 GILROY 95021 GLEN ELLEN 95442 GLENCOE 95232 GLENHAVEN 95443 GLENN 95943 GOLD RIVER 95670 GOLD RUN 95717 GONZALES 93926 GOODYEARS BAR 95944 GRANITE BAY 95746 GRASS VALLEY 95945 GRASS VALLEY 95949 GRASS VALLEY 95959 GRASS VALLEY 95960 GRATON 95444 GRAYSON 95360 GRAYSON 95363 GRAYSON 95387 GREENBRAE 94904 GREENFIELD 93927 GREENVILLE 95947 GREENWOOD 95635 GRIDLEY 95948 GRIMES 95950 GRIZZLY FLATS 95636 GRIZZLY FLATS 95684 GROVELAND 95321 GROVELAND 95321 GROVER BEACH 93433 GROVER BEACH 93483 GUADALUPE 93434 GUADALUPE 93434 GUALALA 95445 GUERNEVILLE 95446 GUERNEVILLE 95471 GUINDA 95637 GUSTINE 95322 GUSTINE 95322 HALCYON 93420 HALF MOON BAY 94019 HAMILTON CITY 95951 HANFORD 93230 HANFORD 93232


HARMONY 93435 HAT CREEK 96040 HATHAWAY PINES 95233 HAWKINS BAR 95527 HAWKINS BAR 95563 HAYWARD 94540 HAYWARD 94541 HAYWARD 94542 HAYWARD 94542 HAYWARD 94543 HAYWARD 94544 HAYWARD 94544 HAYWARD 94544 HAYWARD 94545 HAYWARD 94545 HAYWARD 94545 HAYWARD 94546 HAYWARD 94552 HAYWARD 96064 HEALDSBURG 95448 HELM 93627 HERCULES 94547 HICKMAN 95323 HIDDEN VALLEY LAKE 95467 HILLSBOROUGH 94010 HILMAR 95324 HOLLISTER 95023 HOLLISTER 95023 HOLLISTER 95024 HOLT 95234 HONEYDEW 95545 HOOPA 95546 HOOPA 95547 HOOPA 95573 HOPLAND 95449 HORNITOS 95325 HUGHSON 95326 HUME 93628 HURON 93210 HURON 93234 HURON 93245 HYDESVILLE 95547 IGO 96047 INVERNESS 94937

INYOKERN 93526 INYOKERN 93527 INYOKERN 93555 IONE 95640 IRVINE 92612 ISLETON 95641 JACKSON 92629 JACKSON 95642 JACKSON 95647 JACKSON 99210 JAMESTOWN 95327 JENNER 95450 JOHNSON PARK 96013 JOLON 93928 KEDDIE 95971 KELSEY 95667 KELSEYVILLE 95451 KENSINGTON 94706 KENSINGTON 94707 KENSINGTON 94707 KENSINGTON 94708 KENTFIELD 94901 KENTFIELD 94904 KENWOOD 95409 KENWOOD 95452 KERMAN 93630 KERMAN 93631 KETTLEMAN CITY 93234 KETTLEMAN CITY 93239 KEYES 95328 KING CITY 93930 KING CITY 93930 KING CITY 93930 KINGS CANYON 93633 KINGS CANYON 93633 KINGSBURG 93631 KINGSBURG 93631 KINGSBURG 93631 KNEELAND 95549 KNIGHTS FERRY 95361 KNIGHTS LANDING 95645 KNIGHTS LANDING 95645 KNIGHTS LANDING 95645 KNIGHTSEN 94548 KORBEL 95550

KYBURZ 95720 LA GRANGE 95329 LA GRANGE 95329 LA GRANGE 95329 LA HONDA 94020 LA HONDA 94020 LA PORTE 95981 LA SELVA BEACH 95076 LAFAYETTE 94549 LAGUNITAS 94938 LAKE ALMANOR 96020 LAKE ALMANOR 96137 LAKE ALMANOR 96137 LAKE BERRYESSA 94558 LAKEHEAD 96051 LAKEPORT 90267 LAKEPORT 95453 LAMONT 93241 LARKSPUR 94904 LARKSPUR 94939 LARKSPUR 94977 LATHROP 95330 LATON 93242 LATON 93242 LAYTONVILLE 95417 LAYTONVILLE 95454 LAYTONVILLE 95490 LE GRAND 95333 LEBEC 93243 LEBEC 93243 LEGGETT 95585 LEMOORE 93245 LEMOORE 93656 LINCOLN 95648 LINCOLN 95648 LINDEN 95236 LINDEN 95236 LITTLE NORWAY 95721 LITTLE NORWAY 95735 LITTLE RIVER 95456 LITTLE VALLEY 96056 LIVE OAK 95816 LIVE OAK 95953 LIVERMORE 92660 LIVERMORE 94513


LIVERMORE 94550 LIVERMORE 94550 LIVERMORE 94550 LIVERMORE 94551 LIVERMORE 94551 LIVERMORE 94551 LIVERMORE 94551 LIVERMORE 94551 LIVERMORE 94588 LIVINGSTON 95334 LOCH LOMOND 95426 LOCH LOMOND 95461 LOCKEFORD 95237 LOCKWOOD 93932 LODI 95240 LODI 95241 LODI 95242 LOLETA 95551 LOMA MAR 94021 LOMPOC 93436 LOMPOC 93437 LOMPOC 93438 LONG BARN 95335 LOOMIS 95650 LOS ALAMOS 93440 LOS ALAMOS 93441 LOS ALTOS 94022 LOS ALTOS 94022 LOS ALTOS 94024 LOS ALTOS HILLS 94022 LOS ALTOS HILLS 94024 LOS BANOS 93635 LOS BANOS 93635 LOS GATOS 95030 LOS GATOS 95030 LOS GATOS 95030 LOS GATOS 95031 LOS GATOS 95032 LOS GATOS 95032 LOS GATOS 95032 LOS GATOS 95033 LOS GATOS 95033 LOS GATOS 95033 LOS MOLINOS 96055 LOS OLIVOS 93441

LOS OSOS 93401 LOS OSOS 93402 LOS OSOS 93405 LOS OSOS 93412 LOST HILLS 93249 LOTUS 95651 LOWER LAKE 95457 LUCERNE 95458 LUCERNE VALLEY 92356 MAD RIVER 95552 MAD RIVER 95552 MADERA 93637 MADERA 93638 MADERA 93638 MADERA 93639 MADISON 95653 MAGALIA 95954 MANCHESTER 95459 MANTECA 95336 MANTECA 95337 MANTECA 95366 MANTON 96059 MANTON 96059 MARICOPA 93252 MARICOPA 93252 MARINA 93933 MARIPOSA 95338 MARIPOSA 95338 MARKLEEVILLE 96120 MARSHALL 94940 MARTELL 95642 MARTELL 95654 MARTINEZ 94553 MARTINEZ 94553 MARYSVILLE 95661 MARYSVILLE 95901 MARYSVILLE 95901 MARYSVILLE 95903 MARYSVILLE 95991 MARYSVILLE 95992 MAXWELL 95955 MC ARTHUR 96056 MC FARLAND 93205 MC FARLAND 93250 MC FARLAND 93350

MC KITTRICK 93251 MCARTHUR 96056 MCARTHUR 96056 MCCLELLAN 95652 MCKINLEYVILLE 95519 MCKINLEYVILLE 95521 MEADOW VALLEY 95656 MEADOW VALLEY 95956 MEADOW VALLEY 95971 MEADOW VISTA 95722 MENDOCINO 95460 MENDOTA 93640 MENLO PARK 94025 MENLO PARK 94027 MENLO PARK 94028 MERCED 95329 MERCED 95340 MERCED 95341 MERCED 95344 MERCED 95348 MERIDIAN 95957 MERIDIAN 95957 METTLER STATION 93301 METTLER STATION 93313 MI WUK VILLAGE 95346 MIDDLETOWN 95461 MIDDLETOWN 95461 MIDDLETOWN 95467 MIDPINES 95345 MILL CREEK 96061 MILL VALLEY 94941 MILL VALLEY 94941 MILL VALLEY 94942 MILLBRAE 94030 MILLVILLE 96062 MILPITAS 94583 MILPITAS 94583 MILPITAS 95035 MILPITAS 95035 MILPITAS 95036 MINERAL 96061 MINERAL 96063 MIRAMONTE 93641 MIRANDA 95553 MODESTO 95350


MODESTO 95351 MODESTO 95352 MODESTO 95353 MODESTO 95354 MODESTO 95355 MODESTO 95355 MODESTO 95356 MODESTO 95357 MODESTO 95358 MOJAVE 93502 MOKELUMNE HILL 95245 MONTARA 94037 MONTE RIO 95462 MONTE SERENO 95030 MONTEREY 93924 MONTEREY 93940 MONTEREY 93942 MONTEREY 93944 MONTGOMERY CREEK 96001 MONTGOMERY CREEK 96065 MONTGOMERY CREEK 96084 MORAGA 94556 MORGAN HILL 95037 MORGAN HILL 95038 MORRO BAY 93442 MORRO BAY 93443 MOSS BEACH 94038 MOSS LANDING 93950 MOSS LANDING 95039 MOUNT AUKUM 95656 MOUNT HERMON 95018 MOUNT HERMON 95041 MOUNTAIN HOUSE 95391 MOUNTAIN RANCH 95246 MOUNTAIN RANCH 95246 MOUNTAIN VIEW 94039 MOUNTAIN VIEW 94040 MOUNTAIN VIEW 94040 MOUNTAIN VIEW 94041 MOUNTAIN VIEW 94043 MUIR BEACH 94965 MURPHYS 95247

MYERS FLAT 95554 NAPA 94558 NAPA 94558 NAPA 94559 NAVARRO 95463 NELSON 95958 NEVADA CITY 95949 NEVADA CITY 95959 NEW CUYAMA 93254 NEWARK 94538 NEWARK 94560 NEWARK 94560 NEWBERRY SPRINGS 92365 NEWCASTLE 95658 NEWMAN 95350 NEWMAN 95360 NEWMAN 95360 NICASIO 94946 NICE 95464 NICOLAUS 95659 NIPOMO 93420 NIPOMO 93444 NIPOMO 93444 NIPOMO 93454 NORDEN 95724 NORDEN 95724 NORTH EDWARDS 93523 NORTH FORK 93643 NORTH HIGHLANDS 95652 NORTH HIGHLANDS 95660 NORTH SAN JUAN 95960 NORTH SAN JUAN 95960 NORTH SAN JUAN 95960 NOVATO 94945 NOVATO 94945 NOVATO 94947 NOVATO 94947 NOVATO 94948 NOVATO 94949 NOVATO 94954 NOVATO 94998 NUBIEBER 96068 O NEALS 93645 OAK RUN 96069 OAKDALE 95361

OAKDALE 95361 OAKDALE 95361 OAKHURST 93644 OAKHURST 95389 OAKLAND 94601 OAKLAND 94602 OAKLAND 94603 OAKLAND 94604 OAKLAND 94605 OAKLAND 94606 OAKLAND 94607 OAKLAND 94607 OAKLAND 94608 OAKLAND 94609 OAKLAND 94610 OAKLAND 94611 OAKLAND 94612 OAKLAND 94612 OAKLAND 94613 OAKLAND 94614 OAKLAND 94615 OAKLAND 94618 OAKLAND 94619 OAKLAND 94621 OAKLAND 94623 OAKLAND 94623 OAKLAND 94623 OAKLAND 94704 OAKLAND 94705 OAKLAND 95816 OAKLEY 94513 OAKLEY 94561 OAKVILLE 94562 OCCIDENTAL 95465 OCEANO 93445 OLD STATION 96071 OLEMA 94950 OLIVEHURST 95901 OLIVEHURST 95918 OLIVEHURST 95961 ORANGE COVE 93646 ORANGE COVE 93646 ORANGE COVE 93675 ORANGEVALE 95662 ORANGEVALE 95662


ORCUTT 93440 ORCUTT 93454 ORCUTT 93455 OREGON HOUSE 95962 ORICK 95555 ORINDA 94523 ORINDA 94563 ORLAND 95963 ORLAND 95963 ORLAND 95963 ORLAND 96130 ORLEANS 95556 OROSI 93647 OROVILLE 95965 OROVILLE 95966 OROVILLE 95966 PACHECO 94553 PACIFIC GROVE 93950 PACIFIC HOUSE 95726 PACIFICA 94044 PAICINES 95043 PALERMO 95968 PALO ALTO 94034 PALO ALTO 94066 PALO ALTO 94301 PALO ALTO 94303 PALO ALTO 94303 PALO ALTO 94304 PALO ALTO 94304 PALO ALTO 94305 PALO ALTO 94306 PALO CEDRO 96073 PARADISE 95967 PARADISE 95969 PARLIER 93648 PARLIER 93727 PASKENTA 96074 PASO ROBLES 93446 PASO ROBLES 93447 PASO ROBLES 93465 PATTERSON 95363 PAYNES CREEK 96075 PEBBLE BEACH 93953 PENN VALLEY 95946 PENN VALLEY 95946

PENNGROVE 94951 PENRYN 95663 PESCADERO 94060 PETALUMA 93003 PETALUMA 94952 PETALUMA 94952 PETALUMA 94953 PETALUMA 94954 PETROLIA 95558 PHILLIPSVILLE 95559 PHILO 95466 PIEDMONT 94602 PIEDMONT 94610 PIEDMONT 94611 PIEDMONT 94618 PIERCY 95587 PIERCY 95587 PIKE CITY 95960 PILOT HILL 95664 PILOT HILL 95664 PINE GROVE 95665 PINE GROVE 95666 PINECREST 95314 PINECREST 95364 PINEDALE 93650 PINEHURST 93641 PINOLE 94564 PINOLE 94803 PIONEER 95666 PISMO BEACH 93448 PISMO BEACH 93449 PITTSBURG 94553 PITTSBURG 94565 PLACERVILLE 95667 PLANADA 95365 PLATINA 96076 PLATINA 96076 PLEASANT GROVE 95668 PLEASANT GROVE 95668 PLEASANT HILL 94523 PLEASANTON 94538 PLEASANTON 94566 PLEASANTON 94566 PLEASANTON 94566 PLEASANTON 94566

PLEASANTON 94566 PLEASANTON 94566 PLEASANTON 94568 PLEASANTON 94588 PLEASANTON 94588 PLEASANTON 94588 PLEASANTON 94588 PLEASANTON 94588 PLUMAS LAKE 95961 PLYMOUTH 95669 POINT ARENA 95468 POINT REYES 94956 POINT REYES STATION 94956 POLLOCK PINES 95726 POPE VALLEY 94567 PORT COSTA 94569 PORTOLA VALLEY 94028 POTTER VALLEY 95469 PRATHER 93651 PRESIDIO 94129 PRINCETON 95970 PRINCETON 95970 PRINCETON 95970 PROBERTA 96078 PULGA 95965 QUINCY 95971 RACKERBY 95972 RAIL ROAD FLAT 95232 RAIL ROAD FLAT 95245 RAIL ROAD FLAT 95248 RAIL ROAD FLAT 95248 RAISIN 93652 RAISIN CITY 93652 RANCHO CORDOVA 95655 RANCHO CORDOVA 95670 RANCHO CORDOVA 95742 RAYMOND 93653 RAYMOND 93653 RED BLUFF 96080 RED BLUFF 96080 RED TOP 95340 REDCREST 95569 REDDING 96001 REDDING 96002


REDDING 96003 REDDING 96049 REDDING 96099 REDDING 97405 REDWAY 95560 REDWOOD CITY 94061 REDWOOD CITY 94062 REDWOOD CITY 94063 REDWOOD CITY 94063 REDWOOD CITY 94064 REDWOOD CITY 94065 REDWOOD ESTATES 95044 REDWOOD ESTATES 95044 REDWOOD VALLEY 95470 REEDLEY 93654 REEDLEY 93654 REEDLEY 93654 REEDLEY 99999 RESCUE 95672 RESCUE 95682 RICHMOND 90221 RICHMOND 94530 RICHMOND 94801 RICHMOND 94802 RICHMOND 94803 RICHMOND 94804 RICHMOND 94805 RICHMOND 94806 RICHMOND 94806 RICHMOND 94807 RICHMOND 94808 RICHMOND 94850 RICHVALE 95974 RIDGECREST 93555 RIDGECREST 93555 RIO DELL 95562 RIO LINDA 95661 RIO LINDA 95673 RIO NIDO 95471 RIO OSO 95674 RIO VISTA 94520 RIO VISTA 94571 RIO VISTA 94571 RIPON 95366 RIPON 95366

RIVER PINES 95675 RIVERBANK 95361 RIVERBANK 95363 RIVERBANK 95367 RIVERBANK 95367 RIVERDALE 93656 RIVERDALE 93656 ROBBINS 95676 ROBBINS 95676 Rocklin 95677 ROCKLIN 95677 ROCKLIN 95765 ROCKLIN 95775 RODEO 94572 RODEO 94577 ROHNERT PARK 94927 ROHNERT PARK 94928 ROHNERT PARK 94931 ROSEVILLE 95661 ROSEVILLE 95678 ROSEVILLE 95678 ROSEVILLE 95678 ROSEVILLE 95746 ROSEVILLE 95747 ROSEVILLE 95841 ROSS 94957 ROUGH AND READY 95975 ROUND MOUNTAIN 96084 RUMSEY 95679 RUTH 95526 RUTH 95526 RUTH 95551 RUTHERFORD 94573 RYDE 95680 SACRAMENTO 94298 SACRAMENTO 95628 SACRAMENTO 95758 SACRAMENTO 95812 SACRAMENTO 95814 SACRAMENTO 95814 SACRAMENTO 95815 SACRAMENTO 95816 SACRAMENTO 95816 SACRAMENTO 95816 SACRAMENTO 95816

SACRAMENTO 95816 SACRAMENTO 95816 SACRAMENTO 95816 SACRAMENTO 95817 SACRAMENTO 95818 SACRAMENTO 95818 SACRAMENTO 95819 SACRAMENTO 95820 SACRAMENTO 95821 SACRAMENTO 95822 SACRAMENTO 95823 SACRAMENTO 95824 SACRAMENTO 95825 SACRAMENTO 95825 SACRAMENTO 95826 SACRAMENTO 95827 SACRAMENTO 95828 SACRAMENTO 95829 SACRAMENTO 95830 SACRAMENTO 95831 SACRAMENTO 95832 SACRAMENTO 95833 SACRAMENTO 95834 SACRAMENTO 95834 SACRAMENTO 95834 SACRAMENTO 95834 SACRAMENTO 95834 SACRAMENTO 95835 SACRAMENTO 95836 SACRAMENTO 95837 SACRAMENTO 95837 SACRAMENTO 95838 SACRAMENTO 95841 SACRAMENTO 95842 SACRAMENTO 95843 SACRAMENTO 95864 SAINT HELENA 94574 SAINT HELENA 94574 SALIDA 95368 SALINAS 93901 SALINAS 93902 SALINAS 93905 SALINAS 93905 SALINAS 93906 SALINAS 93907


SALINAS 93908 SALINAS 93912 SALINAS 93915 SALYER 95563 SAMOA 95564 SAN ANDREAS 95249 SAN ANSELMO 94960 SAN ARDO 93450 SAN BRUNO 94066 SAN CARLOS 94070 SAN CARLOS 94070 SAN CARLOS 94303 SAN FRANCISCO 94080 SAN FRANCISCO 94101 SAN FRANCISCO 94102 SAN FRANCISCO 94103 SAN FRANCISCO 94104 SAN FRANCISCO 94105 SAN FRANCISCO 94105 SAN FRANCISCO 94105 SAN FRANCISCO 94106 SAN FRANCISCO 94106 SAN FRANCISCO 94107 SAN FRANCISCO 94108 SAN FRANCISCO 94108 SAN FRANCISCO 94109 SAN FRANCISCO 94110 SAN FRANCISCO 94111 SAN FRANCISCO 94111 SAN FRANCISCO 94112 SAN FRANCISCO 94114 SAN FRANCISCO 94115 SAN FRANCISCO 94116 SAN FRANCISCO 94117 SAN FRANCISCO 94118 SAN FRANCISCO 94119 SAN FRANCISCO 94121 SAN FRANCISCO 94122 SAN FRANCISCO 94123 SAN FRANCISCO 94123 SAN FRANCISCO 94124 SAN FRANCISCO 94127 SAN FRANCISCO 94128 SAN FRANCISCO 94129 SAN FRANCISCO 94131

SAN FRANCISCO 94132 SAN FRANCISCO 94133 SAN FRANCISCO 94133 SAN FRANCISCO 94134 SAN FRANCISCO 94143 SAN FRANCISCO 94158 SAN GERONIMO 94963 SAN GREGORIO 94074 SAN JOAQUIN 93660 SAN JOSE 94538 SAN JOSE 95002 SAN JOSE 95008 SAN JOSE 95013 SAN JOSE 95035 SAN JOSE 95037 SAN JOSE 95101 SAN JOSE 95102 SAN JOSE 95110 SAN JOSE 95110 SAN JOSE 95110 SAN JOSE 95111 SAN JOSE 95112 SAN JOSE 95113 SAN JOSE 95113 SAN JOSE 95116 SAN JOSE 95117 SAN JOSE 95118 SAN JOSE 95119 SAN JOSE 95119 SAN JOSE 95119 SAN JOSE 95120 SAN JOSE 95121 SAN JOSE 95122 SAN JOSE 95123 SAN JOSE 95124 SAN JOSE 95124 SAN JOSE 95125 SAN JOSE 95125 SAN JOSE 95125 SAN JOSE 95126 SAN JOSE 95126 SAN JOSE 95126 SAN JOSE 95126 SAN JOSE 95127 SAN JOSE 95128

SAN JOSE 95129 SAN JOSE 95129 SAN JOSE 95130 SAN JOSE 95131 SAN JOSE 95132 SAN JOSE 95133 SAN JOSE 95133 SAN JOSE 95134 SAN JOSE 95135 SAN JOSE 95136 SAN JOSE 95138 SAN JOSE 95139 SAN JOSE 95140 SAN JOSE 95141 SAN JOSE 95148 SAN JOSE 95150 SAN JOSE 95151 SAN JOSE 95153 SAN JOSE 95153 SAN JOSE 95154 SAN JOSE 95160 SAN JOSE 95160 SAN JOSE 95161 SAN JOSE 95192 SAN JUAN BAUTISTA 95045 SAN LEANDRO 94577 SAN LEANDRO 94577 SAN LEANDRO 94578 SAN LEANDRO 94579 SAN LEANDRO 94580 SAN LORENZO 94580 SAN LUCAS 93930 SAN LUCAS 93954 SAN LUIS OBISPO 90071 SAN LUIS OBISPO 90603 SAN LUIS OBISPO 93401 SAN LUIS OBISPO 93402 SAN LUIS OBISPO 93403 SAN LUIS OBISPO 93405 SAN LUIS OBISPO 93406 SAN LUIS OBISPO 93408 SAN LUIS OBISPO 93420 SAN LUIS OBISPO 93433 SAN LUIS OBISPO 93449 SAN MARTIN 95046


SAN MATEO 94025 SAN MATEO 94062 SAN MATEO 94401 SAN MATEO 94401 SAN MATEO 94402 SAN MATEO 94403 SAN MATEO 94404 SAN MATEO 94404 SAN MATEO 94404 SAN MIGUEL 93446 SAN MIGUEL 93451 SAN MIGUEL 93451 SAN MIGUEL 93451 SAN MIGUEL 93451 SAN PABLO 94806 SAN QUENTIN 94964 SAN RAFAEL 92264 SAN RAFAEL 94901 SAN RAFAEL 94901 SAN RAFAEL 94903 SAN RAFAEL 94904 SAN RAFAEL 94912 SAN RAFAEL 94913 SAN RAFAEL 94915 SAN RAFAEL 94915 SAN RAFAEL 94956 SAN RAFAEL 95816 SAN RAMON 94506 SAN RAMON 94582 SAN RAMON 94583 SAN RAMON 94583 SAN RAMON 94583 SAN RAMON 94583 SAN RAMON 94583 SAN SIMEON 93452 SAND CITY 93955 SANGER 93657 SANGER 93711 SANTA BARBARA 93101 SANTA BARBARA 93103 SANTA BARBARA 93105 SANTA BARBARA 93110 SANTA CLARA 95050 SANTA CLARA 95050 SANTA CLARA 95050

SANTA CLARA 95051 SANTA CLARA 95053 SANTA CLARA 95054 SANTA CRUZ 95060 SANTA CRUZ 95062 SANTA CRUZ 95062 SANTA CRUZ 95062 SANTA CRUZ 95062 SANTA CRUZ 95064 SANTA CRUZ 95065 SANTA CRUZ 95066 SANTA MARGARITA 93422 SANTA MARGARITA 93453 SANTA MARIA 92674 SANTA MARIA 92693 SANTA MARIA 93454 SANTA MARIA 93454 SANTA MARIA 93455 SANTA MARIA 93456 SANTA MARIA 93457 SANTA MARIA 93458 SANTA NELLA 95322 SANTA ROSA 95401 SANTA ROSA 95402 SANTA ROSA 95403 SANTA ROSA 95404 SANTA ROSA 95405 SANTA ROSA 95406 SANTA ROSA 95407 SANTA ROSA 95407 SANTA ROSA 95409 SANTA ROSA 95492 SANTA YNEZ 93460 SARATOGA 95070 SARATOGA 95070 SARATOGA 95071 SAUSALITO 94965 SAUSALITO 94966 SCOTIA 95565 SCOTTS VALLEY 95060 SCOTTS VALLEY 95065 SCOTTS VALLEY 95066 SEA RANCH 95445 SEA RANCH 95497 SEA RANCH 95497

SEASIDE 93955 SEBASTOPOL 95401 SEBASTOPOL 95472 SEBASTOPOL 95473 SELMA 90720 SELMA 93622 SELMA 93622 SELMA 93657 SELMA 93662 SELMA 93706 SELMA 93721 SEVILLE 93292 SHAFTER 93263 SHANDON 93451 SHANDON 93461 SHASTA 96087 SHASTA LAKE 96003 SHASTA LAKE 96019 SHASTA LAKE 96089 SHAVER LAKE 93602 SHAVER LAKE 93664 SHEEP RANCH 95250 SHELL BEACH 93449 SHERIDAN 95681 SHINGLE SPRINGS 95682 SHINGLE SPRINGS 95682 SHINGLETOWN 96088 SIERRA CITY 96125 SISQUOC 93454 SISQUOC 93455 SITES 95979 SMARTVILLE 95977 SMARTVILLE 95977 SNELLING 95369 SNELLING 95369 SODA SPRINGS 95724 SODA SPRINGS 95724 SODA SPRINGS 95728 SODA SPRINGS 95728 SOLEDAD 93960 SOLVANG 93463 SOLVANG 93464 SOMERSET 95684 SOMES BAR 95568 SONOMA 95476


SONOMA 95476 SONORA 92651 SONORA 95370 SONORA 95379 SOQUEL 95073 SOULSBYVILLE 95372 SOUTH DOS PALOS 93665 SOUTH SAN FRANCISCO 94080 SOUTH SAN FRANCISCO 94083 SOUTH SAN FRANCISCO 94112 SPRECKELS 93962 SQUAW VALLEY 93646 SQUAW VALLEY 93675 STANDARD 95373 STANFORD 94305 STEVINSON 95374 STEWARTS POINT 95480 STINSON BEACH 94970 STIRLING CITY 95978 STOCKTON 90212 STOCKTON 90404 STOCKTON 94545 STOCKTON 95201 STOCKTON 95202 STOCKTON 95202 STOCKTON 95203 STOCKTON 95204 STOCKTON 95204 STOCKTON 95204 STOCKTON 95205 STOCKTON 95206 STOCKTON 95206 STOCKTON 95207 STOCKTON 95207 STOCKTON 95208 STOCKTON 95209 STOCKTON 95209 STOCKTON 95210 STOCKTON 95211 STOCKTON 95212 STOCKTON 95213 STOCKTON 95213

STOCKTON 95215 STOCKTON 95219 STOCKTON 95219 STOCKTON 95234 STOCKTON 95236 STOCKTON 95240 STOCKTON 95267 STOCKTON 95336 STONYFORD 95979 STONYFORD 95979 STORRIE 95980 STRATFORD 93266 STRAWBERRY 95375 STRAWBERRY VALLEY 95981 SUISUN 94533 SUISUN 94534 SUISUN 94585 SUISUN 95685 SUISUN CITY 94534 SUISUN CITY 94585 SUISUN CITY 94585 SUISUN CITY 94585 SULTANA 93666 SUNNYVALE 94085 SUNNYVALE 94086 SUNNYVALE 94087 SUNNYVALE 94088 SUNNYVALE 94089 SUNNYVALE 95014 SUNOL 94586 SUTTER 95982 SUTTER CREEK 95685 TAFT 92647 TAFT 93268 TAFT 93453 TAYLORSVILLE 95934 TAYLORSVILLE 95983 TEHACHAPI 93561 TEHAMA 96090 TEMPLETON 93465 THORNTON 95686 TIBURON 94920 TOLLHOUSE 93667 TOMALES 94971

TRACY 92110 TRACY 92691 TRACY 92707 TRACY 94520 TRACY 94550 TRACY 94577 TRACY 94588 TRACY 95201 TRACY 95206 TRACY 95304 TRACY 95304 TRACY 95304 TRACY 95376 TRACY 95376 TRACY 95376 TRACY 95377 TRACY 95377 TRACY 95378 TRACY 95378 TRACY 95385 TRACY 95385 TRACY 95391 TRACY 95391 TRANQUILLITY 93668 TRAVER 93673 TRAVIS AFB 94535 TRES PINOS 95075 TRINIDAD 95570 TRONA 93562 TULARE 93274 TUOLUMNE 95379 TUPMAN 93276 TURLOCK 95380 TURLOCK 95380 TURLOCK 95382 TWAIN 95984 TWAIN HARTE 95383 TWIN BRIDGES 95735 UKIAH 95482 UKIAH 95482 UNION CITY 94587 UNION CITY 94587 UPPER LAKE 95485 UPPER LAKE 95493 VACAVILLE 95687


VACAVILLE 95688 VACAVILLE 95696 VALLECITO 95229 VALLECITO 95251 VALLEJO 94503 VALLEJO 94503 VALLEJO 94583 VALLEJO 94589 VALLEJO 94590 Vallejo 94590 VALLEJO 94590 VALLEJO 94591 Vallejo 94591 VALLEJO 94592 VALLEY ACRES 93268 VALLEY FORD 94972 VALLEY FORD 94972 VALLEY HOME 95361 VALLEY SPRINGS 95252 VALLEY SPRINGS 95255 VERNALIS 95385 VERNALIS 95385 VICTOR 95253 VICTORVILLE 92394 VILLA GRANDE 95486 VINA 96092 VISALIA 93277 VISALIA 93279 VISALIA 93291 VISALIA 93292 VOLCANO 95689 WALLACE 95254 WALNUT CREEK 94595 WALNUT CREEK 94595 WALNUT CREEK 94596 WALNUT CREEK 94596 WALNUT CREEK 94597 WALNUT CREEK 94597 WALNUT CREEK 94597 WALNUT CREEK 94598 WALNUT CREEK 94598 WALNUT GROVE 95690 WALNUT GROVE 95690 WALNUT GROVE 95690

WALNUT GROVE 95690 WASCO 93280 WASHINGTON 95986 WATERFORD 95386 WATSONVILLE 95019 WATSONVILLE 95076 WATSONVILLE 95076 WATSONVILLE 95076 WATSONVILLE 95077 WAUKENA 93274 WAUKENA 93282 WAWONA 95389 WEIMAR 95713 WEIMAR 95736 WEITCHPEC 95546 WEOTT 95571 WEST POINT 95255 WEST POINT 95255 WEST POINT 95404 WEST SACRAMENTO 95605 WEST SACRAMENTO 95691 WEST SACRAMENTO 95691 West Sacramento 95691 WEST SACRAMENTO 95695 WEST SACRAMENTO 95695 WEST SACRAMENTO 95798 WEST SACRAMENTO 95828 WEST SACRAMENTO 95961 WESTLEY 95387 WESTPORT 95488 WESTWOOD 96137 WESTWOOD 96137 WHEATLAND 95692 WHEATLAND 95692 WHISKEYTOWN 96095 WHITE PINES 95223 WHITETHORN 95589 WHITETHORN 95589 WHITMORE 96096 WILDWOOD 96076 WILLIAMS 95987 WILLITS 95490 WILLOW CREEK 95573 WILLOW CREEK 96039

WILLOWS 95988 WILLOWS 95988 WILSEYVILLE 95257 WILSEYVILLE 95257 WINDSOR 95492 WINTERS 95694 WINTERS 95694 WINTERS 95695 WINTON 95301 WINTON 95388 WISHON 93669 WITTER SPRINGS 95493 WOODACRE 94973 WOODBRIDGE 95258 WOODBRIDGE 95258 WOODLAKE 93286 WOODLAND 95695 WOODLAND 95695 WOODLAND 95776 WOODSIDE 94026 WOODSIDE 94061 WOODSIDE 94062 YETTEM 93670 YOLO 95697 YORKVILLE 95494 YOSEMITE NATIONAL PARK 95389 YOSEMITE NATIONAL PARK 95389 YOUNTVILLE 94599 YUBA CITY 95661 YUBA CITY 95901 YUBA CITY 95991 YUBA CITY 95992 YUBA CITY 95993 YUBA CITY 95994 ZAMORA 95698 ZENIA 95595

A P P E N D I X 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