FERC Form

THIS FILING IS

Item 1:

☑ An Initial (Original) Submission

☐ Resubmission No.




FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature

Exact Legal Name of Respondent (Company)

PACIFIC GAS AND ELECTRIC COMPANY

Year/Period of Report

End of:

2018

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose
FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q)is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
Who Must Submit
Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities and Licensees Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).
Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
1. one million megawatt hours of total annual sales,
2. 100 megawatt hours of annual sales for resale,
3. 500 megawatt hours of annual power exchanges delivered, or
4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).

What and Where to Submit

Submit FERC Forms 1 and 3-Q electronically through the forms submission software. Retain one copy of each report for your files. Any electronic submission must be created by using the forms submission software provided free by the Commission at its web site: http://www.ferc.gov/docs-filing/forms/form-1/elec-subm-soft.asp. The software is used to submit the electronic filing to the Commission via the Internet.
The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
Secretary
Federal Energy Regulatory Commission 888 First Street, NE
Washington, DC 20426

For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

The CPA Certification Statement should:

Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and

Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

Schedules	Pages
Comparative Balance Sheet	110-113
Statement of Income	114-117
Statement of Retained Earnings	118-119
Statement of Cash Flows	120-121
Notes to Financial Statements	122-123

The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.
“In connection with our regular examination of the financial statements of for the year ended on which we have reported separately under date of , we have also reviewed schedules of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.
Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. To further that effort, new selections, “Annual Report to Stockholders,” and “CPA Certification Statement” have been added to the dropdown “pick list” from which companies must choose when eFiling. Further instructions are found on the Commission’s website at http://www.ferc.gov/help/how-to.asp.
Federal, State and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from http://www.ferc.gov/docs-filing/forms/form-1/form-1.pdf and http://www.ferc.gov/docs-filing/forms.asp#3Q-gas .

When to Submit
FERC Forms 1 and 3-Q must be filed by the following schedule:
1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
Where to Send Comments on Public Reporting Burden.
The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.
Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
For any resubmissions, submit the electronic filing using the form submission software only. Please explain the reason for the resubmission in a footnote to the data field.
Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.

Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS

Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
'Person' means an individual or a corporation;
'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;

'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......

"project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered

'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development -costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.

Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may be rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the -proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports salt be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10

"Sec. 309.

The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).

FERC FORM NO.

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER

IDENTIFICATION

01 Exact Legal Name of Respondent

PACIFIC GAS AND ELECTRIC COMPANY

02 Year/ Period of Report

End of:

2018

03 Previous Name and Date of Change (If name changed during year)

PACIFIC GAS AND ELECTRIC COMPANY

04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

77 BEALE STREET, P.O BOX 770000, SAN FRANCISCO, CA 94177

05 Name of Contact Person

RACHEL PETERSEN

06 Title of Contact Person

DIRECTOR, CORP ACCOUNTING

07 Address of Contact Person (Street, City, State, Zip Code)

77 BEALE STREET, Mail Code B7A, P.O BOX 770000, SAN FRANCISCO, CA 94177

08 Telephone of Contact Person, Including Area Code

(415) 973-1700

09 This Report is An Original / A Resubmission

(1)

☑ An Original

(2)

☐ A Resubmission

10 Date of Report (Mo, Da, Yr)

04/16/2019

Annual Corporate Officer Certification

The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

DAVID THOMASON

02 Title

VP, CONTROLLER, UTILITY CFO

03 Signature

DAVID THOMASON

04 Date Signed (Mo, Da, Yr)

04/16/2019

Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

LIST OF SCHEDULES (Electric Utility)
Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".
Line No.	Title of Schedule (a)	Reference Page No. (b)	Remarks (c)
	ScheduleIdentificationAbstract Identification	1
	ScheduleListOfSchedulesAbstract List of Schedules	2
1	ScheduleGeneralInformationAbstract General Information	101
2	ScheduleControlOverRespondentAbstract Control Over Respondent	102
3	ScheduleCorporationsControlledByRespondentAbstract Corporations Controlled by Respondent	103
4	ScheduleOfficersAbstract Officers	104
5	ScheduleDirectorsAbstract Directors	105
6	ScheduleInformationOnFormulaRatesAbstract Information on Formula Rates	106
7	ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year	108
8	ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet	110
9	ScheduleStatementOfIncomeAbstract Statement of Income for the Year	114
10	ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Year	118
11	ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows	120
12	ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements	122
13	ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Other Comp Income, Comp Income, and Hedging Activities	122a
14	ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep	200
15	ScheduleNuclearFuelMaterialsAbstract Nuclear Fuel Materials	202
16	ScheduleElectricPlantInServiceAbstract Electric Plant in Service	204
17	ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others	213
18	ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use	214
19	ScheduleConstructionWorkInProgressElectricAbstract Construction Work in Progress-Electric	216
20	ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract Accumulated Provision for Depreciation of Electric Utility Plant	219
21	ScheduleInvestmentsInSubsidiaryCompaniesAbstract Investment of Subsidiary Companies	224
22	ScheduleMaterialsAndSuppliesAbstract Materials and Supplies	227
23	ScheduleAllowanceInventoryAbstract Allowances	228
24	ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses	230a
25	ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs	230b
26	ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs	231
27	ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets	232
28	ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits	233
29	ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes	234
30	ScheduleCapitalStockAbstract Capital Stock	250
31	ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital	253
32	ScheduleCapitalStockExpenseAbstract Capital Stock Expense	254b
33	ScheduleLongTermDebtAbstract Long-Term Debt	256
34	ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax	261
35	ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract Taxes Accrued, Prepaid and Charged During the Year	262
36	ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract Accumulated Deferred Investment Tax Credits	266
37	ScheduleOtherDeferredCreditsAbstract Other Deferred Credits	269
38	ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property	272
39	ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract Accumulated Deferred Income Taxes-Other Property	274
40	ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract Accumulated Deferred Income Taxes-Other	276
41	ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities	278
42	ScheduleElectricOperatingRevenuesAbstract Electric Operating Revenues	300
43	ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1)	302
44	ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules	304
45	ScheduleSalesForResaleAbstract Sales for Resale	310
46	ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses	320
47	SchedulePurchasedPowerAbstract Purchased Power	326
48	ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others	328
49	ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs	331
50	ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others	332
51	ScheduleMiscellaneousGeneralExpensesAbstract Miscellaneous General Expenses-Electric	335
52	ScheduleDepreciationDepletionAndAmortizationAbstract Depreciation and Amortization of Electric Plant (Account 403, 404, 405)	336
53	ScheduleRegulatoryCommissionExpensesAbstract Regulatory Commission Expenses	350
54	ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract Research, Development and Demonstration Activities	352
55	ScheduleDistributionOfSalariesAndWagesAbstract Distribution of Salaries and Wages	354
56	ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses	356
57	ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements	397
58	SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services	398
59	ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load	400
60	ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load	400a
61	ScheduleElectricEnergyAccountAbstract Electric Energy Account	401a
62	ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output	401b
63	ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics	402
64	ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics	406
65	SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics	408
66	ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages	410
0	ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants)	414
67	ScheduleTransmissionLineStatisticsAbstract Transmission Line Statistics Pages	422
68	ScheduleTransmissionLinesAddedAbstract Transmission Lines Added During Year	424
69	ScheduleSubstationsAbstract Substations	426
70	ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract Transactions with Associated (Affiliated) Companies	429
71	FootnoteDataAbstract Footnote Data	450
	StockholdersReportsAbstract Stockholders' Reports (check appropriate box)
	Stockholders' Reports Check appropriate box: ☐ Two copies will be submitted ☐ No annual report to stockholders is prepared

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept. David S. Thomason, Vice President, Controller, and CFO 77 Beale Street, B11H San Francisco, CA 94105 David CEO 123 Main St
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized. California - October 10, 1905 State of Incorporation: CA Date of Incorporation: 1905-10-10 Incorporated Under Special Law: YES - CA Law Type of organization if not Incorporated : AAA
3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased. Not Applicable. (a) Name of Receiver or Trustee Holding Property of the Respondent: ABC (b) Date Receiver took Possession of Respondent Property: 1905-10-10 (c) Authority by which the Receivership or Trusteeship was created: ABC (d) Date when possession by receiver or trustee ceased: 1999-10-01
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated. Electricity and natural gas distribution, electric generation, procurement, and transmission, and natural gas procurement, transportation, and storage. State of California only.
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements? (1) ☐ Yes 10/01/1999 (2) ☑ No

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

CORPORATIONS CONTROLLED BY RESPONDENT
Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests. Definitions See the Uniform System of Accounts for a definition of control. Direct control is that which is exercised without interposition of an intermediary. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.	NameOfCompanyControlledByRespondent Name of Company Controlled (a)	CompanyControlledByRespondentKindOfBusinessDescription Kind of Business (b)	VotingStockOwnedByRespondentPercentage Percent Voting Stock Owned (c)	FootnoteReferences Footnote Ref. (d)
1	Eureka Energy Company	Formerly managed	100
2		the Utility's Utah coal
3		venture. Currently holds
4		part of the Marre Ranch
5		property in San Luis
6		Obispo County.
7	Midway Power, LLC	Formed to be the ownership	100
8		entity for real estate and
9		licenses for a suspended
10		development project.
11	Natural Gas Corporation of California (NGC)	Entity used to amortize	100
12		remaining Gas
13		Exploration and
14		Development Account
15		assets.
16	FuelCo LLC	Formed to share costs and	50	1
17		reduce fuel acquisition
18		costs.
19	Pacific Energy Fuels Company	Formed to own and	100
20		finance the nuclear fuel
21		inventory previously owned
22		by Pacific Energy Trust
23	Standard Pacific Gas Line Incorporated	Engaged in the transportation	85.71
24		of natural gas in California.
25		The Utility owns an 85.71%
26		interest and Chevron Pipe
27		Line Company owns the
28		remaining 14.29% interest.
29	Morro Bay Mutual Water Company	Formed to jointly hold	50	2
30		property rights in connection
31		with the divestiture of the
32		Morro Bay Power Plant.
33	Moss Landing Mutual Water Company	Formed to jointly hold	33	3
34		propert rights in connection
35		with the divestiture of the
36		Moss Landing Power Plant.
37	Alaska Gas Exploration Associates	Formed to explore,	100	4
38		develop, produce, acquire,
39		and market oil and gas
40		reserves in Alaska.
41	STARS Alliance, LLC	Formed to increase efficiency	25	5
42		and reduce costs related to
43		the operation of the members
44		nuclear generation
45		facilities.

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

OFFICERS
Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.	OfficerTitle Title (a)	OfficerName Name of Officer (b)	OfficerSalary Salary for Year (c)	DateOfficerIncumbencyStarted Date Started in Period (d)	DateOfficerIncumbencyEnded Date Ended in Period (e)
1	Senior VP, Human Resources and Chief Diversity Officer	Dinyar B. Mistry	504,167	2018-01-01	2019-01-01
2	Senior VP, Gas Operations	Jesus Soto, Jr.	474,333	2018-01-01	2019-01-01
3	Senior VP and Chief Ethics and Compliance Officer and	Julie M. Kane	470,197	2018-01-01	2019-01-01
4	Deputy General Council	Julie M. John	470,197	2018-01-01	2019-01-01
5	Senior VP and Chief Customer Officer	Loraine M. Giammona	461,667	2018-01-01	2019-01-01
6	Senior VP, Energy Supply and Policy	Steven Malnight	460,633	2018-01-01	2019-01-01
7	Senior VP, Electric Operation	Patrick M. Hogan	422,500	2018-01-01	2019-01-01
8	Senior VP, Energy Policy and Procurement	Fong Wan	410,833	2018-01-01	2019-01-01
9	Senior VP and Chief Information Officer	Kathleen B. Kay	387,333	2018-01-01	2019-01-01
10	Senior VP and Deputy General Counsel of the Utility	Janet C. Loduca	370,850	2018-01-01	2019-01-01
11	Vice President, Chief Financial Officer and Controller	David S. Thomason	320,833	2018-01-01	2019-01-01
12	Special Advisor	Nickolas Stavropoulos	618,667	2018-01-01	2019-01-01
13	Senior VP and Cheif Information Officer	Karen A. Austin	477,833	2018-01-01	2019-01-01

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

DIRECTORS
Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), abbreviated titles of the directors who are officers of the respondent. Designate members of the Executive Committee in column (c) and the Chairman of the Executive Committee in column (d).
Line No.	NameAndTitleOfDirector Name (and Title) of Director (a)	PrincipalBusinessAddress Principal Business Address (b)	MemberOfTheExecutiveCommittee Member of the Executive Committee (c)	ChairmanOfTheExecutiveCommittee Chairman of the Executive Committee (d)
1	Lewis Chew ***	c/o PG&E Corporation	false	true
2		77 Beale Street, 32nd Floor
3		San Francisco, CA 94105
4	Fred J. Fowler	c/o PG&E Corporation	true	true
5		77 Beale Street, 32nd Floor
6		San Francisco, CA 94105
7	Richard C. Kelly **	c/o PG&E Corporation	true	true
8		77 Beale Street, 32nd Floor
9		San Francisco, CA 94105
10	Roger H. Kimmel	c/o PG&E Corporation	false	true
11		77 Beale Street, 32nd Floor
12		San Francisco, CA 94105
13	Richard A. Meserve ***	c/o PG&E Corporation	true	true
14		77 Beale Street, 32nd Floor
15		San Francisco, CA 94105
16	Forrest E. Miller ***	c/o PG&E Corporation	true	true
17		77 Beale Street, 32nd Floor
18		San Francisco, CA 94105
19	Benito Minicucci	c/o PG&E Corporation	true	true
20		77 Beale Street, 32nd Floor
21		San Francisco, CA 94105
22	Eric D. Mullins	c/o PG&E Corporation	true	true
23		77 Beale Street, 32nd Floor
24		San Francisco, CA 94105
25	Rosendo G. Parra	c/o PG&E Corporation	true	true
26		77 Beale Street, 32nd Floor
27		San Francisco, CA 94105
28	Barbara L. Rambo ***	c/o PG&E Corporation	true	true
29		77 Beale Street, 32nd Floor
30		San Francisco, CA 94105
31	Anne Shen Smith ***	c/o PG&E Corporation	true	true
32		77 Beale Street, 32nd Floor
33		San Francisco, CA 94105
34	Geisha J. Williams	c/o PG&E Corporation	true	true
35		77 Beale Street, 32nd Floor
36		San Francisco, CA 94105

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

INFORMATION ON FORMULA RATES
Does the respondent have formula rates?		☐ Yes ☑ No
Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.	RateScheduleTariffNumber FERC Rate Schedule or Tariff Number (a)	ProceedingDocketNumber FERC Proceeding (b)
1	NOT APPLICABLE	100

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?			☐ Yes ☑ No
If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.	AccessionNumber Accession No. (a)	DocumentDate Document Date / Filed Date (b)	DocketNumber Docket No. (c)	DescriptionOfFiling Description (d)	RateScheduleTariffNumber Formula Rate FERC Rate Schedule Number or Tariff Number (e)
1	1000	01/01/2017	NOT APPLICABLE	Annual	234

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

INFORMATION ON FORMULA RATES - Formula Rate Variances
If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.	PageNumberOfFormulaRateVariances Page No(s). (a)	ScheduleOfFormulaRateVariances Schedule (b)	ColumnOfFormulaRateVariances Column (c)	LineNumberOfFormulaRateVariances Line No. (d)
1	24	NOT APPLICABLE	ABC	35

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

IMPORTANT CHANGES DURING THE QUARTER/YEAR
Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments. State the estimated annual effect and nature of any important wage scale changes during the year. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Page 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest. (Reserved.) If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.



1. ORGANIZATION Buckeye Partners, L.P. (“Buckeye”) is a master limited partnership organized in 1986 under the laws of the state of Delaware. Buckeye’s principal line of business is the transportation, terminalling, storage and handling of refined petroleum products in the United States and the Caribbean, for integrated oil companies, refined product marketing companies and end users of petroleum products, on a fee basis through facilities owned and jointly owned by Buckeye. Buckeye conducts all of its operations through subsidiary entities, which include Buckeye Pipe Line Transportation Company, LLC (the “Company”), as well as joint ventures. Buckeye owns a 100% ownership interest in the Company. The Company is the sole member (100% owner) of Buckeye Linden Pipe Line Company LLC. Buckeye Linden Pipe Line Company LLC was formed as a Delaware limited liability company on October 16, 2013 and commenced operations in June 2014. Buckeye Linden Pipe Line Company LLC provides b-directional pipeline transportation service between Perth Amboy, New Jersey and Linden, New Jersey, thereby offering shippers enhanced connectivity and service optionality in the New York Harbor.

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlant Utility Plant (101-106, 114)	200	86,967,343,203	81,000,792,691
3	ConstructionWorkInProgress Construction Work in Progress (107)	200	2,562,027,669	2,470,588,868
4	UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3)		89,529,370,872	83,471,381,559
5	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)	200	37,353,599,037	35,680,789,356
6	UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5)		52,175,771,835	47,790,592,203
7	NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)	202	233,949,233	261,763,030
8	NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9	NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3)		427,381,622	416,084,176
10	SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4)		2,359,998,526	2,265,141,307
11	NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6)		0	0
12	AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)	202	2,630,936,779	2,505,050,242
13	NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12)		390,392,602	437,938,271
14	UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13)		52,566,164,437	48,228,530,474
15	OtherElectricPlantAdjustments Utility Plant Adjustments (116)
16	GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117)		55,907,325	55,907,325
17	OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS
18	NonutilityProperty Nonutility Property (121)		29,171,933	30,929,381
19	AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122)
20	InvestmentInAssociatedCompanies Investments in Associated Companies (123)
21	InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1)	224	50,082,345	48,859,887
23	NoncurrentPortionOfAllowances Noncurrent Portion of Allowances	228	355,147,460	195,017,512
24	OtherInvestments Other Investments (124)		10,942	10,942
25	SinkingFunds Sinking Funds (125)
26	DepreciationFund Depreciation Fund (126)
27	AmortizationFundFederal Amortization Fund - Federal (127)
28	OtherSpecialFunds Other Special Funds (128)		2,729,720,970	2,863,247,030
29	SpecialFunds Special Funds (Non Major Only) (129)		545,313,624	553,022,543
30	DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175)		165,299,922	102,130,395
31	DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176)
32	OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31)		3,874,747,196	3,793,217,690
33	CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS
34	CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130)
35	Cash Cash (131)		71,327,413	57,718,289
36	SpecialDeposits Special Deposits (132-134)		6,886,597	6,951,064
37	WorkingFunds Working Fund (135)		147,415	146,305
38	TemporaryCashInvestments Temporary Cash Investments (136)		1,220,000,000	385,000,000
39	NotesReceivable Notes Receivable (141)
40	CustomerAccountsReceivable Customer Accounts Receivable (142)		1,273,685,556	1,368,326,668
41	OtherAccountsReceivable Other Accounts Receivable (143)		3,128,236,294	1,294,343,299
42	AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144)		56,198,372	64,476,202
43	NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145)
44	AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146)		34,585,453	21,355,991
45	FuelStock Fuel Stock (151)	227	1,566,341	1,375,066
46	FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152)	227	100	100
47	Residuals Residuals (Elec) and Extracted Products (153)	227	100	100
48	PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154)	227	442,660,312	365,624,033
49	Merchandise Merchandise (155)	227	100	100
50	OtherMaterialsAndSupplies Other Materials and Supplies (156)	227	100	100
51	NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157)	202/227	0	0
52	AllowanceInventoryAndWithheld Allowances (158.1 and 158.2)	228	396,185,501	419,851,065
53	NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances	228	355,147,460	195,017,512
54	StoresExpenseUndistributed Stores Expense Undistributed (163)	227	0	0
55	GasStoredCurrent Gas Stored Underground - Current (164.1)		108,986,991	113,465,206
56	LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57	Prepayments Prepayments (165)		305,102,547	227,100,005
58	AdvancesForGas Advances for Gas (166-167)
59	InterestAndDividendsReceivable Interest and Dividends Receivable (171)		3,281,579
60	RentsReceivable Rents Receivable (172)
61	AccruedUtilityRevenues Accrued Utility Revenues (173)		1,000,028,952	945,999,103
62	MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174)		102,494,054	14,376,070
63	DerivativeInstrumentAssets Derivative Instrument Assets (175)		208,704,537	129,373,589
64	DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175)		165,299,922	102,130,395
65	DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176)
66	DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67	CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66)		7,727,233,788	4,989,381,644
68	DeferredDebitsAbstract DEFERRED DEBITS
69	UnamortizedDebtExpense Unamortized Debt Expenses (181)		124,158,942	131,251,529
70	ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1)	230a	0
71	UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2)	230b	68,809,105	3,683,889
72	OtherRegulatoryAssets Other Regulatory Assets (182.3)	232	5,845,482,579	5,018,800,793
73	PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183)		162,540	82,918
74	PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1)
75	OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2)
76	ClearingAccounts Clearing Accounts (184)		174,950	3,237,868
77	TemporaryFacilities Temporary Facilities (185)
78	MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186)	233	26,073,137	55,551,664
79	DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187)
80	ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188)	352
81	UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189)		93,374,528	97,418,150
82	AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190)	234	5,025,590,626	1,728,161,422
83	UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191)
84	DeferredDebits Total Deferred Debits (lines 69 through 83)		11,183,826,407	7,038,188,233
85	AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84)		75,407,879,153	64,105,225,366

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	ProprietaryCapitalAbstract PROPRIETARY CAPITAL
2	CommonStockIssued Common Stock Issued (201)	250	1,321,874,045	1,321,874,045
3	PreferredStockIssued Preferred Stock Issued (204)	250	257,994,575	257,994,575
4	CapitalStockSubscribed Capital Stock Subscribed (202, 205)
5	StockLiabilityForConversion Stock Liability for Conversion (203, 206)
6	PremiumOnCapitalStock Premium on Capital Stock (207)		1,805,194,230	1,805,194,230
7	OtherPaidInCapital Other Paid-In Capital (208-211)	253	6,780,547,928	6,735,547,928
8	InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212)	252
9	DiscountOnCapitalStock (Less) Discount on Capital Stock (213)	254	6,916,899	6,916,899
10	CapitalStockExpense (Less) Capital Stock Expense (214)	254b	28,951,886	28,951,886
11	RetainedEarnings Retained Earnings (215, 215.1, 216)	118	2,884,435,643	9,712,977,993
12	UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1)	118	58,010,567	56,608,615
13	ReacquiredCapitalStock (Less) Reaquired Capital Stock (217)	250
14	NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218)
15	AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219)	122(a)(b)	986,708	6,290,667
16	ProprietaryCapital Total Proprietary Capital (lines 2 through 15)		12,955,180,361	19,747,402,038
17	LongTermDebtAbstract LONG-TERM DEBT
18	Bonds Bonds (221)	256	18,387,100,000	18,032,100,000
19	ReacquiredBonds (Less) Reaquired Bonds (222)	256	11,000,003
20	AdvancesFromAssociatedCompanies Advances from Associated Companies (223)	256	7,000,007
21	OtherLongTermDebt Other Long-Term Debt (224)	256	18,000,010
22	UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225)		13,404,631	14,860,769
23	UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226)		76,509,009	80,156,440
24	LongTermDebt Total Long-Term Debt (lines 18 through 23)		18,323,995,622	17,966,804,329
25	OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES
26	ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227)		9,012,994	17,990,411
27	AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1)
28	AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2)		14,641,225,188	1,003,439,991
29	AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3)		2,040,734,062	2,025,769,027
30	AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4)		1,434,278,826	1,039,213,260
31	AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229)
32	LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities		88,211,315	57,007,082
33	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges
34	AssetRetirementObligations Asset Retirement Obligations (230)		5,994,342,481	4,899,104,864
35	OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34)		24,207,804,866	9,042,524,635
36	CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES
37	NotesPayable Notes Payable (231)		3,135,000,001	800,000,001
38	AccountsPayable Accounts Payable (232)		2,651,188,423	2,402,987,144
39	NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233)
40	AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234)		38,940,769	22,050,491
41	CustomerDeposits Customer Deposits (235)		235,799,401	231,822,866
42	TaxesAccrued Taxes Accrued (236)	262	360,498,405	433,396,782
43	InterestAccrued Interest Accrued (237)		234,978,351	220,498,682
44	DividendsDeclared Dividends Declared (238)		16,235,704	2,319,386
45	MaturedLongTermDebt Matured Long-Term Debt (239)
46	MaturedInterest Matured Interest (240)
47	TaxCollectionsPayable Tax Collections Payable (241)		30,123,144	34,679,077
48	MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242)		411,182,395	692,014,936
49	ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243)		1,682,542	12,512,046
50	DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244)		109,769,265	88,095,705
51	LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities		88,211,315	57,007,082
52	DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245)
53	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54	CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53)		7,137,187,085	4,883,370,034
55	DeferredCreditsAbstract DEFERRED CREDITS
56	CustomerAdvancesForConstruction Customer Advances for Construction (252)		359,612,163	423,431,367
57	AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255)	266	108,383,883	114,033,790
58	DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256)
59	OtherDeferredCredits Other Deferred Credits (253)	269	227,311,425	208,094,334
60	OtherRegulatoryLiabilities Other Regulatory Liabilities (254)	278	3,496,782,247	3,876,105,498
61	UnamortizedGainOnReacquiredDebt Unamortized Gain on Reaquired Debt (257)		716,895	862,920
62	AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281)	272	307	307
63	AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282)		7,973,787,674	7,394,379,151
64	AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283)		617,116,725	448,217,063
65	DeferredCredits Total Deferred Credits (lines 56 through 64)		12,783,711,319	12,465,124,430
66	LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)		75,407,879,253	64,105,225,466

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

STATEMENT OF INCOME
Quarterly Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter. If additional columns are needed, place them in a footnote. Annual or Quarterly if applicable Do not report fourth quarter data in columns (e) and (f) Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility columnin a similar manner to a utility department. Spread the amount(s) over lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. Use page 122 for important notes regarding the statement of income for any account thereof. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purches, and a summary of the adjustments made to balance sheet, income, and expense accounts. If any notes appearing in the report to stokholders are applicable to the Statement of Income, such notes may be included at page 122. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.	Title of Account (a)	(Ref.) Page No. (b)	Total Current Year to Date Balance for Quarter/Year (c)	Total Prior Year to Date Balance for Quarter/Year (d)	Current 3 Months Ended - Quarterly Only - No 4th Quarter (e)	Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f)	Electric Utility Current Year to Date (in dollars) (g)	Electric Utility Previous Year to Date (in dollars) (h)	Gas Utiity Current Year to Date (in dollars) (i)	Gas Utility Previous Year to Date (in dollars) (j)	Other Utility Current Year to Date (in dollars) (k)	Other Utility Previous Year to Date (in dollars) (l)
1	UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME
2	OperatingRevenues Operating Revenues (400)	300	17,337,575,325	17,477,273,258			13,086,062,407	13,283,628,752	4,251,512,918	4,193,644,506	0	0
3	OperatingExpensesAbstract Operating Expenses
4	OperationExpense Operation Expenses (401)	320	21,090,929,970	9,354,586,213			18,919,388,088	7,014,966,243	2,171,541,872	2,339,619,950	10	20
5	MaintenanceExpense Maintenance Expenses (402)	320	1,698,634,311	1,473,178,225			1,071,056,781	959,259,070	627,577,520	513,919,135	10	20
6	DepreciationExpense Depreciation Expense (403)	336	2,708,898,400	2,520,662,622			2,121,424,880	1,980,795,695	587,473,510	539,866,907	10	20
7	DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1)	336					100
8	AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405)	336	323,697,675	332,006,690			225,407,275	237,269,411	98,290,390	94,737,259	10	20
9	AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406)	336
10	AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)		2,113,770	116,111			2,113,770	116,111
11	AmortizationOfConversionExpenses Amort. of Conversion Expenses (407.2)
12	RegulatoryDebits Regulatory Debits (407.3)			629,795				629,795
13	RegulatoryCredits (Less) Regulatory Credits (407.4)
14	TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1)	262	632,365,632	592,757,485			475,321,400	449,084,479	157,044,222	143,672,986	10	20
15	IncomeTaxesOperatingIncome Income Taxes - Federal (409.1)	262	4,236,134	10,252,653			4,236,133	10,252,653	1
16	IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1)	262	13,470,011	108,797,147			112,005,442	105,092,246	98,535,441	3,704,881	10	20
17	ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1)	234, 272	864,342,003	208,874,972			738,531,553	275,512,268	125,810,460	66,637,276	10	20
18	ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1)	234, 272	2,478,874,964	718,959,065			2,388,974,856	713,495,770	89,900,108	5,463,295
19	InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4)	266
20	GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6)		580,002	13,324,707			580,002	2,517,330		10,807,377
21	LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7)			270,691				270,691
22	GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8)		0				0		0		0
23	LossesFromDispositionOfAllowances Losses from Disposition of Allowances (411.9)		0				0		0		0
24	AccretionExpense Accretion Expense (411.10)		0				0		0		0
25	UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)		23,130,548,934	14,868,252,122			19,802,867,458	11,171,437,670	3,327,681,506	3,696,814,312	70	140
27	NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25)		5,792,973,609	2,609,021,136
28	OtherIncomeAndDeductionsAbstract Other Income and Deductions
29	OtherIncomeAbstract Other Income
30	NonutilityOperatingIncomeAbstract Nonutilty Operating Income
31	RevenuesFromMerchandisingJobbingAndContractWork Revenues From Merchandising, Jobbing and Contract Work (415)
32	CostsAndExpensesOfMerchandisingJobbingAndContractWork (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
33	RevenuesFromNonutilityOperations Revenues From Nonutility Operations (417)
34	ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1)
35	NonoperatingRentalIncome Nonoperating Rental Income (418)
36	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1)	119	42,609	3,103,044
37	InterestAndDividendIncome Interest and Dividend Income (419)		74,371,716	30,022,985
38	AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1)		129,009,681	89,256,337
39	MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421)		3,071,748	5,679,371
40	GainOnDispositionOfProperty Gain on Disposition of Property (421.1)		315,099	6,657,171
41	OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40)		206,810,853	128,512,820
42	OtherIncomeDeductionsAbstract Other Income Deductions
43	LossOnDispositionOfProperty Loss on Disposition of Property (421.2)
44	MiscellaneousAmortization Miscellaneous Amortization (425)
45	Donations Donations (426.1)		12,499,780	10,944,162
46	LifeInsurance Life Insurance (426.2)
47	Penalties Penalties (426.3)		5,324,520	24,386,884
48	ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4)		13,096,115	13,443,474
49	OtherDeductions Other Deductions (426.5)		255,846,898	301,635,298
50	OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49)		286,767,313	350,409,818
51	TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions
52	TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2)	262	486,744	362,370
53	IncomeTaxesFederal Income Taxes-Federal (409.2)	262	8,062,576	71,582,687
54	IncomeTaxesOther Income Taxes-Other (409.2)	262	29,809,600	39,875,243
55	ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2)	234, 272	33,169,360	40,539,809
56	ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2)	234, 272	25,839,617	158,562,363
57	InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5)		5,649,907	14,378,049
58	InvestmentTaxCredits (Less) Investment Tax Credits (420)
59	TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)		32,098,790	181,410,407
60	NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59)		112,055,250	40,486,591
61	InterestChargesAbstract Interest Charges
62	InterestOnLongTermDebt Interest on Long-Term Debt (427)		791,084,121	806,065,887
63	AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428)		29,043,258	27,416,689
64	AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1)		19,003,995	18,399,376
65	AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429)		818,824	1,963,283
66	AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1)		146,025	146,025
67	InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430)
68	OtherInterestExpense Other Interest Expense (431)		127,444,511	65,165,469
69	AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)		52,532,426	37,674,326
70	NetInterestCharges Net Interest Charges (Total of lines 62 thru 69)		913,078,610	877,263,787
71	IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70)		6,818,107,469	1,691,270,758
72	ExtraordinaryItemsAbstract Extraordinary Items
73	ExtraordinaryIncome Extraordinary Income (434)
74	ExtraordinaryDeductions (Less) Extraordinary Deductions (435)
75	NetExtraordinaryItems Net Extraordinary Items (Total of line 73 less line 74)
76	IncomeTaxesExtraordinaryItems Income Taxes-Federal and Other (409.3)	262	0
77	ExtraordinaryItemsAfterTaxes Extraordinary Items After Taxes (line 75 less line 76)
78	NetIncomeLoss Net Income (Total of line 71 and 77)		6,818,107,469	1,691,270,758

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

STATEMENT OF RETAINED EARNINGS
Do not report Lines 49-53 on the quarterly report. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b). State the purpose and amount for each reservation or appropriation of retained earnings. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order. Show dividends for each class and series of capital stock. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122-123.
Line No.	Item (a)	Contra Primary Account Affected (b)	Current Quarter/Year Year to Date Balance (c)	Previous Quarter/Year Year to Date Balance (d)
	UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1	UnappropriatedRetainedEarnings Balance-Beginning of Period		9,450,613,073	8,576,546,935
2	ChangesAbstract Changes
3	AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439)
4	AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit
4.1	AdjustmentsToRetainedEarningsCredit Reclassify stranded tax effects resulting from the 2017 Tax Cuts
4.2	AdjustmentsToRetainedEarningsCredit and Jobs Act from Accumulated Other Comprehensive Income	219	2,079,484
9	AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439)		2,079,484
10	AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit
10.1	AdjustmentsToRetainedEarningsDebit
10.2	AdjustmentsToRetainedEarningsDebit
15	AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439)
16	BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1)		6,818,150,078	1,694,373,802
17	AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436)
17.1	AppropriationsOfRetainedEarnings Reserves for excess earnings on FERC hydroelectric
17.2	AppropriationsOfRetainedEarnings project licenses pursuant to Federal Power Act Section 10 (d)	215	23,656,015	23,778,373
22	AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436)		23,656,015	23,778,373
23	DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437)
23.1	DividendsDeclaredPreferredStock Preferred Dividends Declared	238		13,916,352
23.2	DividendsDeclaredPreferredStock Accrued Preferred Dividends Requirement	238	13,916,318
29	DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437)		13,916,318	13,916,352
30	DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438)
30.1	DividendsDeclaredCommonStock Common Stock Dividends Declared	234		784,000,000
36	DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438)			784,000,000
37	TransfersFromUnappropriatedUndistributedSubsidiaryEarnings Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings		1,444,562	1,387,061
38	UnappropriatedRetainedEarnings Balance - End of Period (Total 1,9,15,16,22,29,36,37)		2,598,414,708	9,450,613,073
39	AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215)
39.1	AppropriatedRetainedEarnings Reserves for excess earnings on FERC hydroelectric
39.2	AppropriatedRetainedEarnings project licenses pursuant to Federal Power Act Section 10 (d)
45	AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215)		23,656,015	23,778,373
	AppropriatedRetainedEarningsAmortizationReserveFederalAbstract APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46	AppropriatedRetainedEarningsAmortizationReserveFederal TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)		262,364,920	238,586,547
47	AppropriatedRetainedEarningsIncludingReserveAmortization TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)		286,020,935	262,364,920
48	RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)		2,884,435,643	9,712,977,993
	UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49	UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit)		56,608,615	52,118,510
50	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1)		42,609	3,103,044
51	DividendsReceived (Less) Dividends Received (Debit)
52	ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
52.1	ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits Utility subsidiary earnings reflected in operations and maintenance accounts (offset in 216)		1,444,561	1,387,061
53	UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52)		58,010,567	56,608,615

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

STATEMENT OF CASH FLOWS
Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.	Description (See Instructions No.1 for explanation of codes) (a)	Current Year to Date Quarter/Year (b)	Previous Year to Date Quarter/Year (c)
1	NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities
2	NetIncomeLoss Net Income (Line 78(c) on page 117)	6,818,107,469	1,691,270,758
3	NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income:
4	DepreciationAndDepletion Depreciation and Depletion	3,034,709,845	2,852,785,423
5	NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details)
5.1	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Disallowed Capital Expenditures	44,798,404	47,398,938
5.2	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of Unamortized Loss or Gain on Reacquired Debt	18,857,970	17,613,914
5.3	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of Expenses, Discount and Premium - Long Term Debt	19,699,655	18,098,551
8	DeferredIncomeTaxesNet Deferred Income Taxes (Net)	2,538,903,619	1,083,992,255
9	InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net)	5,649,907	14,378,049
10	NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables	(a) 1,853,762,002	(k) 39,678,174
11	NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory	(b) 72,749,339	(l) 16,973,849
12	NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory
13	NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses	348,769,957	505,815,231
14	NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets	(c) 715,545,561	(m) 981,763,074
15	NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities	16,151,084	609,750,902
16	AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction	129,009,681	89,256,337
17	UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies	1,401,952	4,490,105
18	OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote):
18.1	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other (provide details in footnote):	13,476,022,102	129,518,306
22	NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)	4,704,784,415	5,898,041,248
24	CashFlowsFromInvestmentActivitiesAbstract Cash Flows from Investment Activities:
25	ConstructionAndAcquisitionOfPlantIncludingLandAbstract Construction and Acquisition of Plant (including land):
26	GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities Gross Additions to Utility Plant (less nuclear fuel)	(d) 6,564,592,641	(n) 5,596,719,659
27	GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel	(e) 78,340,868	(o) 131,760,000
28	GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant
29	GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant
30	AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction	(f) 129,009,681	(p) 89,256,337
31	OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote):
34	CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33)	(g) 6,513,923,828	(q) 5,639,223,322
36	AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d)
37	ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d)	22,233,335	25,953,577
39	InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Investments in and Advances to Assoc. and Subsidiary Companies	(h) 1,611,620	(r) 3,512,324
40	ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies Contributions and Advances from Assoc. and Subsidiary Companies
41	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract Disposition of Investments in (and Advances to)
42	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44	PurchaseOfInvestmentSecurities Purchase of Investment Securities (a)
45	ProceedsFromSalesOfInvestmentSecurities Proceeds from Sales of Investment Securities (a)
46	LoansMadeOrPurchased Loans Made or Purchased
47	CollectionsOnLoans Collections on Loans
49	NetIncreaseDecreaseInReceivablesInvestingActivities Net (Increase) Decrease in Receivables
50	NetIncreaseDecreaseInInventoryInvestingActivities Net (Increase) Decrease in Inventory
51	NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities Net (Increase) Decrease in Allowances Held for Speculation
52	NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities Net Increase (Decrease) in Payables and Accrued Expenses
53	OtherAdjustmentsToCashFlowsFromInvestmentActivities Other (provide details in footnote):
53.1	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Payments to Advances by Assoc. and Subsidiary Companies		3,253,555
53.2	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Net (Increase) Decrease in Restricted Cash
53.3	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Proceeds from nuclear decommissioning trust investments	1,411,689,770	1,291,749,504
53.4	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Purchases of nuclear decommissioning trust investments and other	1,484,791,279	1,322,693,283
57	CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)	6,566,403,622	5,650,979,403
59	CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities:
60	ProceedsFromIssuanceAbstract Proceeds from Issuance of:
61	ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b)	792,991,500	2,713,526,928
62	ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock
63	ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock
64	OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote):
66	NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c)	2,334,796,430	221,734,268
67	OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
67.1	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Equity contribution from PG&E Corporation	45,000,000	455,000,000
70	CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69)	3,172,787,930	2,946,792,660
72	PaymentsForRetirementAbstract Payments for Retirement of:
73	PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b)	(i) 445,000,000	(s) 1,445,000,000
74	PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock
75	PaymentsForRetirementOfCommonStockFinancingActivities Common Stock
76	OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):
76.1	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Customer Advances for Construction	(j) 4,227,505	7,963,753
76.2	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Other	21,850,462	68,324,365
78	NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c)		(t) 500,000,000
80	DividendsOnPreferredStock Dividends on Preferred Stock		13,916,352
81	DividendsOnCommonStock Dividends on Common Stock		784,000,000
83	CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)	2,710,164,973	127,588,190
85	NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents
86	NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)	848,545,766	374,650,035
88	CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period	449,815,658	75,165,623
90	CashAndCashEquivalents Cash and Cash Equivalents at End of Period	1,298,361,424	449,815,658

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

FOOTNOTE DATA

(a) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
-1853762002
(b) Concept: NetIncreaseDecreaseInInventoryOperatingActivities
-72749339
(c) Concept: NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
-715545561
(d) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
-6564592641
(e) Concept: GrossAdditionsToNuclearFuelInvestingActivities
-78340868
(f) Concept: AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
-129009681
(g) Concept: CashOutflowsForPlant
-6513923828
(h) Concept: InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
-1611620
(i) Concept: PaymentsForRetirementOfLongTermDebtFinancingActivities
-445000000
(j) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
4227505
(k) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
39678174
(l) Concept: NetIncreaseDecreaseInInventoryOperatingActivities
-16973849
(m) Concept: NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
-981763074
(n) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
-5596719659
(o) Concept: GrossAdditionsToNuclearFuelInvestingActivities
-131760000
(p) Concept: AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
-89256337
(q) Concept: CashOutflowsForPlant
-5639223322
(r) Concept: InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
-3512324
(s) Concept: PaymentsForRetirementOfLongTermDebtFinancingActivities
-1445000000
(t) Concept: NetDecreaseInShortTermDebt
-500000000

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

NOTES TO FINANCIAL STATEMENTS
Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement. Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock. For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Cormmission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts. Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions. If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted. For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred. Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.
1. ORGANIZATION Buckeye Partners, L.P. (“Buckeye”) is a master limited partnership organized in 1986 under the laws of the state of Delaware. Buckeye’s principal line of business is the transportation, terminalling, storage and handling of refined petroleum products in the United States and the Caribbean, for integrated oil companies, refined product marketing companies and end users of petroleum products, on a fee basis through facilities owned and jointly owned by Buckeye. Buckeye conducts all of its operations through subsidiary entities, which include Buckeye Pipe Line Transportation Company, LLC (the “Company”), as well as joint ventures. Buckeye owns a 100% ownership interest in the Company. The Company is the sole member (100% owner) of Buckeye Linden Pipe Line Company LLC. Buckeye Linden Pipe Line Company LLC was formed as a Delaware limited liability company on October 16, 2013 and commenced operations in June 2014. Buckeye Linden Pipe Line Company LLC provides b-directional pipeline transportation service between Perth Amboy, New Jersey and Linden, New Jersey, thereby offering shippers enhanced connectivity and service optionality in the New York Harbor.







1. ORGANIZATION Buckeye Partners, L.P. (“Buckeye”) is a master limited partnership organized in 1986 under the laws of the state of Delaware. Buckeye’s principal line of business is the transportation, terminalling, storage and handling of refined petroleum products in the United States and the Caribbean, for integrated oil companies, refined product marketing companies and end users of petroleum products, on a fee basis through facilities owned and jointly owned by Buckeye. Buckeye conducts all of its operations through subsidiary entities, which include Buckeye Pipe Line Transportation Company, LLC (the “Company”), as well as joint ventures. Buckeye owns a 100% ownership interest in the Company. The Company is the sole member (100% owner) of Buckeye Linden Pipe Line Company LLC. Buckeye Linden Pipe Line Company LLC was formed as a Delaware limited liability company on October 16, 2013 and commenced operations in June 2014. Buckeye Linden Pipe Line Company LLC provides b-directional pipeline transportation service between Perth Amboy, New Jersey and Linden, New Jersey, thereby offering shippers enhanced connectivity and service optionality in the New York Harbor.

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote. Report data on a year-to-date basis.
Line No.	Item (a)	Unrealized Gains and Losses on Available-For-Sale Securities (b)	Minimum Pension Liability Adjustment (net amount) (c)	Foreign Currency Hedges (d)	Other Adjustments (e)	Other Cash Flow Hedges Interest Rate Swaps (f)	Other Cash Flow Hedges [Specify] (g)	Totals for each category of items recorded in Account 219 (h)	Net Income (Carried Forward from Page 116, Line 78) (i)	Total Comprehensive Income (j)
1	Balance of Account 219 at Beginning of Preceding Year	5	5	5	2,433,232	5	5	2,433,257
2	Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income	10	10	10	520,590	10	10	520,640
3	Preceding Quarter/Year to Date Changes in Fair Value	5	5	5	3,336,795	5	5	3,336,770
4	Total (lines 2 and 3)	5	5	5	3,857,385	5	5	3,857,410	1,691,270,758	1,695,128,168
5	Balance of Account 219 at End of Preceding Quarter/Year	10	10	10	6,290,617	10	10	6,290,667
6	Balance of Account 219 at Beginning of Current Year	10	10	10	6,290,617	10	10	6,290,667
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income	10	10	10	1,479,887	10	10	1,479,837
8	Current Quarter/Year to Date Changes in Fair Value	5	5	5	5,797,513	5	5	5,797,538
9	Total (lines 7 and 8)	5	5	5	7,277,400	5	5	7,277,375	6,818,107,469	6,825,384,844
10	Balance of Account 219 at End of Current Quarter/Year	15	15	15	986,783	15	15	986,708

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.
Line No.	Classification (a)	Total Company For the Current Year/Quarter Ended (b)	Electric (c)	Gas (d)	Other (Specify) (e)	Other (Specify) (f)	Other (Specify) (g)	Common (h)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlantInServiceAbstract In Service
3	UtilityPlantInServiceClassified Plant in Service (Classified)	74,125,476,600	54,086,032,049	13,916,406,240	100	100	0	6,123,038,311
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases	18,230,721	0	0	100	100	0	18,230,721
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold	175,153	5,412	180,565	100	100	0	0
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified	12,823,811,035	7,129,231,035	5,175,470,140	200	200	0	519,109,860
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified	0	0	0	100	100	0	0
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	86,967,343,203	61,215,268,496	19,091,695,815	0	0	0	6,660,378,892
9	UtilityPlantLeasedToOthers Leased to Others	0	0	0	0	0	0	0
10	UtilityPlantHeldForFutureUse Held for Future Use	0	0	0	0	0	0	0
11	ConstructionWorkInProgress Construction Work in Progress	2,562,027,669	1,720,845,397	352,902,795	0	0	0	488,279,477
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments	0	0	0	0	0	0	0
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	89,529,370,872	62,936,113,893	19,444,598,610	0	0	0	7,148,658,369
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	37,353,599,037	26,907,643,431	7,703,873,367	0	0	0	2,742,082,239
15	UtilityPlantNet Net Utility Plant (13 less 14)	52,175,771,835	36,028,470,462	11,740,725,243	0	0	0	4,406,576,130
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	36,332,965,571	26,845,549,665	7,696,385,371	100	100	100	1,791,030,535
19	AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights	0	0	0	100	100	100	0
20	AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights	8,525,339	0	8,525,339	100	100	100	0
21	AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant	1,012,108,127	62,093,766	1,037,343	100	100	100	951,051,704
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	37,353,599,037	26,907,643,431	7,703,873,367	0	0	0	2,742,082,239
23	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others
24	DepreciationUtilityPlantLeasedToOthers Depreciation	200	200	200	100	100	100	200
25	AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion	200	200	200	100	100	100	200
26	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25)	0	0	0	0	0	0	0
27	DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use
28	DepreciationUtilityPlantHeldForFutureUse Depreciation	200	200	200	100	100	100	200
29	AmortizationUtilityPlantHeldForFutureUse Amortization	200	200	200	100	100	100	200
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)	0	0	0	0	0	0	0
31	AbandonmentOfLeases Abandonment of Leases (Natural Gas)	200	200	200	100	100	100	200
32	AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment	200	200	200	100	100	100	200
33	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32)	37,353,599,037	26,907,643,431	7,703,873,367	0	0	0	2,742,082,239

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.	Description of item (a)	Balance Beginning of Year (b)	Changes during Year Additions (c)	Changes during Year Amortization (d)	Changes during Year Other Reductions (Explain in a footnote) (e)	Balance End of Year (f)
1	Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2	Fabrication	0	100		100	0
3	Nuclear Materials	261,763,030	78,340,869		106,154,666	233,949,233
4	Allowance for Funds Used during Construction	0	100		100	0
5	(Other Overhead Construction Costs, provide details in footnote)	0	200		200	0
6	SUBTOTAL (Total 2 thru 5)	261,763,030	78,340,869		106,154,666	233,949,233
7	Nuclear Fuel Materials and Assemblies
8	In Stock (120.2)	0	0	0	0	0
9	In Reactor (120.3)	416,084,176	106,154,666	0	94,857,220	427,381,622
10	SUBTOTAL (Total 8 & 9)	416,084,176	106,154,666	0	0	427,381,622
11	Spent Nuclear Fuel (120.4)	2,265,141,307	94,857,219	0	0	2,359,998,526
12	Nuclear Fuel Under Capital Leases (120.6)	0	0	0	0	0
13	(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)	2,505,050,242	0	125,886,537	0	2,630,936,779
14	TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)	437,938,271	279,352,754	125,886,537	201,011,886	390,392,602
15	Estimated Net Salvage Value of Nuclear Materials in Line 9	0				0
16	Estimated Net Salvage Value of Nuclear Materials in Line 11	0				0
17	Est Net Salvage Value of Nuclear Materials in Chemical Processing	0				0
18	Nuclear Materials held for Sale (157)
19	Uranium	0	200	100	100	0
20	Plutonium	0	200	100	100	0
21	Other (Provide details in footnote)	0	200	100	100	0
22	TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)	0	600	300	300	0

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Report below the original cost of electric plant in service according to the prescribed accounts. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.	Account (a)	Balance Beginning of Year (b)	Additions (c)	Retirements (d)	Adjustments (e)	Transfers (f)	Balance at End of Year (g)
1	1. INTANGIBLE PLANT
2	(301) Organization	0	0	0	0	0	0
3	(302) Franchise and Consents	113,935,938	24,823,199	0	0	0	138,759,137
4	(303) Miscellaneous Intangible Plant	4,126,232	1,166,068	3,389	0	0	5,288,911
5	TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)	118,062,170	25,989,267	3,389	0	0	144,048,048
6	2. PRODUCTION PLANT
7	A. Steam Production Plant
8	(310) Land and Land Rights	8,644,205	0	0	0	0	8,644,205
9	(311) Structures and Improvements	113,561,273	109,771	0	0	0	113,671,044
10	(312) Boiler Plant Equipment	276,508,417	2,442,743	0	0	989,383	277,961,777
11	(313) Engines and Engine-Driven Generators		0	0	0	0
12	(314) Turbogenerator Units	257,380,332	0	0	0	0	257,380,332
13	(315) Accessory Electric Equipment	52,595,986	29,565	0	0	0	52,625,551
14	(316) Misc. Power Plant Equipment	28,348,904	0	0	0	0	28,348,904
15	(317) Asset Retirement Costs for Steam Production	96,102,035	0	0	0	0	96,102,035
16	TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)	833,141,152	2,582,079	0	0	989,383	834,733,848
17	B. Nuclear Production Plant
18	(320) Land and Land Rights	22,726,561	0	0	0	0	22,726,561
19	(321) Structures and Improvements	1,085,772,994	6,835,729	3,353,723	0	0	1,089,255,000
20	(322) Reactor Plant Equipment	3,517,473,860	71,354,380	10,522,065			3,578,306,175
21	(323) Turbogenerator Units	1,170,599,139	7,411,227	3,261,577			1,174,748,789
22	(324) Accessory Electric Equipment	846,769,572	21,188,894	66,467			867,891,999
23	(325) Misc. Power Plant Equipment	1,147,664,525	41,690,752	25,947,697			1,163,407,580
24	(326) Asset Retirement Costs for Nuclear Production	2,272,616,627			1,092,350,056		3,364,966,683
25	TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)	10,063,623,278	148,480,982	43,151,529	1,092,350,056		11,261,302,787
26	C. Hydraulic Production Plant
27	(330) Land and Land Rights	42,302,196	409,562	8,974			42,702,784
28	(331) Structures and Improvements	499,373,873	29,748,058	3,410,063			525,711,868
29	(332) Reservoirs, Dams, and Waterways	2,079,068,411	40,774,259	1,296,654		4,728,569	2,123,274,585
30	(333) Water Wheels, Turbines, and Generators	954,260,058	68,183,816	10,722,940			1,011,720,934
31	(334) Accessory Electric Equipment	271,049,293	27,932,714	2,865,660			296,116,347
32	(335) Misc. Power Plant Equipment	94,926,142	8,559,531	1,063,343			102,422,330
33	(336) Roads, Railroads, and Bridges	85,007,646	8,146,421	17,742			93,136,325
34	(337) Asset Retirement Costs for Hydraulic Production	7,200,427	0	0	0	0	7,200,427
35	TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)	4,033,188,046	183,754,361	19,385,376		4,728,569	4,202,285,600
36	D. Other Production Plant
37	(340) Land and Land Rights	19,207,870	0	0	0	0	19,207,870
38	(341) Structures and Improvements	210,604,019	200,429	0	0	0	210,804,448
39	(342) Fuel Holders, Products, and Accessories	11,271,196	0	0	0	0	11,271,196
40	(343) Prime Movers	226,088,318	803,368	0	0	989,383	227,881,069
41	(344) Generators	353,681,235	197,027	0	0	0	353,878,262
42	(345) Accessory Electric Equipment	212,857,732	856,942	0	0	0	213,714,674
43	(346) Misc. Power Plant Equipment	97,457,928	1,188,085	0	0	0	98,646,013
44	(347) Asset Retirement Costs for Other Production		0	0	0	0
44.1	(348) Energy Storage Equipment - Production		0	0	0	0
45	TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)	1,131,168,298	3,245,851			989,383	1,135,403,532
46	TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)	16,061,120,774	338,063,273	62,536,905	1,092,350,056	4,728,569	17,433,725,767
47	3. Transmission Plant
48	(350) Land and Land Rights	276,608,506	684,064	1,490			277,291,080
48.1	(351) Energy Storage Equipment - Transmission		0	0	0	0
49	(352) Structures and Improvements	461,242,771	34,815,270				496,058,041
50	(353) Station Equipment	6,170,545,480	481,497,306	41,550,592	822,172		6,609,670,022
51	(354) Towers and Fixtures	916,974,214	47,048,198	2,188,965			961,833,447
52	(355) Poles and Fixtures	1,174,526,222	211,430,662	4,322,481			1,381,634,403
53	(356) Overhead Conductors and Devices	1,535,926,474	184,432,168	7,297,467			1,713,061,175
54	(357) Underground Conduit	504,865,156	7,335,852	1,024,869			511,176,139
55	(358) Underground Conductors and Devices	272,635,262	1,728,574	343,845			274,019,991
56	(359) Roads and Trails	86,759,267	7,594,898				94,354,165
57	(359.1) Asset Retirement Costs for Transmission Plant	3,988,851			2,354,516		1,634,335
58	TOTAL Transmission Plant (Enter Total of lines 49 thru 59)	11,404,072,203	976,566,992	56,729,709	3,176,688		12,320,732,798
59	4. Distribution Plant
60	(360) Land and Land Rights	175,062,439	5,593,729	5,329			180,650,839
61	(361) Structures and Improvements	327,090,066	742,753	254,994		4,728,569	322,849,256
62	(362) Station Equipment	3,354,258,444	191,731,907	33,300,743	125,567		3,512,564,041
63	(363) Energy Storage Equipment – Distribution	33,232,585	264,688				33,497,273
64	(364) Poles, Towers, and Fixtures	4,323,200,397	542,735,774	33,207,217			4,832,728,954
65	(365) Overhead Conductors and Devices	4,690,443,433	257,144,056	147,761,741			4,799,825,748
66	(366) Underground Conduit	2,861,362,449	142,249,470	59,432			3,003,552,487
67	(367) Underground Conductors and Devices	4,554,288,320	261,215,464	8,883,910			4,806,619,874
68	(368) Line Transformers	3,451,398,731	365,166,596	25,838,062			3,790,727,265
69	(369) Services	3,272,328,566	151,958,578	2,107,371			3,422,179,773
70	(370) Meters	1,157,714,458	55,069,449	11,503,350			1,201,280,557
71	(371) Installations on Customer Premises	27,313,912	756,690				28,070,602
72	(372) Leased Property on Customer Premises	895,448	0	0	0	0	895,448
73	(373) Street Lighting and Signal Systems	231,835,835	22,931,564	31,017			254,736,382
74	(374) Asset Retirement Costs for Distribution Plant	15,233,800			8,940,961		6,292,839
75	TOTAL Distribution Plant (Enter Total of lines 62 thru 76)	28,475,658,883	1,997,560,718	262,953,166	9,066,528	4,728,569	30,196,471,338
76	5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77	(380) Land and Land Rights	0	100	100	100	100	0
78	(381) Structures and Improvements	0	100	100	100	100	0
79	(382) Computer Hardware	0	100	100	100	100	0
80	(383) Computer Software	0	100	100	100	100	0
81	(384) Communication Equipment	0	100	100	100	100	0
82	(385) Miscellaneous Regional Transmission and Market Operation Plant	0	100	100	100	100	0
83	(386) Asset Retirement Costs for Regional Transmission and Market Oper	0	100	100	100	100	0
84	TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)	0	700	700	700	700	0
85	6. General Plant
86	(389) Land and Land Rights	424,632					424,632
87	(390) Structures and Improvements	11,254,863	522,272				11,777,135
88	(391) Office Furniture and Equipment	15,628,644	215,865	414,288			15,430,221
89	(392) Transportation Equipment
90	(393) Stores Equipment
91	(394) Tools, Shop and Garage Equipment	129,933,249	15,424,364				145,357,613
92	(395) Laboratory Equipment	14,556,151	1,471,911	121,553			15,906,509
93	(396) Power Operated Equipment	271,024		271,024
94	(397) Communication Equipment	291,009,027	77,704,741	463,072			368,250,696
95	(398) Miscellaneous Equipment	70,772,401	16,144,550	1,510,994	1,694,626		87,100,583
96	SUBTOTAL (Enter Total of lines 86 thru 95)	533,849,991	111,483,703	2,780,931	1,694,626		644,247,389
97	(399) Other Tangible Property	468,499,422					468,499,422
98	(399.1) Asset Retirement Costs for General Plant	7,292,156			246,166		7,538,322
99	TOTAL General Plant (Enter Total of lines 96, 97, and 98)	1,009,641,569	111,483,703	2,780,931	1,940,792		1,120,285,133
100	TOTAL (Accounts 101 and 106)	57,068,555,599	3,449,663,953	385,004,100	1,082,047,632		61,215,263,084
101	(102) Electric Plant Purchased (See Instr. 8)
102	(Less) (102) Electric Plant Sold (See Instr. 8)	219,416			224,828		5,412
103	(103) Experimental Plant Unclassified
104	TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)	57,068,336,183	3,449,663,953	385,004,100	1,082,272,460		61,215,268,496

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.	LesseeName Name of Lessee (a)	IndicationOfAssociatedCompany * (Designation of Associated Company) (b)	LeaseDescription Description of Property Leased (c)	CommissionAuthorization Commission Authorization (d)	ExpirationDateOfLease Expiration Date of Lease (e)	ElectricPlantLeasedToOthers Balance at End of Year (f)
1	ABC Group	True	Long Term	01/01/2019	12/31/2030	1,000,000
2	EFG Group	False	Short Term	02/01/2020	12/31/2021	1,000,000
47	TOTAL					0

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.	ElectricPlantHeldForFutureUseDescription Description and Location of Property (a)	ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate Date Originally Included in This Account (b)	ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate Date Expected to be used in Utility Service (c)	ElectricPlantHeldForFutureUse Balance at End of Year (d)
1	Land and Rights:
2	James Rowe Substation	08/01/2010	08/01/2022	1,004,575
3	Marina Substation	12/01/2015	12/01/2019	272,883
4
5
6
21	Other Property:
22	Pantera Other	04/01/2017	10/01/2022	1,277,458
47	TOTAL			0

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
Report below descriptions and balances at end of year of projects in process of construction (107). Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts). Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.	ConstructionWorkInProgressProjectDescription Description of Project (a)	ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b)
1	74001039 SAN FRAN Y (LARKIN): REPLACE 12KV SWGR	47,860,661
2	7054908 MC-P Relic- Project Management	38,252,003
3	68011748 PLO-U2:Repl Main Generator Stator	37,302,124
4	74000916 KERN PP: UPGRADE 230 KV BUS	34,011,822
5	74015944 EMBARCADERO (SF-Z) DECOUPLE BKS 1, 3, 5	24,225,606
6	7070913 DS conduct Rel studies	23,593,525
7	74001857 EL CERRITO G: 115KV BUS UPGRADE PHASE 1	22,076,849
8	74004821 VACA DIXON: REP 500 KV SERIES CAP BK 2	20,143,416
9	74000600 FULTON-FITCH MTN. RECOND 60KV LN	16,298,171
10	7021725 UNFFR Relic Routine Project Management	16,293,482
11	74000924 ESTRELLA_CPUC LIC/PER	15,863,538
12	74003442 MOSS LANDING: REPLACE 500 KV BREAKERS	14,111,604
13	74000925 MIDWAY ANDREW_CPUC LIC/PER	14,024,624
14	74001031 MIDWAY-KERN PP #2 230 KV LINE KERN AREA	13,946,561
15	74002444 GATES: REPL BK 500/230 KV TRANSFORMER	13,843,748
16	74002376 BORDEN 230 KV VOLTAGE SUPPORT (SUB)	13,574,688
17	74002462 PEASE - 115KV BUS TO BAAH RECONFIG	13,493,496
18	7026033 UNFFR Relic Aquatic Resource Stdy	12,909,427
19	74000841 HERNDON-KEARNEY 230 KV LINE RECONDUCTOR	12,236,016
20	13004820 Drum Spaulding - Developing PAD and NOI	12,088,194
21	74002892 VACA DIXON: REP 500 KV SERIES CAP BK 1	11,980,879
22	74000846 METCALF - EVERGREEN RECONDUCTORING (TL)	11,662,602
23	74001780 RIO OSO: INSTALL 230KV BAAH/GIS	11,614,759
24	74001097 COOLEY LANDING: INSTALL BK 2	11,606,728
25	74001782 RIO OSO: INSTALL 115 KV BAAH/GIS	11,559,275
26	74000662 VALLEJO B: REPLACE 4KV SWGR & BANKS	11,532,821
27	74001858 EL CERRITO G: REPL 12KV CBS W/SWGR	11,304,634
28	74001957 MONTA VISTA: UPGRADE 230 KV BUS - PH 1	11,289,147
29	74003144 BELLOTA: INSTALL 230 KV SHUNT REACTOR	11,272,940
30	74000939 WRJ NONCOMPETITIVE_CPUC LIC/PER	10,818,407
31	74001389 SMYRNA-SEMITROP-MIDWAY 115KV NERC ALERT	10,453,243
32	74001953 SAN FRAN F (MARINA): REPLACE 4KV SWGR	10,098,274
33	74003358 PIT PH 1: ADD BK 5	9,844,074
34	74011380 74011380_GREATER BAY ER STORAGE FAC SF	9,786,344
35	74000901 MARTIN BUS EXTENSION_CPUC LIC/PER	9,773,092
36	74002346 MARYSVILLE SUB: CONVERT TO RING BUS	9,559,341
37	74011760 NETWORK SCADA Y-2	9,381,992
38	68053001 COM: Integrated Video Mgt System Upgrade	9,324,636
39	74001398 60-SOUTH OF PALERMO REINFORCEMENT (PH-3)	9,058,695
40	74007941 CALTRAIN INTERCONNECTIONS SUB SITE 3	9,055,298
41	74001223 REDWOOD CITY: REP CB404,406,408,409,410	9,012,860
42	74001396 60-SOUTH OF PALERMO REINFORCEMENT (PH-2)	8,974,429
43	74000988 CASTRO VALLEY: REPLACE 12 KV SWITCHGEAR	8,788,097
44	74010530 74010530 GREATER BAY ER STORAGE FAC OAK	8,566,174
45	13003982 DS-C Relic- Cond studies for all RA	8,517,659
46	74001785 RIO OSO: INSTALL 230 KV MPAC	8,379,509
47	74001942 KERN PP 230KV MPAC	8,334,198
48	74000933 230 KV TLINE LOCKEFORD - NEW INDUSTRIAL	8,252,391
49	74001588 ORO LOMA: INSTALL 115 KV MPAC	8,203,725
50	74000981 HERNDON SUB - NORTHERN FRESNO 115KV AREA	8,201,914
51	74006580 NV_TESLA 230KV BUS DIFFERENTIAL REPLACE	7,869,354
52	74000714 (DA-CE) COLGATE-CHALLENGE RELIABILITY	7,793,112
53	7076869 Buck Rel Studies	7,549,005
54	74001786 RIO OSO: INSTALL 115 KV MPAC	7,510,911
55	74000959 MCCALL SUB - NORTHERN FRESNO 115KV AREA	7,369,704
56	74001710 SANGER: REPLACE 115 KV BUS	7,325,398
57	74000343 CALTRAIN INTERCONNECTIONS SUB SITE 1	7,142,520
58	74001391 60-SOUTH OF PALERMO REINFORCEMENT (PH-1)	6,973,678
59	74001620 Pit 3 Unit 3 Replace Rewind	6,892,123
60	74015243 TSRP-NORTH BAY SIERRA PROJECT MANAGEMENT	6,823,920
61	74009262 KASSON SUB: REPLACE BANK 1	6,221,577
62	7026032 UNFFR Relic Water Use & Qlty Stdy	6,197,315
63	74001708 SANGER: INSTALL 115 KV MPAC	6,197,049
64	74001781 RIO OSO: INSTALL BK 1 AND BK 2	6,180,150
65	74001112 RIPON NEW 115 KV LINE 2ND TAP RELIABILIT	6,097,982
66	74001713 HUNTERS POINT: 115KV GIS BAAH	6,085,776
67	7026037 UNFFR Relic Land Use/Mgt Study	5,936,003
68	74004964 SOBRANTE: ADD & REPL 14-115KV BKERS P2	5,867,022
69	7055507 DS Relic- Strategic Planning	5,736,990
70	7055646 DS Relic- Project Management	5,702,054
71	68017320 PLO-Remove Abandoned in place RO System	5,639,241
72	74003025 IGNACIO: INSTALL 230 KV SHUNT REACTOR	5,622,270
73	74001063 GATE-GREGG 230KV T-LINE CPUC LIC/PER	5,602,736
74	74016300 NETWORK SCADA Y-1	5,523,955
75	74010662 Helms - Main Crane Modification	5,416,072
76	74004615 EAGLE ROCK-FULTON-SILVERADO NERC PROJECT	5,273,864
77	74001960 MOSS LANDING: INST 500 KV CTRL BUILDING	5,229,936
78	74001853 EL CERRITO G:REPLBK4 W/BK3 115-12KV 60MV	5,039,026
79	74010941 BORDEN: INSTALL MPAC	4,980,717
80	7089447 Potter Valley Rel Studies	4,865,138
81	74003359 MARTIN: REPLACE 230 KV SHUNT REACTOR 1	4,818,696
82	7072819 Helms - Replace Liquid Rheostat	4,775,041
83	74002483 SPENCE: INSTALL BK 1	4,523,667
84	74002743 STOCKTON A WEBER	4,508,263
85	74014700 Pit 6 U1 Replace Transformer	4,477,671
86	74009948 BELLOTA SUB: PHYSICAL SECURITY UPGRADE	4,386,447
87	68015242 PLO-COM::Rplc Secondary Chem Lab	4,310,063
88	74001472 GOLD HILL: REPLACE CB 222 242 252 212	4,300,964
89	74001436 (DA-B&M) ELECTRA-VALLEY SPRGS CAP/RECOND	4,285,069
90	74001723 PEASE - INST BANK 5	4,285,039
91	74000626 CAMANCHE TAP 115KV RECONDUCTOR	4,210,824
92	74005663 KERN PP: CONVERT 115KV BUS TO BAAH	4,102,854
93	74008620 Fordyce Dam Leakage Reduction	4,045,838
94	74006762 METCALF-SALINAS NO. 1 (IDLE) (P3)	3,914,960
95	74009504 SF M SUB, REPLACE BK 1 12KV & 4KV SWGR	3,902,068
96	74004832 WEEDPATCH 70 KV CB 42 52 62	3,888,438
97	68049386 PLO-COM: Reloc Security VIS	3,887,443
98	74001001 WHEELER RIDGE-WEEDPATCH 70 KV (KALTR)	3,867,833
99	68020200 PLO: U2: REPL CFCU CLNG COILS (2R21)2-5	3,861,388
100	74002247 ORO LOMA: REPLACE BK 2 115/70 KV	3,805,760
101	74020222 FULTON-CALISTOGA 60 KV LINE RECONDUCTORE	3,745,737
102	74000709 (DA-TRC) HUMBOLDT BAY RECOND. PROJ. 2021	3,719,903
103	74018125 SPENCE: UPGRADE TRANSMISSION 60 KV	3,695,509
104	74002930 COLUMBUS: INSTALL 2-115 KV CBS	3,682,051
105	74001175 MOSHER-LOCKFORD 60KV RECOND.	3,666,256
106	74004265 ORO LOMA: INSTALL BK 3	3,639,894
107	74011616 Helms - Rewind U2	3,637,902
108	74009760 TC Canal_Install Canal Liner 17/19	3,516,447
109	74000825 LEMOORE NAS 70 KV SCADA SW#55,65	3,397,631
110	74004888 OAKLAND D SUB: REPLACE 4KV SWITCHGEAR	3,365,135
111	74000711 NRS-SCOTT RECONDUCTORING	3,340,931
112	74001688 NC_(DA-ABB) MAPLE CREEK SUB:REACTIVE SUP	3,336,884
113	68019301 U1:Upgrade Polisher Computer Workstation	3,322,543
114	30797619 OAKLEY GENERATING STN: LAS POSITAS-NEWAR	3,305,177
115	74001432 COTTNWD-RED BLUFF - RECONDUCTOR	3,291,424
116	7049829 DC Relic Begin Prep of NOI and PAD	3,253,857
117	7026034 UNFFR Relic Terres Resources Stdy	3,250,247
118	74001453 Electra U3 New Needle, Stem & Bushings	3,244,265
119	74018362 FLINT SUB: EMER BK1 REPLACE	3,227,687
120	74004617 GEYSERS #9-LAKEVILLE NERC PROJECT	3,165,208
121	74002214 HOPLAND: REPLACE BK 2	3,119,450
122	74001179 NV_94-INDIAN FLAT SUB:REPL SW 17 W/1-70K	3,113,452
123	13006140 MC-P Relic- Conduct Relicensing Studies	3,089,012
124	74006763 METCALF-SALINAS NO. 2	3,030,268
125	74000700 TEMPLETON 230/70KV MPAC	3,022,647
126	74005020 MIDWAY: UPGRADE 230 KV BUS SECTION D	2,989,401
127	31168794 ETTM RANCHO VISTA MHP	2,959,277
128	7053945 DC Relic - Prepare Study Plans	2,939,134
129	74005023 SHAFTER SUBSTATION: BANK 1	2,938,687
130	74000731 EAST SHORE-OAKLAND J 115KV RECONDUCT(TL)	2,938,111
131	7054909 MC-P Relic- Prepare NOI and PAD	2,908,006
132	74001200 EXCHEQUER SUB TO BEAR VALLEY SUB	2,854,654
133	74001427 WEBER-SANTA FE JUNCTION 60 KV RECON	2,835,960
134	74011148 VACA DIXON: EM INSTALL STATION LIGHTING	2,782,683
135	74008580 ASHLAN: CONVERT TO 230 KV RING BUS	2,779,535
136	74005670 VALLEJO B: REPLACE 4 KV SWGR - DLINE	2,769,754
137	74004826 67-HICKS: INSTALL 230KV MPAC (CONSTR 201	2,764,927
138	74009861 BRUCE RD CHICO R20A	2,762,560
139	74001022 LERDO: REPLACE 12 KV BUS SECTION E	2,760,452
140	68044182 PLO: COM: REPL HVAC Units 501, 502, 503	2,739,325
141	74021024 MORGAN HILL SUB: 115KV BAAH CONVERSION	2,736,161
142	13008740 Battle Crk - Phase 2 License Amendment	2,732,217
143	7076872 Buck Rel Lic App	2,732,140
144	74000915 KERN 230KV AREA REIN MIDWAY-KERN 3 & 4 (	2,705,944
145	74001642 R1 MIDDLEFIELD ROAD REDWOOD CITY R20A	2,693,039
146	74015245 TSRP-NORTH BAY SIERRA ET COMM- READY SUB	2,688,328
147	13011921 NFSL Additional Design Imp	2,688,213
148	7043247 RCC Lic Imp Cold Water Feasibility Study	2,687,809
149	74001856 EL CERRITO G: 115KV BUS UPGRADE PHASE 2	2,684,935
150	74008161 2018 CARUTHERS 1102 EXTEND & REINF PH. 2	2,674,750
151	68009762 PLO-U2:Replace DG22 Exciter/Voltage Regu	2,669,044
152	74008366 MESA SUB VOLTAGE SUPPORT	2,665,296
153	74000601 FULTON-FITCH: RECONDUCTORING 60 KV	2,663,947
154	7021727 UNFFR Relic Prepare 5 Year Library	2,604,684
155	74002486 KERN PP: INSTALL 115KV MPAC BLDGS	2,597,583
156	74000936 WRJ COMPETITIVE_CPUC LIC/PER	2,577,508
157	74007560 EMBARCADERO - REPLACE 34/12KV BANK 12	2,561,630
158	74000546 KEARNEY-CARUTHERS 70 KV LINE RECONDUCTOR	2,561,447
159	30854865 NEWARK-AMES 1300FT BW 46-50 CRITTENDON	2,550,149
160	74001766 RAVENSWOOD-COOLEY LANDING 115 KV (TL)	2,532,159
161	7093246 ODN Network Segmentation	2,517,120
162	74021027 METCALF-GREEN VALLEY 115KV: LINE RECONDU	2,474,875
163	74003441 ASHLAN: INSTALL MPAC BUILDING & OPGW	2,472,488
164	74018601 GATES-TULARE LAKE 70KV EMERGENCY WORK	2,454,647
165	68019124 PLO-Com:Repl Breathing Air Compsr Ph II	2,452,174
166	13002402 DS-C Relic- Conduct Pre-App Proj Man	2,446,314
167	68000146 Lead Order-U2:Repl Boric Acid Xfer Pumps	2,443,385
168	13011869 Pit 6 Replace Stoplog Lifting Device	2,437,234
169	74001334 TEMBLOR-SAN LUIS OBISPO 115KV NERC	2,430,238
170	30842587 OAKLEY GENERATING STN:COCOPP-DELTA PUMPS	2,423,395
171	74000345 CHSR INTERCONNECTIONS SUB SITES 4-7	2,383,891
172	7026036 UNFFR Relic Rec Resources Study	2,361,923
173	31214160 EM_RICHMOND Q SUB - REPL. UNIT SUBS	2,359,578
174	74001677 NV_STOCKTON A SUB- REPLACE CB 402,404	2,354,542
175	74006884 MORRO BAY SUB: UPGRADE 230KV BUS	2,345,835
176	68019302 PLO-U2:Cond. Polisher Cmptr Upgrade	2,304,229
177	74001064 GATES-GREGG PRE-BID COSTS	2,290,371
178	74000900 Bucks Creek U2 Generator Rewind	2,288,512
179	74018460 RMR: TRIMBLE-SAN JOSE B 115KV SERIES REA	2,286,635
180	68036981 PLO: COM: 500kv Road Upgrade	2,274,196
181	68050741 PLO-U1: Repl DRPI Detector/Encoder Cards	2,253,910
182	31298384 ODN SECURITY PROJECT	2,236,884
183	74000707 60 KINGSBURG-LEMOORE 70KV RECOND. PH1	2,225,234
184	74008419 Caribou 1 Crane Modernization	2,224,924
185	74001173 LODI: REPLACE CB 12 22 32	2,190,937
186	74005121 EVERGREEN SUB: 115KV BUS UPGRADE	2,190,606
187	74000341 CHSR INTERCONNECTIONS SUB SITES 8-13	2,188,887
188	74001732 VIERRA 115 KV REINFORCEMENT (T-LINE)	2,188,471
189	74007808 RICE SUB: REPLACE BANK 1	2,174,438
190	68048860 PLO - U1: Repl Plant Recorders	2,165,077
191	74008380 Cresta PH Refurbish Transformers	2,164,619
192	74008281 Bucks Cr Replace Turb Brg / Shaft	2,147,649
193	74004825 HICKS: IMPROVE 230 KV BUS RELIABILITY	2,114,460
194	13011870 Pit 7 Replace Stoplog Lifting Device	2,103,301
195	74001020 SHAFTER SUB-REPLACE CB 1101, 1102, 1103	2,093,449
196	74006361 DELEVAN: INSTALL 200 MVAR SHUNT REACTOR	2,087,161
197	74008660 2018 GATES 1110 12KV FEEDER	2,075,286
198	74001047 KERN 230KV AREA REIN MIDWAY-KERN 1 & 2 (	2,074,734
199	13009580 DeSabla Replace Governor	2,072,742
200	74015582 STUART: EM REPLACE 12/4 KV BK1	2,066,581
201	74005355 RIO OSO SUB: SVC	2,054,284
202	74008455 Cresta PH Arc Flash Remediation U1&U2	2,042,601
203	74000840 -ENG.ONLY (DA-B&M) KESWICK-TRINITY REL.	1,997,723
204	74002485 NC_PUEBLO SUB: REPLACE BK 1	1,991,741
205	74015805 LERDO: REPLACE 12 KV BUS SECTION	1,970,734
206	7026029 UNFFR Relic Prep 1st Stage Consult Pkg	1,962,278
207	74010660 Balch 2 - U2 Replace Cooling Water	1,959,326
208	68038260 PLO-COM: North Access Rd Upgrade	1,947,546
209	74001739 (CONT.EST) MAPLE CREEK-WILLOW 60KV REL.	1,944,682
210	74008524 EP BRIDGE ST COLUSA R20A	1,936,386
211	74010750 MONTA VISTA: INSTALL 230KV MPAC	1,932,577
212	74001553 EP SHELL BEACH RD PISMO BEACH R20A	1,927,008
213	74012040 NICOLAUS-WILKINS SLOUGH 60KV LINE POLE	1,919,578
214	74017519 VACA DIXON: INSTALL 230 KV SMART WIRES	1,919,282
215	74011030 KERN 230KV BAAH 115KV LINE RELOCATION	1,917,488
216	7092705 Asset Data Improvement (GIS Phasing-Sub)	1,916,059
217	68021733 PLO-U1:Replace DG 1-2 Controls System	1,916,040
218	74003803 Q954 FIFTH STANDARD SOLAR (NU) GATES	1,915,635
219	74002410 Pit 5 TGB Install Inline Oil Filtration	1,901,496
220	74008358 SAN LEANDRO U: REPLACE CB 182, 372, 382	1,897,243
221	74002321 Inskip Eagle Canyon Access Safety Improv	1,895,135
222	74001792 RED BLUFF-COLEMAN REINFORCEMENT	1,894,567
223	74010413 BORDEN VOLTAGE SUPPORT - STOREY SUB	1,881,696
224	74008456 Cresta PH Repl Stoplog Hoist	1,846,138
225	7093006 WSOC (Ramp for addl functionality)	1,846,115
226	74003903 SHEPHERD 2111 AUBERRY ROAD RECON - 2018	1,820,443
227	74016583 Electra U2 Generator Rewind	1,818,114
228	74008384 Battle Cr Salmon/Steelhead Phase 2	1,810,645
229	74001704 FIREBAUGH: INSTALL 70 KV SCADA SWITCH	1,787,843
230	74004819 COTTLE: INSTALL 2 17 KV FEEDERS	1,770,652
231	68044188 PLO: COM: Upgrd Bldg 104 Entire 5th Flr	1,761,792
232	74016341 TSRP NBS IT OTHER SITES	1,760,829
233	13023101 Butte Head Dam Road Improvements 2017	1,702,945
234	74011488 VALLEYSPRINGS-MARTELL NO.2 SCADA	1,701,544
235	74005120 EVERGREEN: UPGRADE 60 KV PROTECTION	1,657,793
236	74009204 TABLE MTN:REPL 500KV TM-ROUND MTN #1 REL	1,651,955
237	74001943 WHEELER RIDGE VOLTAGE SUPPORT (SUB)	1,626,733
238	7062249 MC-P- Proj Scoping and Study Plan Devp	1,623,336
239	7070917 DS Post App filing activities	1,620,566
240	7087874 Permit Holdover Project - Shasta-Trinity	1,579,866
241	74001735 POTRERO-MISSION #1 (A-X 1) SEISMIC RETRO	1,574,099
242	74002189 FRENCH GULCH: INSTALL D-SCADA	1,573,970
243	74016584 Tiger Creek U2 Generator Rewind	1,573,569
244	74008849 CYMRIC: INSTALL MRTU	1,573,184
245	74003501 SUMMIT: REPL 60 KV SW 37 & SW OPERATOR	1,550,888
246	74009567 HERNDON: EM REPLACE CIRCUIT BREAKER 242	1,542,679
247	68035784 PLO-U2: Rewind RCP Stator S1	1,532,679
248	74000937 MERCY SPRINGS - CANAL SS T-LINE RECONDUC	1,531,312
249	74001584 STOCKTON A: REPLACE CONTROL BUILDING	1,524,445
250	74008301 Lower Bucks Dam Resurface Face	1,522,282
251	74010323 Poe PH Deck/Roof Resurface	1,505,083
252	74003484 WILSON: INSTALL STATCOM	1,504,758
253	74015248 TSRP NBS IT NEW MPLS	1,503,871
254	74020280 OAKLAND K: EM_REPLACE ALS RTU	1,496,104
255	74009588 Pit 7 U2 Rewind	1,493,738
256	74001397 (DA-TRC)ESSEX JCT ORICK 60KV RELIABILITY	1,488,818
257	74000622 BELLOTA - WARNERVILLE RECONDUCTOR	1,485,149
258	74000505 MARTIN: 230KV BUS RETROFIT	1,472,849
259	74007647 PEASE - TLINE SUPPORT	1,470,458
260	74001098 TABLE MOUNTAIN: REPLACE 500 KV BK 1	1,470,212
261	74018320 RMR: MTN VIEW-WHISMAN-AMES PROJECT (AMES	1,466,319
262	13002403 DS-C Relic- Conduct Studies	1,465,011
263	7055645 DS Relic- Coord Study w/ NID	1,457,743
264	74001579 OAKLAND L: CUTOVER 4 KV TO 12 KV	1,449,832
265	35047949 Z-1113 CIRCUIT RECONDUCTOR	1,447,405
266	74010363 KERN PP - LIVE OAK 115KV PROJECT	1,446,453
267	74001733 POTRERO-LARKIN #2 (A-Y2) SEISMIC RETROFI	1,437,707
268	74001734 MARTIN-LARKIN #1 115 KV CABLE (H-Y 1)	1,437,233
269	74009587 Pit 1 U1 Rewind Generator	1,436,015
270	74001855 EL CERRITO G: 115KV BUS UPGRADE T-LINE	1,428,078
271	68021224 PLO- U1:Replace AFW Chem Inj Pmp	1,421,077
272	74009061 WESTPARK: INSTALL MPAC BUILDING	1,416,659
273	74008750 HP-3 GROUNDING PROJECT	1,411,402
274	74001802 PIT PH 1: REPLACE 230 KV BK 1	1,411,046
275	74003261 Caribou 1 U1 Rewind	1,410,606
276	74014522 ORO LOMA: UPGRADE 70 KV BUS	1,408,897
277	7093170 Wildfire Wire Down detection	1,398,790
278	7049828 DC Relic Project Management	1,394,967
279	31155972 OSM EBOSS COFUNDING	1,390,463
280	74004618 SILVERADO-FULTON JCT 115KV NERC	1,384,455
281	74008009 WILSON-LEGRAND 115KV LINE RECON TL - DO	1,383,073
282	74015260 CASCADE: INSTALL BK 2 PHASE 1	1,381,063
283	74011982 MISSION BLVD DIST 30 HAYWARD R20A	1,380,843
284	74001686 NC_MAPLE CREEK PROJ-BUS RECONFIGURATION	1,369,960
285	13006781 DeSabla-Centerville Proj Mgmt Post LA	1,353,139
286	74003600 Helms Replace Load Center 1, 2, 7 & 8	1,331,654
287	7089886 Kerckhoff Rel PAD and NOI	1,320,555
288	74011243 IGNACIO-MARE ISL 115KV (HWY SUB/COR SUB)	1,301,384
289	74002796 COCO: REPLACE D-SCADA	1,290,923
290	74015249 TSRP-NORTH BAY SIERRA ET MPAC/HMI SUBSTA	1,278,712
291	74009901 Rock Cr PH U1 & U2 Repl WG Seals	1,248,879
292	74010362 PILOT: SAN BRUNO INT PIPE-TYPE UG CABLE	1,232,203
293	74015247 TSRP-NORTH BAY SIERRA ET NEW COMM SYSTEM	1,231,725
294	74001486 GRIZZLY PEAK BLVD BERKELEY R20A	1,223,680
295	74006664 RICE: EM REPLACE UNIT SUB 2	1,217,800
296	74010464 OLIVE SW STA-SMYRNA 115KV MAINTENANCE RE	1,201,884
297	74009501 Tiger Crk Abay LLO Gate Replace	1,197,997
298	74008922 VACA-TULUCAY-LAKEVILLE 230KV-NERC	1,196,386
299	74002547 Kings River PH - Replace Governor	1,188,342
300	74008421 Bucks Cr Modify 2 Cranes	1,180,523
301	74003069 LOS ESTEROS SHUNT REACTOR PROJECT	1,178,722
302	74003661 Bucks Creek U1 Generator Stator Rewind	1,178,121
303	74002167 HYAMPOM JCT: INSTALL T-SCADA CB 62	1,172,437
304	74001089 STOCKDALE 230 KV TAP #1 AND #2 FROM THE	1,169,293
305	31168741 ETTM MOREHEAD PARK	1,166,730
306	74004481 +MESA 1104 FEEDER - PHASE 1	1,161,207
307	74007445 Q1036 MUSTANG 2 (NU) 230 KV SS	1,154,391
308	74004508 LAKEWOOD SUB: REPLACE BANK 5	1,154,272
309	74001392 SOUTH OF PALERMO - PALERMO SUB	1,147,870
310	74002206 GLENN: REPLACE BK 1	1,147,214
311	74000665 BRIGHTON-GRAND ISLAND #1 & #2 115KV NERC	1,139,328
312	74008385 Coleman Decommission Asbury Pipe	1,136,821
313	74000733 CARIBOU-BIG BEND 115KV NERC	1,136,383
314	74014400 ASHLAN: REROUTE 230KV T-LINES	1,121,417
315	7093366 Dist Resources Planning Tools MA	1,114,320
316	7076871 Buck Rel Draft Lic App	1,113,730
317	74007447 PANOCHE-ORO LOMA 115 KV LINE RECONDUCTOR	1,108,160
318	74003620 Cresta PH Repl Tailrace Gates	1,102,409
319	74002545 Kings River - Repl Exciter	1,097,417
320	74009027 POTRERO: REPLACE SVC CONTROLLER	1,089,778
321	74003560 SKAGGS ISLAND: REM SUB	1,085,831
322	68045340 PLO: COM:ACCESS RD COMMUNICATIONS	1,081,955
323	74002818 KIRKER: INSTALL D-SCADA 2200	1,078,043
324	74003761 Rock Cr PH Repl Tailrace Gates	1,076,103
325	31234874 RELIAIBLITY 2017 - UWF VARIOUS CKTS	1,074,933
326	74004443 PITTSBURG: REPLACE CB 352 362	1,069,212
327	74002965 OAKLAND X: UPGD 115KV DIFF EDRS#: 201	1,068,652
328	74008666 EL CERRITO G: INST 12KV FDR OUTLET, PH 1	1,064,661
329	74010465 SMYRNA-SEMITROPIC-MIDWAY 115KV MAINTENAN	1,042,962
330	74001560 OAKLAND L: INSTALL 406, 407 CUTOVER 4KV	1,041,777
331	74010343 MARTIN: REPLACE 4KV SWITCHGEAR	1,041,281
332	74008383 Coleman Tailrace Barrier Trashrake	1,034,131
333	74009203 ROUND MTN: REPL 500KV RM-TAB MTN #1 REL	1,029,901
334	30978746 MUNI CENTRAL SUBWAY-CHINA TOWN STATI	1,029,226
335	74015486 ESTRELLA CPUC DATA REQUEST #3	1,028,982
336	74002176 CRESCENT MILLS: INSTALL D-SCADA CB210	1,012,873
337	See footnote for detail.	268,814,896
43		1,720,845,397

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Explain in a footnote any important adjustments during year. Explain in a footnote any difference between the amount for book cost of plant retired, Line 11, column (c), and that reported for electric plant in service, pages 204-207, column 9d), excluding retirements of non-depreciable property. The provisions of Account 108 in the Uniform System of accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.	Item (a)	Total (c + d + e) (b)	Electric Plant in Service (c)	Electric Plant Held for Future Use (d)	Electric Plant Leased To Others (e)
Section A. Balances and Changes During Year
1	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance Beginning of Year	25,630,993,906	25,630,993,906	0	0
2	Depreciation Provisions for Year, Charged to
3	DepreciationExpenseExcludingAdjustments (403) Depreciation Expense	2,121,424,880	2,121,424,880	100	100
4	DepreciationExpenseForAssetRetirementCosts (403.1) Depreciation Expense for Asset Retirement Costs	100	100	100	100
5	ExpensesOfElectricPlantLeasedToOthers (413) Exp. of Elec. Plt. Leas. to Others	100	100	100	100
6	TransportationExpensesClearing Transportation Expenses-Clearing	100	100	100	100
7	OtherClearingAccounts Other Clearing Accounts	100	100	100	100
8	OtherAccounts Other Accounts (Specify, details in footnote):
9.1		149,778,194	149,778,194
10	DepreciationProvision TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)	1,971,646,686	1,971,646,686	500	500
11	Net Charges for Plant Retired:
12	BookCostOfRetiredPlant Book Cost of Plant Retired	385,000,708	385,000,708	50	50
13	CostOfRemovalOfPlant Cost of Removal	292,499,258	292,499,258	50	50
14	SalvageValueOfRetiredPlant Salvage (Credit)	8,843,414	8,843,414	100	100
15	NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)	668,656,552	668,656,552	0	0
16	OtherAdjustmentsToAccumulatedDepreciation Other Debit or Cr. Items (Describe, details in footnote):
17.1		88,434,375	88,434,375
18	BookCostOfAssetRetirementCosts Book Cost or Asset Retirement Costs Retired	0	0	500	500
19	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)	26,845,549,665	26,845,549,665	0	0
Section B. Balances at End of Year According to Functional Classification
20	AccumulatedDepreciationSteamProduction Steam Production	309,485,888	309,485,888	100	100
21	AccumulatedDepreciationNuclearProduction Nuclear Production	6,706,852,865	6,706,852,865	100	100
22	AccumulatedDepreciationHydraulicProductionConventional Hydraulic Production-Conventional	1,403,250,911	1,403,250,911	100	100
23	AccumulatedDepreciationHydraulicProductionPumpedStorage Hydraulic Production-Pumped Storage	774,777,368	774,777,368	100	100
24	AccumulatedDepreciationOtherProduction Other Production	329,161,699	329,161,699	100	100
25	AccumulatedDepreciationTransmission Transmission	3,155,263,008	3,155,263,008	100	100
26	AccumulatedDepreciationDistribution Distribution	13,577,519,257	13,577,519,257	100	100
27	AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation	0	0	100	100
28	AccumulatedDepreciationGeneral General	589,238,669	589,238,669	800	800
29	AccumulatedProvisionForDepreciationOfElectricUtilityPlant TOTAL (Enter Total of lines 20 thru 28)	26,845,549,665	26,845,549,665	0	0

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
Report below investments in Account 123.1, Investments in Subsidiary Companies. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f). Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.	DescriptionOfInvestmentsInSubsidiaryCompanies Description of Investment (a)	DateOfAcquisitionInvestmentsInSubsidiaryCompanies Date Acquired (b)	DateOfMaturityInvestmentsInSubsidiaryCompanies Date of Maturity (c)	InvestmentInSubsidiaryCompanies Amount of Investment at Beginning of Year (d)	EquityInEarningsOfSubsidiaryCompanies Equity in Subsidiary Earnings of Year (e)	InterestAndDividendRevenueFromInvestments Revenues for Year (f)	InvestmentInSubsidiaryCompanies Amount of Investment at End of Year (g)	InvestmentGainLossOnDisplosal Gain or Loss from Investment Disposed of (h)
1	My Favorite Company
2	Paid in capital 1	01/01/2015	10/01/2025	48,859,587	41,809	1,179,049	50,080,445	200
3	PAG1	01/01/2015	10/01/2025	100	400	400	900	400
4	PAA1	01/01/2015	10/01/2025	100	300	300	700	300
5	Capital Contribution1	01/01/2015	10/01/2025	100	100	100	300	100
6	SubTotal			48,859,887	42,609	1,179,849	50,082,345	1,000
7	My Second Favorite Company
8	Paid in capital 2			0			0
9	SubTotal			0			0
42	Total Cost of Account 123.1 $ 99,999		Total	48,859,887	42,609	1,179,849	50,082,345	1,000

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

MATERIALS AND SUPPLIES
For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.	Account (a)	Balance Beginning of Year (b)	Balance End of Year (c)	Department or Departments which Use Material (d)
1	Fuel Stock (Account 151)	1,375,066	1,566,341	ELECTRIC
2	Fuel Stock Expenses Undistributed (Account 152)	100	100	ELECTRIC
3	Residuals and Extracted Products (Account 153)	100	100	ELECTRIC
4	Plant Materials and Operating Supplies (Account 154)
5	Assigned to - Construction (Estimated)	98,115,315	118,788,016	ALL
6
7	Production Plant (Estimated)	131,373,581	122,909,574	ALL
8	Transmission Plant (Estimated)	31,138,026	42,589,220	ALL
9	Distribution Plant (Estimated)	104,997,211	158,373,602	ALL
10	Regional Transmission and Market Operation Plant (Estimated)	100	100
11	Assigned to - Other (provide details in footnote)	200	200	ALL
12	TOTAL Account 154 (Enter Total of lines 5 thru 11)	365,624,033	442,660,312	ALL
13	Merchandise (Account 155)	100	100
14	Other Materials and Supplies (Account 156)	100	100
15	Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)	100	100
16	Stores Expense Undistributed (Account 163)	0	0	ALL
17
18
19
20	TOTAL Materials and Supplies	366,999,199	444,226,753

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Lines 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquire and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	SO2 Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year	10	10	10	10	10	10	10	10	10	10	50	50
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)	10	10	10	10	10	10	10	10	10	10	50	50
5	Returned by EPA	10	10	10	10	10	10	10	10	10	10	50	50
6
7
8	Purchases and Transfers1	10	10	10	10	10	10	10	10	10	10	50	50
9	Purchases and Transfers2	10	10	10	10	10	10	10	10	10	10	50	50
10
11
12
13
14
15	Total	20	20	20	20	20	20	20	20	20	20	100	100
16
17	Relinquished During Year:
18	Charges to Account 509	10	10	10	10	10	10	10	10	10	10	50	50
19	Other:
20	Allowances Used
20.1	Other Relinquished1	10	10	10	10	10	10	10	10	10	10	50	50
20.2	Other Relinquished2	10	10	10	10	10	10	10	10	10	10	50	50
21	Cost of Sales/Transfers:
22	Cost of Sales1	10	10	10	10	10	10	10	10	10	10	50	50
23	Cost of Sales2	10	10	10	10	10	10	10	10	10	10	50	50
24
25
26
27
28	Total	20	20	20	20	20	20	20	20	20	20	100	100
29	Balance-End of Year	100	100	100	100	100	100	100	100	100	100	500	500
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)	10	10	10	10	10	10	10	10	10	10	50	50
33	Net Sales Proceeds (Other)	10	10	10	10	10	10	10	10	10	10	50	50
34	Gains	10	10	10	10	10	10	10	10	10	10	50	50
35	Losses	10	10	10	10	10	10	10	10	10	10	50	50
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year	10	10	10	10	10	10	10	10	10	10	50	50
37	Add: Withheld by EPA	10	10	10	10	10	10	10	10	10	10	50	50
38	Deduct: Returned by EPA	10	10	10	10	10	10	10	10	10	10	50	50
39	Cost of Sales	10	10	10	10	10	10	10	10	10	10	50	50
40	Balance-End of Year	0	0	0	0	0	0	0	0	0	0	0	0
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)	10	10	10	10	10	10	10	10	10	10	50	50
44	Net Sales Proceeds (Other)	10	10	10	10	10	10	10	10	10	10	50	50
45	Gains	10	10	10	10	10	10	10	10	10	10	50	50
46	Losses	10	10	10	10	10	10	10	10	10	10	50	50

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Lines 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquire and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	NOx Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year	10	10	10	10	10	10	10	10	10	10	50	50
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)	10	10	10	10	10	10	10	10	10	10	50	50
5	Returned by EPA	10	10	10	10	10	10	10	10	10	10	50	50
6
7
8	Purchases and Transfers1	10	10	10	10	10	10	10	10	10	10	50	50
9	Purchases and Transfers2	10	10	10	10	10	10	10	10	10	10	50	50
10
11
12
13
14
15	Total	20	20	20	20	20	20	20	20	20	20	100	100
16
17	Relinquished During Year:
18	Charges to Account 509	10	10	10	10	10	10	10	10	10	10	50	50
19	Other:
20	Allowances Used	20	20	20	20	20	20	20	20	20	20	100	100
20.1	Other Relinquished1	10	10	10	10	10	10	10	10	10	10	50	50
20.2	Other Relinquished2	10	10	10	10	10	10	10	10	10	10	50	50
21	Cost of Sales/Transfers:
22	Cost of Sales1	10	10	10	10	10	10	10	10	10	10	50	50
23	Cost of Sales2	10	10	10	10	10	10	10	10	10	10	50	50
24
25
26
27
28	Total	20	20	20	20	20	20	20	20	20	20	100	100
29	Balance-End of Year	100	100	100	100	100	100	100	100	100	100	500	500
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)	10	10	10	10	10	10	10	10	10	10	50	50
33	Net Sales Proceeds (Other)	10	10	10	10	10	10	10	10	10	10	50	50
34	Gains	10	10	10	10	10	10	10	10	10	10	50	50
35	Losses	10	10	10	10	10	10	10	10	10	10	50	50
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year	10	10	10	10	10	10	10	10	10	10	50	50
37	Add: Withheld by EPA	10	10	10	10	10	10	10	10	10	10	50	50
38	Deduct: Returned by EPA	10	10	10	10	10	10	10	10	10	10	50	50
39	Cost of Sales	10	10	10	10	10	10	10	10	10	10	50	50
40	Balance-End of Year	0	0	0	0	0	0	0	0	0	0	0	0
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)	10	10	10	10	10	10	10	10	10	10	50	50
44	Net Sales Proceeds (Other)	10	10	10	10	10	10	10	10	10	10	50	50
45	Gains	10	10	10	10	10	10	10	10	10	10	50	50
46	Losses	10	10	10	10	10	10	10	10	10	10	50	50

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfExtraordinaryPropertyLoss Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).] (a)	ExtraordinaryPropertyLossesNotYetRecognized Total Amount of Loss (b)	ExtraordinaryPropertyLossesRecognized Losses Recognized During Year (c)	ExtraordinaryPropertyLossesWrittenOffAccountCharged Account Charged (d)	ExtraordinaryPropertyLossesWrittenOff Amount (e)	ExtraordinaryPropertyLosses Balance at End of Year (f)
1	ABC Substation	1,005	5	230	300	10,000
2	HIG Substation	5,010	10	230	400	10,000
20	TOTAL	6,015	15		700	0

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)] (a)	UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized Total Amount of Charges (b)	UnrecoveredPlantAndRegulatoryStudyCostsRecognized Costs Recognized During Year (c)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged Account Charged (d)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff Amount (e)	UnrecoveredPlantAndRegulatoryStudyCosts Balance at End of Year (f)
21	Santa Cruz 115kV Reinforcement	3,683,889	63,333	123	100	3,620,556
22	DCPP Relicensing	16,403,494	2,050,437	456	100	14,353,057
23	DCPP Canceled Orders	50,835,492	0	789	200	50,835,492
49	TOTAL	70,922,875	2,113,770		0	68,809,105

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

Transmission Service and Generation Interconnection Study Costs
Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. List each study separately. In column (a) provide the name of the study. In column (b) report the cost incurred to perform the study at the end of period. In column (c) report the account charged with the cost of the study. In column (d) report the amounts received for reimbursement of the study costs at end of period. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.	DescriptionOfStudyPerformed Description (a)	StudyCostsIncurred Costs Incurred During Period (b)	StudyCostsAccountCharged Account Charged (c)	StudyCostsReimbursements Reimbursements Received During the Period (d)	StudyCostsAccountReimbursed Account Credited With Reimbursement (e)
1	Transmission Studies
2	DEF	100	186	100	186
3	ABC	2,610,739	186	2,353,572	186
20	Total	2,610,839		2,353,472
21	Generation Studies
22	DEF2	100	187	100	187
23	ABC2	1,120,039	186	2,034,585	186
39	Total	1,120,139		2,034,485
40	Grand Total	3,730,978		4,387,957

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

OTHER REGULATORY ASSETS (Account 182.3)
Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Assets being amortized, show period of amortization.
				CREDITS
Line No.	DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a)	OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b)	IncreaseDecreaseInOtherRegulatoryAssets Debits (c)	OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d)	OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e)	OtherRegulatoryAssets Balance at end of Current Quarter/Year (f)
1	AB802 Memo Account - Electric	325,759	593,605	400		919,364
2	(amortization: < 12 months)
3	AB802 Memo Account - Gas	266,531	485,676	400		752,207
4	(amortization: < 12 months)
5	Acc Amt - Plant RA Tax	161,887,481		405	3,520,572	165,408,053
6	(amortization: 11 years)
7	Accum Amort - URG Plant Reg Asset	3,520,575		405		3,520,575
8	(amortization: < 12 months)
9	Accum Amort - URG Plant Reg Asset Non Current	646,489,723		405	42,243,000	688,732,723
10	(amortization: 12 years)
11	AMCDOP- Cost Adjust Mechanism	49,846,489	54,347,071	400	66,232,297	37,961,263
12	(amortization: < 12 months)
13	Balancing Account - Utility Generation	13,857,924	2,346,308,203	400	2,253,502,275	78,948,004
14	(amortization: < 12 months)
15	BCA Charge Account	440,258	3,228,320	400	2,721,930	946,648
16	(amortization: <12 months)
17	Biomass Memo Account	357,908	51,287,488	555	22,554,764	29,090,632
18	(amortization: < 12 months)
19	Bioram Memo Account	5,775,726	16,787,864	555	13,111,548	9,452,042
20	(amortization: < 12 months)
21	CA Alternate Rates for Energy Program-Electric	23,438,916	516,932,147	400	497,729,243	42,641,820
22	(amortization: < 12 months)
23	CA Alternate Rates for Energy Program-Gas	21,906,240	124,145,197	400	126,548,962	24,310,005
24	(amortization: < 12 months)
25	CA Solar Initiative Thermal Program Memo Account	6,742,115	7,446,999	400	6,190,940	7,998,174
26	(amortization: < 12 months)
27	Catastrophic Event Memorandum Account	527,923,691	821,286,585	182.3	681,331,001	667,879,275
28	(amortization: <12 months)
29	CEE Incentive Electric Balancing Account	2,471,330	21,457	400	3,750,049	1,257,262
30	(amortization: < 12 months)
31	CEE Incentive Gas Balancing Account	212,379	550,223	400	146,331	616,271
32	(amortization: < 12 months)
33	Core Brokerage Fee	1,183,803	6,507,572	400	6,539,622	1,151,753
34	Amortization : < 12 MONTHS
35	Core Fixed Cost Gas Balancing Account	288,383,643	2,583,642,839	400	2,538,624,137	333,402,345
36	(amortization: < 12 months)
37	Core Pipeline Demand Charge Account	12,944,626	507,268,450	400	506,722,166	13,490,910
38	(amortization: < 12 months)
39	Critical Docs Program memo Acct NC	6,260,968	5,760,560	182.3	3,577,132	8,444,396
40	(amortization: > 12 months)
41	DCRBA - DCPP Employee Retention Program		66,678,204	400	33,891,874	32,786,330
42	(amortization : > 12 months)
43	Deferred Debit - Gas Reserves (Contra Balancing Ac	206,150,601	338,716,664	400	466,934,661	334,368,598
44	(amortization: < 12 months)
45	Demand Response Expenditures BA - DRAM		4,773,654	182.3	18,298,415	13,524,761
46	(amortization: > 12 months)
47	Demand Response Expenditures B/A (DREBA)	7,884,859	36,450,378	400	36,287,129	7,721,610
48	amortization: < 12 months
49	Department of Energy Litigation Balancing Account	15,017,083	15,230,427	182.3	29,270,198	29,056,854
50	(amortization: > 12 months)
51	Diablo Canyon Seismic Studies Balancing Acct	17,360,285	4,636,128	182.3	12,723,018	9,273,395
52	(amortization: < 12 months)
53	Diablo Canyon Retirement Bal Acct (DEPR) - NC		24,083,136	400	2,090,749	21,992,387
54	(amortization: > 12 months)
55	Distribution Revenue Adjustment Mechanism	71,915,222	4,908,351,283	400	4,676,758,177	159,677,884
56	(amortization: < 12 months)
57	Distributed Resources Plan Memorandum Acct		1,211,975	400	716,598	495,377
58	(amortization: > 12 months)
59	Electric Balancing Account Reserve Account	999,999,999				999,999,999
60	Electric Balancing Account Reserve Account	999,999,999				999,999,999
61	Electric Balancing Account Reserve Account	999,999,999				999,999,999
62	Electric Balancing Account Reserve Account	707,101,109		400	292,898,890	999,999,999
63	Electric Balancing Account Reserve Account		748,968,524	400	999,999,999	251,031,475
64	Electric Balancing Account Reserve Account			400	133,840,006	133,840,006
65	(amortization: < 12 months)
66	Electric Hazardous Substance Balancing Account	35,775,193	75,060,107	182.3	71,623,102	39,212,198
67	(amortization: < 12 months)
68	Electric Price Risk Management - Current	43,680,363	149,761,224	555	166,073,774	27,367,813
69	Electric Price Risk Management - NonCurrent	64,887,869	286,879,321	555	262,053,131	89,714,059
70	Electric Program Investment Charge	4,303,871	93,744,038	400	100,847,846	2,799,937
71	(amortization: < 12 months)
72	End-Use Customer Refund Adjustment	18,724,310	13,531,597	400	2,572,825	7,765,538
73	(amortization: < 12 months)
74	Energy Recovery Bonds Balancing Account	3,772,785	47,868,046	400	90,491,604	46,396,343
75	(amortization: < 12 months)
76	Energy Resource Recovery Account	70,591,762	3,731,544,376	400	3,855,245,475	53,109,337
77	(amortization: < 12 months)
78	Environmental Compliance	159,159,599	92,687,558	182.3	28,568,149	223,279,008
79	(amortization: 32 years)
80	Environmental Compliance Non-HSM	40,989,049	4,164,084	228.4	5,883,630	39,269,503
81	(amortization: 32 years)
82	Family Electric Rate Assistance Balancing Acct	6,396,125	5,340,841	400	6,396,125	5,340,841
83	(amortization: < 12 months)
84	FIN 47 - Regulatory Asset	17,558,036	3,921,979	101	2,325,533	19,154,482
85	Financing Costs - Current	1,507,230		428	126,659	1,380,571
86	(amortization: < 12 months)
87	Financing Costs Regulatory Asset	17,025,505	126,659	428	1,495,281	15,656,883
88	(amortization: 20 years)
89	Fire Hazard Prevention Memo Acct	1,078,845	384,213,494	182.3	76,516,282	308,776,057
90	(amortization: < 12 Months)
91	Gas Core Firm Storage Account	2,836,042	73,689,333	400	72,263,354	4,262,021
92	(amortization: < 12 months)
93	Gas Hazardous Substance Balancing Account	83,475,448	174,970,574	182.3	166,950,894	91,495,128
94	(amortization: < 12 months)
95	Gas Hazardous Substance Regulatory Asset	375,144,418	213,630,555	182.3	67,790,619	520,984,354
96	(amortization: 32 years)
97	Gas Non-Hazardous Substance Regulatory Asset	133,533,910	1,098,204	228.4	1,559,252	133,072,862
98	(amortization: 32 years)
99	Gas Pipeline Expense and Capital Balancing Account	3,436,048	404,792	400	3,538,382	302,458
100	(amortization: <12 months)
101	Gas Price Risk Management - Current	1,084,177	5,561,104	807	4,984,714	1,660,567
102	GPBA-Greenhouse Gas Compliance Subaccount	157,201,621	97,708,033	400	203,017,081	51,892,573
103	(amortization: < 12 months)
104	Gas Public Purpose Program Surcharge Memo Acct	45,383,994	262,600,117	186	263,513,722	44,470,389
105	(amortization: < 12 months)
106	Gas Transmission and Storage Memo Account (GTSMA)	180,904,540	120,214,886	400	188,206,878	112,912,548
107	(amortization: < 12 months)
108	Gas Transmission and Storage Revenue Sharing Mech.	18,143,605	409,981,159	400	435,704,157	7,579,393
109	(amortization: < 12 months)
110	GPBA - GHG Operational Cost Subaccount	27,406,445	20,648,625	400	42,120,504	5,934,566
111	(amortization: < 12 months)
112	Green Tariff Shared Renewables Bal Acct	106,047	10,165,144	400	5,772,392	4,498,799
113	(amortization: < 12 months)
114	Greem Tariff Shared Renewables Memo Acct	4,996,470	1,545,419	400	883,302	5,658,587
115	(amortization: < 12 months)
116	Greenhouse Gas Expense Memo Account - E	1,892,397	901,485	400	28,770	1,019,682
117	Greenhouse Gas Expense Memo Account - G	334,859	889,891	400	374,120	850,630
118	(amortization: < 12 months)
119	Hydro Licensing Balancing Account	20,372,843	1,304,870	182.3	28,015,544	47,083,517
120	Hydro Pipeline Testing Memo Acct		90,115,840	182.3		90,115,840
121	(amortization: > 12 months)
122	Integrated Distribution Energy Resources Account	71,232	151,908	400		223,140
123	(amortization: > 12 months)
124	Land Conserv. Plan Env. Remediation Memo Acct.	746,381	1,400,211	182.3	746,382	1,400,210
125	(amortization: < 12 months)
126	Line 407 Memo Acct NC	301,110	3,468,913	182.3	295,206	3,474,817
127	(amortization: > 12 months)
128	Major Emergency Balancing Account	288,710	103,517,472	182.3	125,770,895	21,964,713
129	(amortization: < 12 Months)
130	Miscellaneous Elec-Current-FERC Interest Bearing		57,292,448	400	1,291	57,291,157
131	(amortization: < 12 months)
132	Miscellaneous Electric Reg Asset - Current	481,041,835	171,448,117	Various	623,567,816	28,922,136
133	(amortization: < 12 months)
134	Miscellaneous Electric Reg Asset - NonCurrent	9,638,677	413,600,941	549	259,694,970	163,544,648
135	(amortization: 25 years)
136	Miscellaneous Gas Reg Asset - Current	3,865,759	20,518,440	Various	443,763	23,940,436
137	(amortization: < 12 months)
138	Mobile Home Park Balancing Account - Electric	7,093,489	37,835,958	182.3	26,368,081	18,561,366
139	(amortization: < 12 months)
140	Mobile Home Park Balancing Account - Gas	7,269,902	37,119,683	182.3	26,764,471	17,625,114
141	(amortization: < 12 months)
142	Modified transition cost balancing account	10,808,975	110,636,874	400	81,724,460	18,103,439
143	(amortization: < 12 months)
144	Negative Ongoing Competition Transition Chrg BA	3,089,668,292	109,931,615	182.3	179,905	3,199,420,002
145	(amortization: < 12 months)
146	New System Generation BA	46,650,016	321,811,469	400	156,216,930	118,944,523
147	(amortization: < 12 months)
148	New Environmental Regulations Balancing Acct		34,249,572	182.3	23,699,624	10,549,948
149	(amortization: < 12 months)
150	Non Current HSM BA Elec	38,439,275	57,450,004	182.3	67,007,423	28,881,856
151	(amortization: > 12 months)
152	Non Current HSM BA Gas	89,691,641	134,050,008	182.3	156,350,654	67,390,995
153	(amortization: > 12 months)
154	Noncurr Wildfire Exp Memo Acct - Elec		213,354,963	182.3		213,354,963
155	(amortization: > 12 months)
156	Noncurr Wildfire Exp Memo Acct - Gas		103,948,670	182.3		103,948,670
157	(amortization: > 12 months)
158	Nuclear Decommissioning Adjustment Mechanism	45,752,788	69,235,497	400	40,935,684	17,452,975
159	(amortization: 2 years)
160	Nuclear Regulatory Commission Rulemaking Costs BA	8,001,467	42,424,044	182.3	36,255,129	14,170,382
161	(amortization: > 12 Months)
162	Pension Regulatory Asset	1,953,963,992	151,311,609	926	158,171,730	1,947,103,871
163	(amortization: indefinite)
164	Procurement Energy Efficiency Rev. Adj. Mechanism	11,603,488	334,265,163	400	337,429,250	8,439,401
165	(amortization: < 12 months)
166	Public Purpose Programs Revenue Adjustment Mech.	26,720,208	203,534,997	400	205,662,867	28,848,078
167	(amortization: < 12 months)
168	Purchased Gas Balancing Account	2,119,259	1,629,992,206	400	1,621,443,629	10,667,836
169	(amortization: < 12 months)
170	Reg Asset - Abandoned Capital Projects	18,324,235	20,622,784	400	13,928,167	25,018,852
171	(amortization: < 12 months)
172	Reg Asset - Mobilehome park BA - E Noncurrent	15,117,286	18,860,040	597	9,244,074	24,733,252
173	(amortization: < 12 months)
174	Reg Asset - Mobilehome park BA - G Noncurrent	17,475,604	16,982,398	893	6,741,494	27,716,508
175	(amortization: < 12 months)
176	Reg Asset - Mobilehome park BA - E Current	1,622,479	3,546,678	597	2,737,651	2,431,506
177	(amortization: < 12 months)
178	Reg Asset - Mobilehome park BA - G Current	1,806,908	3,990,547	893	3,066,169	2,731,286
179	(amortization: < 12 months)
180	Reg Asset - Hydro Non Current	10,758,023	107,529	400	9,107	10,856,445
181	(amortization: > 12 months)
182	Reg Asset - Cema Elec Non Current	322,049,440	910,598,355	588	239,781,569	992,866,226
183	(amortization: > 12 months)
184	Reg Asset - Cema Gas Non Current	26,429,472	24,417,732	388	2,128,697	48,718,507
185	(amortization: > 12 months)
186	Reg Asset - Miscellaneous Gas - Non-Current		101,035,834	925, 408.1	70,274,180	30,761,654
187	(amortization: > 12 months)
188	Reliability Services Balancing Account	410,816	69,850,963	400	125,330,531	55,890,384
189	(amortization: < 12 months)
190	Residential Rate Reform Memorandum Account (RRRMA)	19,253,940	18,292,957	182.3	20,910,559	16,636,338
191	(amortization: < 12 months)
192	Tax Normalization Memo Account (TNMA)	9,965,012	9,464,934	400	4,165,656	15,264,290
193	(amortization: > 12 months)
194	Transition Cost - Noncore Balancing Account	2,314,575	180,038,106	400	211,168,204	33,444,673
195	(amortization: < 12 months)
196	Transmission Access Charge Balancing Account	139,010,141	455,486,736	400	466,887,276	127,609,601
197	(amortization: < 12 months)
198	Transmission Revenue Balancing Account	101,030,150	269,566,411	400	239,282,193	70,745,932
199	(amortization: < 12 months)
200	Unamortized Financial Hedging Cost	12,779,845		428	836,195	11,943,650
201	(amortization: 20 years)
202	Unamortized Financial Hedging Cost Current	836,195		428		836,195
203	(amortization: < 12 months)
204	URG Plant Regulatory Asset - current	42,239,000		407.4		42,239,000
205	(amortization: < 12 months)
206	URG Plant Regulatory Asset - noncurrent	944,805,000		407.4		944,805,000
207	(amortization: 22 years)
208	URG Plant Regulatory Asset - Tax	183,010,953		182.3		183,010,953
209	(amortization: 11 years)
210	Vegetation Management Reg. Asset - Current	15,848,080	163,110,849	400	156,874,793	22,084,136
211	(amortization: < 12 months)
212	Wildfires Customer Protections Memo Acct - E		2,209,780	400		2,209,780
213	(amortization: > 12 months)
214	Wildfires Customer Protections Memo Acct - G		1,579,497	400		1,579,497
215	(amortization: > 12 months)
216	Miscellaneous minor items	219,928,700	359,284,630	Various	579,094,281	119,049
44	TOTAL	5,018,800,793	26,561,571,526		25,734,889,740	5,845,482,579

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

MISCELLANEOUS DEFFERED DEBITS (Account 186)
Report below the particulars (details) called for concerning miscellaneous deferred debits. For any deferred debit being amortized, show period of amortization in column (a) Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
				CREDITS
Line No.	Description of Miscellaneous Deferred Debits (a)	Balance at Beginning of Year (b)	Debits (c)	Credits Account Charged (d)	Credits Amount (e)	Balance at End of Year (f)
1	Undistributed Charges	10,756,425	1,138,612,174	VARIOUS	1,147,137,951	19,282,202
2	Customer Adv for Construction	7,277,615	1,154,553	VARIOUS	776,326	7,655,842
3	Development Costs	62,235,288	2,661,177	131	19,283,495	45,612,970
4	Payments for MLX and
5	Non-Energy Invoices	1,370,556	724,044,888	VARIOUS	724,006,244	1,409,200
6	Payments for Main Line
7	Extension	6,311,326	197,112,042	VARIOUS	202,297,724	11,497,008
8	Clearing Account for
9	JP Morgan Chase	1,271,127	23,841,842	VARIOUS	24,006,900	1,106,069
10	Payroll Clearing Account	201,506	12,670,981,026	VARIOUS	12,670,843,910	338,622
11	Land Surplus	480,219	559,044	930.2		1,039,263
12	Credit Card Clearing Account	275,299	8,520,349	VARIOUS	7,963,968	281,082
13	Miscellaneous minor items	58,403	131,790,040	VARIOUS	132,439,144	590,701
47	Miscellaneous Work in Progress
48	Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49	TOTAL	55,551,664				26,073,137

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

ACCUMULATED DEFERRED INCOME TAXES (Account 190)
Report the information called for below concerning the respondent’s accounting for deferred income taxes. At Other (Specify), include deferrals relating to other income and deductions.
Line No.	DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a)	AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b)	AccumulatedDeferredIncomeTaxes Balance at End of Year (c)
1	Electric
2	Environmental	93,803,083	42,478,580
3	Compensation	94,297,980	50,033,114
4	CIAC	146,286,875	121,829,617
5	Injuries and Damages	102,846,333	3,478,176,873
6	California Corporation Franchise Tax	161,001,489	145,217,541
7	Other	170,762,620	437,277,748
8	TOTAL Electric (Enter Total of lines 2 thru 7)	52,706,776	3,071,841,583
9	Gas
10	Environmental	57,056,261	77,136,703
11	Compensation	45,329,183	36,918,182
12	CIAC	204,929,511	168,443,372
13	Injuries and Damages	54,950,921	39,315,702
14	California Corporation Franchise Tax	26,584,707	45,289,022
15	Other	1,223,174,711	1,372,702,830
16	TOTAL Gas (Enter Total of lines 10 thru 15)	1,334,841,516	1,416,322,957
17	Other (Specify)	446,026,682	537,426,086
18	TOTAL (Acct 190) (Total of lines 8, 16 and 17)	1,728,161,422	5,025,590,626

Notes

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

CAPITAL STOCKS (Account 201 and 204)
Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.	Class and Series of Stock and Name of Stock Series (a)	Number of Shares Authorized by Charter (b)	Par or Stated Value per Share (c)	Call Price at End of Year (d)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares (e)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount (f)	Held by Respondent As Reacquired Stock (Acct 217) Shares (g)	Held by Respondent As Reacquired Stock (Acct 217) Cost (h)	Held by Respondent In Sinking and Other Funds Shares (i)	Held by Respondent In Sinking and Other Funds Amount (j)
1	Common Stock (Account 201)
2	Class A Common Stock	10,000,000			900,000	10		100,000
3	Class B Common Stock	10,000,000			900,000	1,321,874,035		100,000
14	Total	20,000,000			1,800,000	1,321,874,045
15	Preferred Stock (Account 204)
16	Preferred Stock A	2,000,000	5	10	1,000,000	100	100,000	100,000	100,000	100,000
17	Preferred Stock B	2,000,000	5	10	1,000,000	257,994,475	100,000	100,000	100,000	100,000
38	Total	4,000,000			2,000,000	257,994,575
1	Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5	Total

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2019-04-16

Year/Period of Report

End of:

2018

Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.	Item (a)	Amount (b)
1	DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208)
2	DonationsReceivedFromStockholders Beginning Balance Amount	3,000
3.1	IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Donations from Stockholder A	1,000
3.2	IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Donations from Stockholder B	2,000
3	IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Increases (Decreases) from Sales of Donations Received from Stockholders	3,000
4	DonationsReceivedFromStockholders Ending Balance Amount	0
5	ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209)
6	ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount	500
7.1	IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock Reduction ABC	200
7.2	IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock Reduction CED	300
7	IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock	500
8	ReductionInParOrStatedValueOfCapitalStock Ending Balance Amount	0
9	GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10	GainOnResaleOrCancellationOfReacquiredCapitalStock Beginning Balance Amount	6,735,547,928
11.1	IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock Common Stock	40,000,000
11.2	IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock Preferred Stock	5,000,000
12	GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount	6,780,547,928
13	MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211)
14	MiscellaneousPaidInCapital Beginning Balance Amount	300
15.1	IncreasesDecreasesDueToMiscellaneousPaidInCapital Equity Infusions from Parent Company	100
15.2	IncreasesDecreasesDueToMiscellaneousPaidInCapital Excess Tax Benefit on Stock Based Compensation	200
15	IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Miscellaneous Paid-In Capital	300
16	MiscellaneousPaidInCapital Ending Balance Amount	0
17	OtherPaidInCapitalAbstract Historical Data - Other Paid in Capital
18	OtherPaidInCapitalDetail Beginning Balance Amount
19	IncreasesDecreasesInOtherPaidInCapital Increases (Decreases) in Other Paid-In Capital
20	OtherPaidInCapitalDetail Ending Balance Amount
40	OtherPaidInCapital Total	6,780,547,928

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

CAPITAL STOCK EXPENSE (Account 214)
Report the balance at end of the year of discount on capital stock for each class and series of capital stock. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.	NameOfClassAndSeriesOfStock Class and Series of Stock (a)	CapitalStockExpense Balance at End of Year (b)
1	COMMON	25,143,083
2	4.36%	29,509
3	4.50%	387,663
4	4.80%	777,999
5	5.00%	1,758,375
6	5.00% - Series A	158,204
7	5.00%	73,717
8	5.50%	173,730
9	6.00%	449,606
22	TOTAL	28,951,886

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

LONG-TERM DEBT (Account 221, 222, 223 and 224)
Report by Balance Sheet Account the details concerning long-term debt included in Account 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (f). Explain in a footnote any difference between the total of column (f) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.	ClassAndSeriesOfObligationCouponRateDescription Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a)	RelatedAccountNumber Related Account Number (b)	Principal Amount of Debt Issued (c)	LongTermDebtIssuanceExpensePremiumOrDiscount Total Expense, Premium or Discount (d)	LongTermDebtIssuanceExpenses Total Expense (e)	LongTermDebtPremium Total Premium (f)	LongTermDebtDiscount Total Discount (g)	NominalDateOfIssue Nominal Date of Issue (h)	DateOfMaturity Date of Maturity (i)	AmortizationPeriodStartDate AMORTIZATION PERIOD Date From (j)	AmortizationPeriodEndDate AMORTIZATION PERIOD Date To (k)	Outstanding (Total amount outstanding without reduction for amounts held by respondent) (l)	Interest for Year Amount (m)
1	Bonds (Account 221)
2	ACCOUNT 221:
3	SENIOR NOTES & POLLUTION CONTROL BONDS:
4	Series Rate
5	Series 6.05% Senior Notes due 2034 6.050%		3,000,000,000		30,717,515			(a) 03/23/2004	(ar) 03/01/2034	(ch) 03/23/2004	(dy) 03/01/2034	3,000,000,000	181,500,000
6					14,640,000
7	Series 5.80% Senior Notes due 2037 5.800%		700,000,000		6,807,234			(b) 03/13/2007	(as) 03/01/2037	(ci) 03/13/2007	(dz) 03/01/2037	700,000,000	40,600,000
8					3,822,000
9	Series 6.35% Senior Notes due 2038 6.350%		400,000,000		3,943,976			(c) 03/03/2008	(at) 02/15/2038	(cj) 03/03/2008	(ea) 02/15/2038	400,000,000	25,400,000
10					568,000
11	Series 8.25% Senior Notes due 2018 8.250%		600,000,000		4,572,075			(d) 10/21/2008	(au) 10/15/2018	(ck) 10/21/2008	(eb) 10/15/2018		2,154,167
12					9,942,000
13	Series 8.25% Senior Notes due 2018 8.250%		200,000,000		1,511,598			(e) 11/18/2008	(av) 10/15/2018	(cl) 11/18/2008	(ec) 10/15/2018		2,154,167
14					8,950,000
15	Series 6.25% Senior Notes due 2039 6.250%		550,000,000		5,145,853			(f) 03/06/2009	(aw) 03/01/2039	(cm) 03/06/2009	(ed) 03/01/2039	550,000,000	34,375,000
16					6,814,500
17	Series 5.4% Senior Notes due 2040 5.400%		550,000,000		5,435,842			(g) 11/18/2009	(ax) 01/15/2040	(cn) 11/18/2009	(ee) 01/15/2040	550,000,000	29,700,000
18					7,815,500
19	Series 5.8% Senior Notes due 2037 5.800%		250,000,000		2,562,097			(h) 04/01/2010	(ay) 03/01/2037	(co) 04/01/2010	(ef) 03/01/2037	250,000,000	14,500,000
20					3,862,500
21	Series 3.5% Senior Notes due 2020 3.500%		550,000,000		4,205,770			(i) 09/15/2010	(az) 10/01/2020	(cp) 09/15/2010	(eg) 10/01/2020	550,000,000	19,250,000
22					2,728,000
23	Series 3.5% Senior Notes due 2020 3.500%		250,000,000		1,897,267			(j) 11/18/2010	(ba) 10/01/2020	(cq) 11/18/2010	(eh) 10/01/2020	250,000,000	8,750,000
24					6,840,000
25	Series 5.4% Senior Notes due 2040 5.400%		250,000,000		2,459,767			(k) 11/18/2010	(bb) 01/15/2040	(cr) 11/18/2010	(ei) 01/15/2040	250,000,000	13,500,000
26					6,252,500
27	Series 4.25% Senior Notes due 2021 4.250%		300,000,000		2,270,404			(l) 05/13/2011	(bc) 05/15/2021	(cs) 05/13/2011	(ej) 05/15/2021	300,000,000	12,750,000
28					243,000
29	Series 3.25% Senior Notes due 2021 3.250%		250,000,000		1,981,515			(m) 09/12/2011	(bd) 09/15/2021	(ct) 09/12/2011	(ek) 09/15/2021	250,000,000	8,125,000
30					1,312,500
31	Series 4.5% Senior Notes due 2041 4.50%		250,000,000		2,576,302			(n) 12/01/2011	(be) 12/15/2041	(cu) 12/01/2011	(el) 12/15/2041	250,000,000	11,250,000
32					862,500
33	Series 4.45% Senior Notes due 2042 4.45%		400,000,000		4,062,665			(o) 04/16/2012	(bf) 04/15/2042	(cv) 04/16/2012	(em) 04/15/2042	400,000,000	17,800,000
34					2,036,000
35	Series 2.45% Senior Notes due 2022 2.45%		400,000,000		3,251,743			(p) 08/16/2012	(bg) 08/16/2022	(cw) 08/16/2012	(en) 08/16/2022	400,000,000	9,800,000
36					1,164,000
37	Series 3.75% Senior Notes due 2042 3.75%		350,000,000		3,632,775			(q) 08/16/2012	(bh) 08/16/2042	(cx) 08/16/2012	(eo) 08/16/2042	350,000,000	13,125,000
38					311,500
39	Series 3.25% Senior Notes due 2023 3.25%		375,000,000		2,924,964			(r) 06/14/2013	(bi) 06/15/2023	(cy) 06/14/2013	(ep) 06/15/2023	375,000,000	12,187,500
40					1,901,250
41	Series 4.6% Senior Notes due 2043 4.60%		375,000,000		3,768,714			(s) 06/14/2013	(bj) 06/15/2043	(cz) 06/14/2013	(eq) 06/15/2043	375,000,000	17,250,000
42					303,750
43	Series 3.85% Senior Notes due 2023 3.85%		300,000,000		2,505,170			(t) 11/12/2013	(bk) 11/15/2023	(da) 11/12/2013	(er) 11/15/2023	300,000,000	11,550,000
44					543,000
45	Series 5.125% Senior Notes due 2043 5.125%		500,000,000		5,099,524			(u) 11/12/2013	(bl) 11/15/2043	(db) 11/12/2013	(es) 11/15/2043	500,000,000	25,625,000
46					765,000
47	Series 3.75% Senior Notes due 2024 3.75%		450,000,000		3,672,801			(v) 02/21/2014	(bm) 02/15/2024	(dc) 02/21/2014	(et) 02/15/2024	450,000,000	16,875,000
48					445,500
49	Series 4.75% Senior Notes due 2044 4.75%		450,000,000		4,685,300			(w) 02/21/2014	(bn) 02/15/2044	(dd) 02/21/2014	(eu) 02/15/2044	450,000,000	21,375,000
50					1,921,500
51	Series 3.4% Senior Notes due 2024 3.40%		350,000,000		2,788,492			(x) 08/18/2014	(bo) 08/15/2024	(de) 08/18/2014	(ev) 08/15/2024	350,000,000	11,900,000
52					262,500
53	Series 4.75% Senior Notes due 2044 4.75%		225,000,000		2,298,853			(y) 08/18/2014	(bp) 02/15/2044	(df) 08/18/2014	(ew) 02/15/2044	225,000,000	10,687,500
54					13,594,500
55	Series 4.3% Senior Notes due 2045 4.30%		500,000,000		5,051,799			(z) 11/06/2014	(bq) 03/15/2045	(dg) 11/06/2014	(ex) 03/15/2045	500,000,000	21,500,000
56					5,745,000
57	Series 3.50% Senior Notes due 2025 3.50%		400,000,000		3,471,059			(aa) 06/12/2015	(br) 06/15/2025	(dh) 06/12/2015	(ey) 06/15/2025	400,000,000	14,000,000
58					2,540,000
59	Series 4.30% Senior Notes due 2045 4.30%		100,000,000		1,092,707			(ab) 06/12/2015	(bs) 03/15/2045	(di) 06/12/2015	(ez) 03/15/2045	100,000,000	4,300,000
60					5,231,000
61	Series 3.50% Senior Notes due 2025 3.50%		200,000,000		1,709,814			(ac) 11/05/2015	(bt) 06/15/2025	(dj) 11/05/2015	(fa) 06/15/2025	200,000,000	7,000,000
62					2,716,000
63	Series 4.25% Senior Notes due 2046 4.25%		450,000,000		4,859,582			(ad) 11/05/2015	(bu) 03/15/2046	(dk) 11/05/2015	(fb) 03/15/2046	450,000,000	19,125,000
64					8,415,000
65	Series 2.95% Senior Notes due 2026 2.95%		600,000,000		5,241,785			(ae) 03/01/2016	(bv) 03/01/2026	(dl) 03/01/2016	(fc) 03/01/2026	600,000,000	17,700,000
66					1,596,000
67	Series 4.00% Senior Notes due 2046 4.00%		400,000,000		4,345,973			(af) 12/01/2016	(bw) 12/01/2046	(dm) 12/01/2016	(fd) 12/01/2046	400,000,000	16,000,000
68					7,344,000
69	Series 4.00% Senior Notes due 2046 4.00%		200,000,000		2,102,746			(ag) 03/10/2017	(bx) 12/01/2046	(dn) 03/10/2017	(fe) 12/01/2046	200,000,000	8,000,000
70					4,136,000
71	Series 3.30% Senior Notes due 2027 3.30%		400,000,000		3,306,994			(ah) 03/10/2017	(by) 03/15/2027	(do) 03/10/2017	(ff) 03/15/2027	400,000,000	13,200,000
72					1,420,000
73	Series 3.30% Senior Notes due 2027 3.30%		1,150,000,000		9,322,742			(ai) 11/29/2017	(bz) 12/01/2027	(dp) 11/29/2017	(fg) 12/01/2027	1,150,000,000	37,950,000
74					3,404,000
75	Series 3.95% Senior Notes due 2047 3.95%		850,000,000		8,803,613			(aj) 11/29/2017	(ca) 12/01/2047	(dq) 11/29/2017	(fh) 12/01/2047	850,000,000	33,575,000
76					3,706,000
77	Series 4.25% Senior Notes due 2023 4.25%		500,000,000		4,061,237			(ak) 08/06/2018	(cb) 08/01/2023	(dr) 08/06/2018	(fi) 08/01/2023	500,000,000	8,559,028
78					1,175,000
79	Series 4.65% Senior Notes due 2028 4.65%		300,000,000		2,587,341			(al) 08/06/2018	(cc) 08/01/2028	(ds) 08/06/2018	(fj) 08/01/2028	300,000,000	5,618,750
80					852,000
81	Pollution Control Bonds
82	1996 Series C/E/F Various		465,000,000		2,485,410			(am) 05/23/1996	(cd) 11/01/2026	(dt) 05/23/1996	(fk) 11/01/2026	465,000,000	6,176,618
83	1997 Series B Various		148,550,000		886,179			(an) 09/16/1997	(ce) 11/01/2026	(du) 09/16/1997	(fl) 11/01/2026	148,550,000	2,047,926
84	2008 Series F-G Various		95,000,000		312,026			(ao) 06/15/2017		(dv) 06/15/2017		50,000,000	1,308,124
85	2009 Series A-B Various		148,550,000		806,484			(ap) 09/01/2009	(cf) 11/01/2026	(dw) 09/01/2009	(fm) 11/01/2026	148,550,000	1,965,341
86	2010 Series E 1.75%		50,000,000		328,903			(aq) 06/15/2017	(cg) 11/01/2026	(dx) 06/15/2017	(fn) 11/01/2026	50,000,000	875,000
87	SUBTOTAL ACCOUNT 221
50	Subtotal		19,232,100,000		271,215,110							18,387,100,000	791,084,121
51	Reacquired Bonds (Account 222)
52	2020 Series A	222	5,000,005		10,000	1,000	4,000	06/15/2017	11/01/2026	06/15/2017	11/01/2026	5,000,001	50,000
53	2020 Series B	222	6,000,005		20,000	5,000	3,000	06/15/2016	11/01/2036	06/15/2016	11/01/2029	6,000,002	90,000
54	Subtotal		11,000,010		30,000	6,000	7,000					11,000,003	140,000
55	Advances from Associated Companies (Account 223)
56	2021 Series C	223	3,000,000		3,000	4,000	5,000	06/15/2016	11/01/2036	06/15/2016	11/01/2029	3,000,006	40,000
57	2021 Series D	223	4,000,000		7,000	6,000	5,000	06/15/2017	11/01/2036	06/15/2016	11/01/2029	4,000,001	90,000
58	Subtotal		7,000,000		10,000	10,000	10,000					7,000,007	130,000
59	Other Long Term Debt (Account 224)
60	2022 Series E	224	11,000,010		30,000	6,000	7,000	06/15/2018	11/01/2046	06/15/2016	11/01/2029	11,000,003	140,000
61	2022 Series F	224	7,000,000		10,000	10,000	10,000	06/15/2018	11/01/2046	06/15/2016	11/01/2029	7,000,007	130,000
62	Subtotal		18,000,010		40,000	16,000	17,000					18,000,010	270,000
33	TOTAL		19,232,100,000									18,387,100,000	791,084,121

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

FOOTNOTE DATA

(a) Concept: NominalDateOfIssue

3/23/04

(b) Concept: NominalDateOfIssue

3/13/07

3/3/08

(d) Concept: NominalDateOfIssue

10/21/08

(e) Concept: NominalDateOfIssue

11/18/08

(f) Concept: NominalDateOfIssue

3/6/09

(g) Concept: NominalDateOfIssue

11/18/09

(h) Concept: NominalDateOfIssue

4/1/10

(i) Concept: NominalDateOfIssue

9/15/10

(j) Concept: NominalDateOfIssue

11/18/10

(k) Concept: NominalDateOfIssue

11/18/10

(l) Concept: NominalDateOfIssue

5/13/11

(m) Concept: NominalDateOfIssue

9/12/11

(n) Concept: NominalDateOfIssue

12/1/11

(o) Concept: NominalDateOfIssue

4/16/2012

(p) Concept: NominalDateOfIssue

8/16/12

(q) Concept: NominalDateOfIssue

8/16/12

(r) Concept: NominalDateOfIssue

6/14/13

(s) Concept: NominalDateOfIssue

6/14/13

(t) Concept: NominalDateOfIssue

11/12/13

(u) Concept: NominalDateOfIssue

11/12/13

(v) Concept: NominalDateOfIssue

2/21/14

(w) Concept: NominalDateOfIssue

2/21/14

(x) Concept: NominalDateOfIssue

8/18/14

(y) Concept: NominalDateOfIssue

8/18/14

(z) Concept: NominalDateOfIssue

11/6/14

(aa) Concept: NominalDateOfIssue

6/12/15

(ab) Concept: NominalDateOfIssue

6/12/15

(ac) Concept: NominalDateOfIssue

11/5/15

(ad) Concept: NominalDateOfIssue

11/5/15

(ae) Concept: NominalDateOfIssue

3/1/16

(af) Concept: NominalDateOfIssue

12/1/16

(ag) Concept: NominalDateOfIssue

3/10/2017

(ah) Concept: NominalDateOfIssue

3/10/17

(ai) Concept: NominalDateOfIssue

11/29/17

(aj) Concept: NominalDateOfIssue

11/29/17

(ak) Concept: NominalDateOfIssue

8/6/2018

(al) Concept: NominalDateOfIssue

8/6/2018

(am) Concept: NominalDateOfIssue

5/23/96

(an) Concept: NominalDateOfIssue

9/16/97

(ao) Concept: NominalDateOfIssue

6/15/17

(ap) Concept: NominalDateOfIssue

9/1/09

(aq) Concept: NominalDateOfIssue

6/15/17

(ar) Concept: DateOfMaturity

3/1/34

(as) Concept: DateOfMaturity

3/1/37

(at) Concept: DateOfMaturity

2/15/38

(au) Concept: DateOfMaturity

10/15/18

(av) Concept: DateOfMaturity

10/15/18

(aw) Concept: DateOfMaturity

3/1/39

(ax) Concept: DateOfMaturity

1/15/40

(ay) Concept: DateOfMaturity

3/1/37

(az) Concept: DateOfMaturity

10/1/20

(ba) Concept: DateOfMaturity

10/1/20

(bb) Concept: DateOfMaturity

1/15/40

(bc) Concept: DateOfMaturity

5/15/21

(bd) Concept: DateOfMaturity

9/15/21

(be) Concept: DateOfMaturity

12/15/41

(bf) Concept: DateOfMaturity

4/15/42

(bg) Concept: DateOfMaturity

8/16/22

(bh) Concept: DateOfMaturity

8/16/42

(bi) Concept: DateOfMaturity

6/15/23

(bj) Concept: DateOfMaturity

6/15/43

(bk) Concept: DateOfMaturity

11/15/23

(bl) Concept: DateOfMaturity

11/15/43

(bm) Concept: DateOfMaturity

2/15/24

(bn) Concept: DateOfMaturity

2/15/44

(bo) Concept: DateOfMaturity

8/15/24

(bp) Concept: DateOfMaturity

2/15/44

(bq) Concept: DateOfMaturity

3/15/45

(br) Concept: DateOfMaturity

6/15/25

(bs) Concept: DateOfMaturity

3/15/45

(bt) Concept: DateOfMaturity

6/15/25

(bu) Concept: DateOfMaturity

3/15/46

(bv) Concept: DateOfMaturity

3/1/26

(bw) Concept: DateOfMaturity

12/1/46

(bx) Concept: DateOfMaturity

12/1/2046

(by) Concept: DateOfMaturity

3/15/27

(bz) Concept: DateOfMaturity

12/1/27

(ca) Concept: DateOfMaturity

12/1/47

(cb) Concept: DateOfMaturity

8/1/2023

(cc) Concept: DateOfMaturity

8/1/2028

(cd) Concept: DateOfMaturity

11/1/26

(ce) Concept: DateOfMaturity

11/1/26

(cf) Concept: DateOfMaturity

11/1/26

(cg) Concept: DateOfMaturity

11/1/26

(ch) Concept: AmortizationPeriodStartDate

3/23/04

(ci) Concept: AmortizationPeriodStartDate

3/13/07

(cj) Concept: AmortizationPeriodStartDate

3/3/08

(ck) Concept: AmortizationPeriodStartDate

10/21/08

(cl) Concept: AmortizationPeriodStartDate

11/18/08

(cm) Concept: AmortizationPeriodStartDate

3/6/09

(cn) Concept: AmortizationPeriodStartDate

11/18/09

(co) Concept: AmortizationPeriodStartDate

4/1/10

(cp) Concept: AmortizationPeriodStartDate

9/15/10

(cq) Concept: AmortizationPeriodStartDate

11/18/10

(cr) Concept: AmortizationPeriodStartDate

11/18/10

(cs) Concept: AmortizationPeriodStartDate

5/13/11

(ct) Concept: AmortizationPeriodStartDate

9/12/11

(cu) Concept: AmortizationPeriodStartDate

12/1/11

(cv) Concept: AmortizationPeriodStartDate

4/16/12

(cw) Concept: AmortizationPeriodStartDate

8/16/12

(cx) Concept: AmortizationPeriodStartDate

8/16/12

(cy) Concept: AmortizationPeriodStartDate

6/14/13

(cz) Concept: AmortizationPeriodStartDate

6/14/13

(da) Concept: AmortizationPeriodStartDate

11/12/13

(db) Concept: AmortizationPeriodStartDate

11/12/13

(dc) Concept: AmortizationPeriodStartDate

2/21/14

(dd) Concept: AmortizationPeriodStartDate

2/21/14

(de) Concept: AmortizationPeriodStartDate

8/18/14

(df) Concept: AmortizationPeriodStartDate

8/18/14

(dg) Concept: AmortizationPeriodStartDate

11/6/14

(dh) Concept: AmortizationPeriodStartDate

6/12/15

(di) Concept: AmortizationPeriodStartDate

6/12/15

(dj) Concept: AmortizationPeriodStartDate

11/5/15

(dk) Concept: AmortizationPeriodStartDate

11/5/15

(dl) Concept: AmortizationPeriodStartDate

3/1/16

(dm) Concept: AmortizationPeriodStartDate

12/1/16

(dn) Concept: AmortizationPeriodStartDate

3/10/2017

(do) Concept: AmortizationPeriodStartDate

3/10/17

(dp) Concept: AmortizationPeriodStartDate

11/29/17

(dq) Concept: AmortizationPeriodStartDate

11/29/17

(dr) Concept: AmortizationPeriodStartDate

8/6/2018

(ds) Concept: AmortizationPeriodStartDate

8/6/2018

(dt) Concept: AmortizationPeriodStartDate

5/23/96

(du) Concept: AmortizationPeriodStartDate

9/16/97

(dv) Concept: AmortizationPeriodStartDate

6/15/17

(dw) Concept: AmortizationPeriodStartDate

9/1/09

(dx) Concept: AmortizationPeriodStartDate

6/15/17

(dy) Concept: AmortizationPeriodEndDate

3/1/34

(dz) Concept: AmortizationPeriodEndDate

3/1/37

(ea) Concept: AmortizationPeriodEndDate

2/15/38

(eb) Concept: AmortizationPeriodEndDate

10/15/18

(ec) Concept: AmortizationPeriodEndDate

10/15/18

(ed) Concept: AmortizationPeriodEndDate

3/1/39

(ee) Concept: AmortizationPeriodEndDate

1/15/40

(ef) Concept: AmortizationPeriodEndDate

3/1/37

(eg) Concept: AmortizationPeriodEndDate

10/1/20

(eh) Concept: AmortizationPeriodEndDate

10/1/20

(ei) Concept: AmortizationPeriodEndDate

1/15/40

(ej) Concept: AmortizationPeriodEndDate

5/15/21

(ek) Concept: AmortizationPeriodEndDate

9/15/21

(el) Concept: AmortizationPeriodEndDate

12/15/41

(em) Concept: AmortizationPeriodEndDate

4/15/42

(en) Concept: AmortizationPeriodEndDate

8/16/22

(eo) Concept: AmortizationPeriodEndDate

8/16/42

(ep) Concept: AmortizationPeriodEndDate

6/15/23

(eq) Concept: AmortizationPeriodEndDate

6/15/43

(er) Concept: AmortizationPeriodEndDate

11/15/23

(es) Concept: AmortizationPeriodEndDate

11/15/43

(et) Concept: AmortizationPeriodEndDate

2/15/24

(eu) Concept: AmortizationPeriodEndDate

2/15/44

(ev) Concept: AmortizationPeriodEndDate

8/15/24

(ew) Concept: AmortizationPeriodEndDate

2/15/44

(ex) Concept: AmortizationPeriodEndDate

3/15/45

(ey) Concept: AmortizationPeriodEndDate

6/15/25

(ez) Concept: AmortizationPeriodEndDate

3/15/45

(fa) Concept: AmortizationPeriodEndDate

6/15/25

(fb) Concept: AmortizationPeriodEndDate

3/15/46

(fc) Concept: AmortizationPeriodEndDate

3/1/26

(fd) Concept: AmortizationPeriodEndDate

12/1/46

(fe) Concept: AmortizationPeriodEndDate

12/1/2046

(ff) Concept: AmortizationPeriodEndDate

3/15/27

(fg) Concept: AmortizationPeriodEndDate

12/1/27

(fh) Concept: AmortizationPeriodEndDate

12/1/47

(fi) Concept: AmortizationPeriodEndDate

8/1/2023

(fj) Concept: AmortizationPeriodEndDate

8/1/2028

(fk) Concept: AmortizationPeriodEndDate

11/1/26

(fl) Concept: AmortizationPeriodEndDate

11/1/26

(fm) Concept: AmortizationPeriodEndDate

11/1/26

(fn) Concept: AmortizationPeriodEndDate

11/1/26

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.	Particulars (Details) (a)	Amount (b)
1	Net Income for the Year (Page 117)	6,818,107,469
2	Reconciling Items for the Year
3
4	Taxable Income Not Reported on Books
5	Contributions In Aid of Construction	238,818,033
9	Deductions Recorded on Books Not Deducted for Return
10	Provision for Federal Income Taxes	2,278,988,662
11	Provision for State Income Taxes	1,015,977,063
12	Per attached schedule (See page 261-1)	13,175,614,895
14	Income Recorded on Books Not Included in Return
15	AFUDC - Equity and debt	181,542,106
16	Balancing Accounts	536,745,233
19	Deductions on Return Not Charged Against Book Income
20	Per attached schedule (See page 261-1)	2,027,348,975
27	Federal Tax Net Income	555,723,419
28	Show Computation of Tax:
29	Federal Tax Net Income as above $	116,701,918
30	Tax at 21% for Electric, Water. Non-Utility, and Gas
31	Other
32	Add: Tax on FIN 48 Interest	298,573
33	Less: Research & Development Credits	4,187,435
34	Less: Motor Vehicle Credit	750,000
35	Foreign Tax Credit Adjustment Resuting From Specified Liability Losk	4,236,131
36	Utilization of Net Operating Loss Carryover	104,000,477
37	Subtotal Tax	12,298,710
38	FIN 48 Tax Adjustments (Net to Gross)
39	Total Tax	12,298,710
40	Federal Income Tax Accrual	12,298,710

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are know, show the amounts in a footnote and designate whether estimated or actual amounts. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. If any tax (exclude Federal and State income taxes)- covers more then one year, show the required information separately for each tax year, identifying the year in column (d). Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (o) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
					BALANCE AT BEGINNING OF YEAR					BALANCE AT END OF YEAR		DISTRIBUTION OF TAXES CHARGED
Line No.	DescriptionOfTaxesAccruedPrepaidAndCharged Kind of Tax (See Instruction 5) (a)	TypeOfTax Type of Tax (b)	TaxJurisdiction State (c)	TaxYear Tax Year (d)	TaxesAccrued Taxes Accrued (Account 236) (e)	PrepaidTaxes Prepaid Taxes (Include in Account 165) (f)	TaxesCharged Taxes Charged During Year (g)	TaxesPaid Taxes Paid During Year (h)	TaxAdjustments Adjustments (i)	TaxesAccrued Taxes Accrued (Account 236) (j)	PrepaidTaxes Prepaid Taxes (Included in Account 165) (k)	TaxesAccruedPrepaidAndCharged Electric (Account 408.1, 409.1) (l)	IncomeTaxesExtraordinaryItems Extraordinary Items (Account 409.3) (m)	AdjustmentsToRetainedEarnings Adjustment to Ret. Earnings (Account 439) (n)	TaxesIncurredOther Other (o)
1	TX Local	Local Tax	TX	2018	12,206,965	0	96,230,144	103,781,479	0	4,655,630	0	65,141,285	0	0	31,088,859
2	Federal - Taxes on Income	Federal Tax	Federal	2019	301,702,762	0	12,298,710	188,653	4,236,129	309,576,690	0	4,236,133	0	0	8,062,577
3	Federal - Unemployment	Unemployment Tax	CT	2018	3,874,854	0	1,077,997	5,007,018	0	54,167	0	724,845	0	0	353,152
4	Fule Tax	Fuel Tax	CT	2018			33,367,070	33,367,070	0			33,367,070	0	0	0
5	State - Taxes on Income	State Tax	NY	2016	111,930,507	0	16,339,589	59,269,453	10,164,738	46,486,203	0	112,005,442	0	0	128,345,031
6	Miscellaneous Other Tax	Miscellaneous Other Tax	NH	2018	90,611	0	8,068,926	8,053,559	0	105,978	0	5,425,546	0	0	2,643,380
7	Ad Valorem property	Property Tax	NY	2017	1,103	0	470,923,474	491,853,474	20,930,000	1,103	0	355,073,218	0	0	115,850,256
8	Other	Other Taxes	NJ	2019	3,589,980	0	23,184,765	27,047,777	0	273,032	0	15,589,436	0	0	7,595,329
40	TOTAL				433,396,782	0	628,811,497	728,568,483	26,858,609	360,498,405	0	591,562,975	0	0	37,248,522

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g).Include in column (i) the average period over which the tax credits are amortized.
			Deferred for Year		Allocations to Current Year's Income
Line No.	Account Subdivisions (a)	Balance at Beginning of Year (b)	Account No. (c)	Amount (d)	Account No. (e)	Amount (f)	Adjustments (g)	Balance at End of Year (h)	Average Period of Allocation to Income (i)	ADJUSTMENT EXPLANATION (j)
1	Electric Utility
2	10%	93,325,105	233	0	411.5	4,652,206	0	88,672,899	18	Adjustment1
8	TOTAL Electric (Enter Total of lines 2 thru 7)	93,325,105				4,652,206		88,672,899
9	Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10	10%	20,708,685	234	0	411.5	997,701	0	19,710,984	22	Adjustment2
11	Adjustments	0		0		0	0	0
47	OTHER TOTAL	20,708,685				997,701		19,710,984
48	GRAND TOTAL	114,033,790						108,383,883

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

OTHER DEFERRED CREDITS (Account 253)
Report below the particulars (details) called for concerning other deferred credits. For any deferred credit being amortized, show the period of amortization. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
			DEBITS
Line No.	Description and Other Deferred Credits (a)	Balance at Beginning of Year (b)	Contra Account (c)	Amount (d)	Credits (e)	Balance at End of Year (f)
1	CIAC Deferred Revenue	150,728,145	143, 146,456	51,059,826	67,340,832	167,009,151
2	Deferred Cr - Electric Reserves	44,650,027	182, 232,926	1,405	2,087,504	46,736,126
3	Other	12,716,162	Various	18,799,660	19,649,646	13,566,148
47	TOTAL	208,094,334		69,860,891	89,077,982	227,311,425

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Accelerated Amortization (Account 281)
2	Electric
3	Defense Facilities	0	200	200	300	300	281	400	281	400	0
4	Pollution Control Facilities	0	500	500	600	600	281	700	281	700	0
5	Other
5.1	Settlement Regulatory Asset	307									307
8	TOTAL Electric (Enter Total of lines 3 thru 7)	307									307
9	Gas
10	Defense Facilities
11	Pollution Control Facilities
12	Other
12.1	Settlement	0	101	101	201	201		301		301	0
15	TOTAL Gas (Enter Total of lines 10 thru 14)	0	101	101	201	201		301		301	0
16	Other
16.1	Other
16.2	Other
17	TOTAL (Acct 281) (Total of 8, 15 and 16)	307									307
18	Classification of TOTAL
19	Federal Income Tax	307	10	10	20	20	281	30	281	30	307
20	State Income Tax	0	1	1	2	2	283	3	283	3	0
21	Local Income Tax	0	5	5	6	6	284	3	284	3	0

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 282
2	Electric	5,866,193,157	567,068,431	246,450,716	0	0	123	0	123	624,198,615	4,921,376,827
3	Gas	1,477,659,791	4,695,705	142,021,557	0	0	123	0	123	1,052,105,146	2,667,090,789
4	Other (Specify)	50,526,203	0	0	14,757,291	153,745,799	456	166,290,765	789	0	385,320,058
5	Total (Total of lines 2 thru 4)	7,394,379,151	571,764,136	388,472,273	14,757,291	153,745,799		166,290,765		427,906,531	7,973,787,674
6
7
8
9	TOTAL Account 282 (Total of Lines 5 thru 8)	7,394,379,151	571,764,136	388,472,273	14,757,291	153,745,799		166,290,765		427,906,531	7,973,787,674
10	Classification of TOTAL
11	Federal Income Tax	5,790,140,411	503,086,946	260,939,801	10,113,424	153,512,599	235	175,076,548	236	332,934,582	6,219,630,419
12	State Income Tax	1,604,238,740	68,677,189	127,532,472	4,643,867	233,200	235	8,785,783	236	94,971,948	1,581,784,925
13	Local Income Tax	0	0	0	0	0	233	0	237	0	0

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
Report the information called for below concerning the respondent’s accounting for deferred income taxes relating to amounts recorded in Account 283. For other (Specify),include deferrals relating to other income and deductions. Provide in the space below explanations for Page 276 and 277. Include amounts relating to insignificant items listed under Other. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 283
2	Electric
3	Loss on Reacquired Debt	46,351,590	17,583,231	29,197,869	0	0	235	0	236	0	34,736,952
4	Balancing Accounts	142,447,428	25,734,058	81,541,543	0	0	235	0	236	102,489,643	352,212,672
5	Other	2,495,951	1,741,064	14,529,089	0	0	235	0	236		18,766,104
9	TOTAL Electric (Total of lines 3 thru 8)	191,294,969	45,058,353	66,872,763	0	0		0		102,489,643	405,715,728
10	Gas
11	Loss on Reacquired Debt	21,963,589	5,789,837	11,015,454	0	0	235	0	236	0	16,737,972
12	Balancing Accounts	268,468,323	23,957,685	99,713,602	0	0	235	0	236	25,112,667	217,825,073
13	Other	2,161,432	597,013	98,562	0	0	235	0	236	0	1,662,981
17	TOTAL Gas (Total of lines 11 thru 16)	288,270,480	30,344,535	110,827,618	0	0		0		25,112,667	232,900,064
18	TOTAL Other	31,348,386	0	0	11,307,727	1,458,408	123	0	456	0	21,499,067
19	TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)	448,217,063	75,402,888	43,954,855	11,307,727	1,458,408		0		127,602,310	617,116,725
20	Classification of TOTAL
21	Federal Income Tax	393,514,962	20,436,820	40,112,798	11,310,245	1,458,408				41,843,093	425,533,914
22	State Income Tax	54,702,101	54,966,068	3,842,057	2,518					85,759,217	191,582,811
23	Local Income Tax
NOTES

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

OTHER REGULATORY LIABILITIES (Account 254)
Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Liabilities being amortized, show period of amortization.
			DEBITS
Line No.	Description and Purpose of Other Regulatory Liabilities (a)	Balance at Beginning of Current Quarter/Year (b)	Account Credited (c)	Amount (d)	Credits (e)	Balance at End of Current Quarter/Year (f)
1	CA Energy Systems 21st Centur B/A Elect NC	308,024	182.3	3,536,524	3,460,596	383,952
2	(amortization: 5 years)
3	California Solar Initiative	66,414,573	400	14,016,129	9,220,917	61,619,361
4	(amortization: 5 years)
5	Demand Response Expenditures Balancing Account	57,642,744	400	69,069,154	51,492,499	40,066,089
6	Distribution Resource Plan Demo B/A Curr	107,978	400	235,686	1,067,647	939,939
7	(amortization: <12 months)
8	DREBA Operations Balancing Account - Current	24,840,637	400	25,169,788	12,458,361	12,129,210
9	Electric Vehicle Program BA Current	1,972,297	400	13,432,047	18,915,509	3,511,165
10	(amortization: <12 months)
11	Electric Price Risk Management - Current	26,867,115	555	104,655,510	120,740,007	42,951,612
12	Electric Price Risk Management - NonCurrent	101,500,411	555	375,684,882	439,345,727	165,161,256
13	Electric Program Investment Charge Balancing Acct	173,193,908	400	90,142,787	106,454,386	189,505,507
14	Engineering Critical Assessment Bal ACCT-CURRENT		400	9,848,830	73,668,433	63,819,603
15	(amortization: <12 months)
16	FAS 109 Reg Liability	1,020,833,435	400	5,397,386,422	4,660,041,025	283,488,038
17	(amortization: >12 months)
18	FAS 143 Regulatory Liability - Nuclear	999,999,999	Various			999,999,999
19	FAS 143 Regulatory Liability - Nuclear	574,459,931		254,460,135	136,957,777	691,962,289
20	FAS 143 Regulatory Liability - Fossil	132,024,941	Various	13,861,210		145,886,151
21	FAS 143 Regulatory Liability - Fossil Decomm	176,633,546	228.4	7,769,312		168,864,234
22	FAS 143 Regulatory Liability-Nuclear Decomm	2,863,247,225	128	588,388,705	454,862,836	2,729,721,356
23	FIN 47 Regulatory Liability	709,047,472	Various	580,609,698	584,794,371	704,862,799
24	Gas PPP Surcharge-RDD	398,165	400	12,095,232	12,058,377	435,020
25	(amortization: <12 months)
26	Gas Price Risk Management - Current	376,079	807	9,427,335	9,504,259	453,003
27	GHGRBA - Greenhouse Gas Revenue Subaccount	89,838,359	400	464,936,605	348,977,027	26,121,219
28	(amortization: <12 months)
29	GHGRBA - Low Carbon Fuels Stnd Rev Subaccount	18,626,564	400	17,572,385	61,611,607	62,665,786
30	(amortization: <12 months)
31	GPBA - Greenhouse Gas Revenue Subaccount	222,829,867	400	331,869,052	109,298,352	259,167
32	(amortization: <12 months)
33	GPBA - Low Carbon Fuels Stnd Rev Subaccount	685,998	400	443,920	391,047	633,125
34	(amortization: <12 months)
35	Miscellaneous Electric Reg Liab - Current	80,613,478	449	99,581,295	343,955,376	324,987,559
36	(amortization: <12 months)
37	Miscellaneous Electric Reg Liab - NonCurrent	245,025,521	549	50,428,889	355,395,957	549,992,589
38	MISCELLANEOUS GAS REG LIAB - CURRENT	9	495	61,085,215	101,987,163	40,901,957
39	Amortization : <12 MONTHS
40	MISCELLANEOUS GAS REG LIAB - NONCURRENT	19,026,468	549	6,158,348	3,382,670	16,250,790
41	Amortization : 2 YEARS
42	NATIONAL GAS LEAK ABATEMENT PROGRAM BALANCING ACT		400	1,145,007	2,166,870	1,021,863
43	(amortization: < 12 months)
44	NON CURRENT REG LIAB-CC8 SETTLEMENT	46,856,179	108	2,260,506		44,595,673
45	(amortization: < 12 months)
46	Amortization : 25 YEARS
47	NON-TARIFFED PRODUCTS AND SVCS BA-ELECTRIC	321,567	182.3	2,434,436	2,688,612	575,743
48	Amortization : < 12 MONTHS
49	NON-TARIFFED PRODUCTS AND SVCS BA-GAS	262,995	182.3	304,707	511,842	470,130
50	Amortization : < 12 MONTHS
51	ON BILL FINANCING BALANCING ELECTRIC	44,053,920	930.2	13,595,803	12,413,062	42,871,179
52	ON BILL FINANCING BALANCING GAS	9,541,493	930.2	2,589,677	2,387,522	9,339,338
53	PPP (PPPLIBA)-ELECTRIC	161,760,083	400	77,081,759	88,351,838	173,030,162
54	Amortization : < 12 MONTHS
55	PPP (PPPLIBA)-GAS	57,115,769	400	59,190,195	79,331,373	77,256,947
56	Amortization : < 12 MONTHS
57	PPP ENERGY EFFICIENCY-GAS	3,523,260	400	1,368,582	329,218	2,483,896
58	PPP SURCHARGE ENERGY EFFICIENCY - GAS	6,165,082	400	97,896,209	90,617,259	1,113,868
59	Amortization : < 12 MONTHS
60	PPP SURCHARGE LOW INCOME - GAS	8,697,021	400	79,311,319	80,449,644	7,558,696
61	Amortization : < 12 MONTHS
62	PPP SURCHARGE RDD - CURRENT	3,589,636	182.3	11,069,274	11,097,731	3,618,093
63	Amortization : < 12 MONTHS
64	PROCUREMENT ENERGY EFFICIENCY	15,108,043	400	6,234,784	1,480,986	10,354,245
65	PROCUREMENT ENERGY EFFICIENCY BALANCING ACCT - CT	121,365,565	400	363,403,980	447,494,954	205,456,539
66	Amortization : <12 MONTHS
67	PUBL PURP PROG ENERGY EFFICIENCY BAL ACCT - CURRT	24,615,780	400	78,711,291	94,747,059	40,651,548
68	Amortization : <12 MONTHS
69	REG LIABILITY GAS RISK MGMT - NONCURRENT	629,984	807	797,660	306,342	138,666
70	REG LIABILITY-MISC ELEC CURRENT -FERC INTEREST BG		400	1,686	74,837,561	74,835,875
71	Amortization : <12 MONTHS
72	REGULATORY LIABILITY RETIREM	418,061,715	520	34,704,994	37,298,481	420,655,202
73	Amortization : INDEFINITE
74	RULE 20A BALANCING ACCOUNT (RBA) NONCURRENT		400	18,110,041	11,472,486	6,637,555
75	Amortization : > 12 MONTHS
76	SELF GENERATION PROGARM-GAS	35,020,030	400	5,040,192	13,822,471	43,802,309
77	SELF GENERATION PROGRAM - ELECTRIC	180,387,537	400	22,960,873	63,388,316	220,814,980
78	SOLAR ON MULTIFAMILY AFFORDABLE HOUSING BAL ACCT		400		51,081,839	51,081,839
79	Amortization : < 12 MONTHS
80	SW MARKETING, EDUCATION AND OUTREACH PROGRAM BA	4,349,169	400	14,652,489	11,904,138	1,600,818
81	Amortization : < 12 MONTHS
82	SW MARKETING, EDUCATION AND OUTREACH PROGRAM BA	755,732	400	1,620,822	1,321,828	456,738
83	Amortization : < 12 MONTHS
84	TAMA - GAS	64,490,315	182.3	36,799,024		101,289,339
85	Amortization : 2 YEARS
86	Miscellanous minor items	45,716,209	Various	1,237,268,178	1,191,551,974	5
41	TOTAL	3,876,105,498		10,770,418,583	10,391,095,332	3,496,782,247

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

Electric Operating Revenues
The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The -average number of customers means the average of twelve figures at the close of each month. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.) See pages 108-109, Important Changes During Period, for important new territory added and important rate increase or decreases. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.	Title of Account (a)	Operating Revenues Year to Date Quarterly/Annual (b)	Operating Revenues Previous year (no Quarterly) (c)	MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d)	MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e)	AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f)	AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g)
1	SalesOfElectricityHeadingAbstract Sales of Electricity
2	ResidentialSalesAbstract (440) Residential Sales	700		80,065,844		15
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)	700		70		15
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)	12,843,421,215		70		15
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting	700		70		15
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities	700		70		15
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways	700		70		15
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales	700		70		5,471,687
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers	12,843,425,415	13,919,611,883	80,066,264	82,513,923	5,471,777	5,479,889
11	SalesForResaleAbstract (447) Sales for Resale	326,502,665	112,554,619	10,790,942	5,661,727
12	SalesOfElectricityAbstract TOTAL Sales of Electricity	13,169,928,080	14,032,166,502	90,857,206	88,175,650	5,471,777	5,479,889
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds	580,325,469	169,512,710	0		15
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds	12,589,602,611	13,862,653,792	90,857,206	88,175,650	5,471,762	5,479,889
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts	4,139,504	5,496,959
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues	9,362,424	9,650,326
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power	3,683,870	3,621,831
19	RentFromElectricProperty (454) Rent from Electric Property	104,364,515	86,527,942
20	InterdepartmentalRents (455) Interdepartmental Rents	0
21	OtherElectricRevenue (456) Other Electric Revenues	262,517,205	343,369,626
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	1,845,837	2,830,782
23	RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues	404	0
24	MiscellaneousRevenue (457.2) Miscellaneous Revenues	0	0
25	OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues
25.1	OtherMiscellaneousOperatingRevenues (400) Balancing Accounts	635,580,851	343,783,254
26	OtherOperatingRevenues TOTAL Other Operating Revenues	496,459,796	579,025,040
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	13,086,062,407	13,283,628,752
Line12, column (b) includes $ 3600 of unbilled revenues.
Line12, column (d) includes $ 360 MWH relating to unbilled revenues

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.	Description of Service (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	ABC	100	200	300	400
2	CDEF	1	2	3	4
46	TOTAL	101	202	303	404

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	Residential1	10	100	10	10	10
2	Residential2	20	200	20	20	20
41	TOTAL Billed Residential Sales	30	300	15	15	15
42	TOTAL Unbilled Rev. (See Instr. 6)	40	400			40
43	TOTAL	80,065,844	700	15	15	15

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	Commerical1	10	100	10	10	10
2	Commerical2	20	200	20	20	20
41	TOTAL Billed Small or Commercial	30	300	15	15	15
42	TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)	40	400			40
43	TOTAL Small or Commercial	70	700	15	15	15

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	Industrial1	10	100	10	10	10
2	Industrial2	20	200	20	20	20
41	TOTAL Billed Large (or Ind.) Sales	30	10	15	15	15
42	TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)	40	12,843,421,205			40
43	TOTAL Large (or Ind.)	70	12,843,421,215	15	15	15

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	Commerical and Industrial1	10	100	10	10	10
2	Commerical and Industrial2	20	200	20	20	20
41	TOTAL Billed Commercial and Industrial Sales	30	300	15	15	15
42	TOTAL Unbilled Rev. (See Instr. 6)	40	400			40
43	TOTAL	70	700	15	15	15

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	Public street1	10	100	10	10	10
2	Public street2	20	200	20	20	20
41	TOTAL Billed Public Street and Highway Lighting	30	300	15	15	15
42	TOTAL Unbilled Rev. (See Instr. 6)	40	400			40
43	TOTAL	70	700	15	15	15

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	Other Sales1	10	100	10	10	10
2	Other Sales2	20	200	20	20	20
41	TOTAL Billed Other Sales to Public Authorities	30	300	15	15	15
42	TOTAL Unbilled Rev. (See Instr. 6)	40	400			40
43	TOTAL	70	700	15	15	15

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	Sales to Railroads1	10	100	10	10	10
2	Sales to Railroads2	20	200	20	20	20
41	TOTAL Billed Sales To Railroads and Railways	30	300	15	15	15
42	TOTAL Unbilled Rev. (See Instr. 6)	40	400			40
43	TOTAL	70	700	15	15	15

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	Interdepartment1	10	100	10	10	10
2	Interdepartment2	20	200	20	20	20
41	TOTAL Billed Interdepartmental Sales	30	300	15	15	15
42	TOTAL Unbilled Rev. (See Instr. 6)	40	400			40
43	TOTAL	70	700	5,471,687	15	15

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	Provision1	10	100	10	10	10
2	Provision2	20	200	20	20	20
41	TOTAL Billed Provision For Rate Refunds	30	10	15	15	15
42	TOTAL Unbilled Rev. (See Instr. 6)	0	580,325,459			40
43	TOTAL	0	580,325,469	15	15	15

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
41	TOTAL Billed - All Accounts	270	1,810	15	15	15
42	TOTAL Unbilled Rev. (See Instr. 6) - All Accounts	360	12,843,423,605	15	15	15
43	TOTAL - All Accounts	630	12,843,425,415	15	15	15

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SALES FOR RESALE (Account 447)
Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k). In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24. Footnote entries as required and provide explanations following all required data.
					ACTUAL DEMAND (MW)			REVENUE
Line No.	Name of Company or Public Authority (Footnote Affiliations) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Average Monthly Billing Demand (MW) (d)	Average Monthly NCP Demand (e)	Average Monthly CP Demand (f)	Megawatt Hours Sold (g)	Demand Charges ($) (h)	Energy Charges ($) (i)	Other Charges ($) (j)	Total ($) (h+i+j) (k)
1	Silicon Valley Power	RQ	248	0.4	17.7	17.7	1,843	1,071	39,544	0	40,615
2	California Independent System Operator	RQ	6	0.6	18.8	19.9	10,789,099	0	344,976,739	18,514,689	326,462,050
15	Subtotal - RQ						10,790,942	1,071	345,016,283	18,514,689	326,502,665
16	Subtotal-Non-RQ							0	0	0	0
17	Total						10,790,942	1,071	345,016,283	18,514,689	326,502,665

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures, explain in footnote.
Line No.	Account (a)	Amount for Current Year (b)	Amount for Previous Year (c) (c)
1	PowerProductionExpensesAbstract 1. POWER PRODUCTION EXPENSES
2	SteamPowerGenerationAbstract A. Steam Power Generation
3	SteamPowerGenerationOperationAbstract Operation
4	OperationSupervisionAndEngineeringSteamPowerGeneration (500) Operation Supervision and Engineering	55,323	1,413
5	FuelSteamPowerGeneration (501) Fuel	207,064,898	176,832,878
6	SteamExpensesSteamPowerGeneration (502) Steam Expenses	16,174	10,249
7	SteamFromOtherSources (503) Steam from Other Sources	0	0
8	SteamTransferredCredit (Less) (504) Steam Transferred-Cr.	0	0
9	ElectricExpensesSteamPowerGeneration (505) Electric Expenses	0	0
10	MiscellaneousSteamPowerExpenses (506) Miscellaneous Steam Power Expenses	388,314	651,480
11	RentsSteamPowerGeneration (507) Rents	0	0
12	Allowances (509) Allowances	35,626,112	27,272,848
13	SteamPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 4 thru 12)	243,150,821	204,768,868
14	SteamPowerGenerationMaintenanceAbstract Maintenance
15	MaintenanceSupervisionAndEngineeringSteamPowerGeneration (510) Maintenance Supervision and Engineering	129,982	17,771
16	MaintenanceOfStructuresSteamPowerGeneration (511) Maintenance of Structures	0	0
17	MaintenanceOfBoilerPlantSteamPowerGeneration (512) Maintenance of Boiler Plant	1,478,290	1,669,805
18	MaintenanceOfElectricPlantSteamPowerGeneration (513) Maintenance of Electric Plant	19,232,845	11,150,358
19	MaintenanceOfMiscellaneousSteamPlant (514) Maintenance of Miscellaneous Steam Plant	1,691,099	4,324,333
20	SteamPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 15 thru 19)	22,532,216	5,138,449
21	PowerProductionExpensesSteamPower TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)	265,683,037	199,630,419
22	NuclearPowerGenerationAbstract B. Nuclear Power Generation
23	NuclearPowerGenerationOperationAbstract Operation
24	OperationSupervisionAndEngineeringNuclearPowerGeneration (517) Operation Supervision and Engineering	4,025,966	6,147,760
25	NuclearFuelExpense (518) Fuel	129,114,087	124,868,867
26	CoolantsAndWater (519) Coolants and Water	37,292,499	30,611,193
27	SteamExpensesNuclearPowerGeneration (520) Steam Expenses	38,815,499	38,190,638
28	SteamFromOtherSourcesNuclearPowerGeneration (521) Steam from Other Sources	0	0
29	SteamTransferredCreditNuclearPowerGeneration (Less) (522) Steam Transferred-Cr.	0	0
30	ElectricExpensesNuclearPowerGeneration (523) Electric Expenses	1,867,685	1,998,438
31	MiscellaneousNuclearPowerExpenses (524) Miscellaneous Nuclear Power Expenses	338,894,022	164,674,710
32	RentsNuclearPowerGeneration (525) Rents
33	NuclearPowerGenerationOperationsExpense TOTAL Operation (Enter Total of lines 24 thru 32)	550,009,758	366,491,606
34	NuclearPowerGenerationMaintenanceAbstract Maintenance
35	MaintenanceSupervisionAndEngineeringNuclearPowerGeneration (528) Maintenance Supervision and Engineering	2,782,594	3,239,200
36	MaintenanceOfStructuresNuclearPowerGeneration (529) Maintenance of Structures	3,442,055	1,104,975
37	MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration (530) Maintenance of Reactor Plant Equipment	26,816,759	29,240,710
38	MaintenanceOfElectricPlantNuclearPowerGeneration (531) Maintenance of Electric Plant	36,172,375	42,948,466
39	MaintenanceOfMiscellaneousNuclearPlant (532) Maintenance of Miscellaneous Nuclear Plant	83,619,837	57,119,138
40	NuclearPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 35 thru 39)	14,406,054	133,652,489
41	PowerProductionExpensesNuclearPower TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)	535,603,704	500,144,095
42	HydraulicPowerGenerationAbstract C. Hydraulic Power Generation
43	HydraulicPowerGenerationOperationAbstract Operation
44	OperationSupervisionAndEngineeringHydraulicPowerGeneration (535) Operation Supervision and Engineering	448,001	2,199,949
45	WaterForPower (536) Water for Power	2,190,879	2,128,801
46	HydraulicExpenses (537) Hydraulic Expenses	1,449,339	1,317,581
47	ElectricExpensesHydraulicPowerGeneration (538) Electric Expenses	26,715,623	29,079,473
48	MiscellaneousHydraulicPowerGenerationExpenses (539) Miscellaneous Hydraulic Power Generation Expenses	60,364,066	65,379,284
49	RentsHydraulicPowerGeneration (540) Rents	796,739	785,420
50	HydraulicPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 44 thru 49)	91,964,647	100,890,508
51	HydraulicPowerGenerationContinuedAbstract C. Hydraulic Power Generation (Continued)
52	HydraulicPowerGenerationMaintenanceAbstract Maintenance
53	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration (541) Mainentance Supervision and Engineering	1,648,157	2,542,935
54	MaintenanceOfStructuresHydraulicPowerGeneration (542) Maintenance of Structures	2,122,736	5,802,047
55	MaintenanceOfReservoirsDamsAndWaterways (543) Maintenance of Reservoirs, Dams, and Waterways	23,269,718	35,462,156
56	MaintenanceOfElectricPlantHydraulicPowerGeneration (544) Maintenance of Electric Plant	19,942,182	21,197,455
57	MaintenanceOfMiscellaneousHydraulicPlant (545) Maintenance of Miscellaneous Hydraulic Plant	5,923,153	8,679,202
58	HydraulicPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 53 thru 57)	52,905,946	73,683,795
59	PowerProductionExpensesHydraulicPower TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)	144,870,593	174,574,303
60	OtherPowerGenerationAbstract D. Other Power Generation
61	OtherPowerGenerationOperationAbstract Operation
62	OperationSupervisionAndEngineeringOtherPowerGeneration (546) Operation Supervision and Engineering	593,029	186,426
63	Fuel (547) Fuel	0	0
64	GenerationExpenses (548) Generation Expenses	10,644,381	11,035,728
64.1	OperationOfEnergyStorageEquipment (548.1) Operation of Energy Storage Equipment	0	0
65	MiscellaneousOtherPowerGenerationExpenses (549) Miscellaneous Other Power Generation Expenses	939,016	3,161,565
66	RentsOtherPowerGeneration (550) Rents	0	0
67	OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67)	12,176,426	8,060,589
68	OtherPowerGenerationMaintenanceAbstract Maintenance
69	MaintenanceSupervisionAndEngineeringOtherPowerGeneration (551) Maintenance Supervision and Engineering	161,732	59,192
70	MaintenanceOfStructures (552) Maintenance of Structures	2,848,377	2,735,312
71	MaintenanceOfGeneratingAndElectricPlant (553) Maintenance of Generating and Electric Plant	7,166,782	5,487,309
71.1	MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration (553.1) Maintenance of Energy Storage Equipment	0	0
72	MaintenanceOfMiscellaneousOtherPowerGenerationPlant (554) Maintenance of Miscellaneous Other Power Generation Plant	5,692,471	2,924,933
73	OtherPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 69 thru 72)	15,869,362	11,206,746
74	PowerProductionExpensesOtherPower TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)	28,045,788	19,267,335
75	OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses
76	PurchasedPower (555) Purchased Power	3,496,844,586	3,852,611,625
76.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations	40	0
77	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching	0	0
78	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses	314,924,584	277,460,451
79	OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)	3,811,769,170	4,130,072,076
80	PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)	4,785,972,292	5,023,688,228
81	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
82	TransmissionExpensesOperationAbstract Operation
83	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	5,738,383	2,652,100
85	LoadDispatchReliability (561.1) Load Dispatch-Reliability	0	0
86	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System	32,099,953	28,980,843
87	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling	0	0
88	SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services	23,000,855	26,125,073
89	ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development	0	0
90	TransmissionServiceStudies (561.6) Transmission Service Studies	0	0
91	GenerationInterconnectionStudies (561.7) Generation Interconnection Studies	0	0
92	ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services	8,859,349	10,285,155
93	StationExpensesTransmissionExpense (562) Station Expenses	7,988,173	6,400,713
93.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment	0	0
94	OverheadLineExpense (563) Overhead Lines Expenses	13,924,543	6,577,810
95	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses	180,771	1,495,308
96	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	949,485	13,665,066
97	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	99,690,874	83,829,810
98	RentsTransmissionElectricExpense (567) Rents	0	0
99	TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98)	192,432,386	180,011,878
100	TransmissionMaintenanceAbstract Maintenance
101	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering	1,184,331	832,264
102	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	703,947	645,279
103	MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware	0	0
104	MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software	0	0
105	MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment	0	0
106	MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant	0	0
107	MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment	22,519,226	21,874,666
107.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment	0	0
108	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	129,824,961	96,349,282
109	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines	1,699,411	192,100
110	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant	725,484	1,070,803
111	TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110)	156,657,360	120,964,394
112	TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111)	349,089,746	300,976,272
113	RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES
114	RegionalMarketExpensesOperationAbstract Operation
115	OperationSupervision (575.1) Operation Supervision	1	1
116	DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation	1	1
117	TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation	1	1
118	CapacityMarketAdministration (575.4) Capacity Market Facilitation	1	1
119	AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation	1	1
120	MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance	1	1
121	MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services	13,832,802	14,650,901
122	RentsRegionalMarketExpenses (575.8) Rents	1	1
123	RegionalMarketOperationExpense Total Operation (Lines 115 thru 122)	13,832,809	14,650,908
124	RegionalMarketExpensesMaintenanceAbstract Maintenance
125	MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements	1	1
126	MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware	1	1
127	MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software	1	1
128	MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment	1	1
129	MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant	4	4
130	RegionalMarketMaintenanceExpense Total Maintenance (Lines 125 thru 129)	0	0
131	RegionalMarketExpenses TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)	13,832,809	14,650,908
132	DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES
133	DistributionExpensesOperationAbstract Operation
134	OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering	2,428,597	4,382,277
135	LoadDispatching (581) Load Dispatching	0	0
136	StationExpensesDistribution (582) Station Expenses	2,238,385	2,196,251
137	OverheadLineExpenses (583) Overhead Line Expenses	30,749,818	20,503,087
138	UndergroundLineExpenses (584) Underground Line Expenses	30,333,882	30,005,042
138.1	OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment	0	0
139	StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses	0	0
140	MeterExpenses (586) Meter Expenses	1,646,498	1,691,253
141	CustomerInstallationsExpenses (587) Customer Installations Expenses	15,512,197	14,004,409
142	MiscellaneousDistributionExpenses (588) Miscellaneous Expenses	240,620,319	37,055,570
143	RentsDistributionExpense (589) Rents	666,513	78,291
144	DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143)	324,196,209	109,916,180
145	DistributionExpensesMaintenanceAbstract Maintenance
146	MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering	1,165,788	4,493,803
147	MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures	2,824,259	2,542,906
148	MaintenanceOfStationEquipment (592) Maintenance of Station Equipment	26,624,095	26,724,342
148.1	MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment	0	0
149	MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines	751,642,765	528,832,572
150	MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines	38,420,026	41,892,183
151	MaintenanceOfLineTransformers (595) Maintenance of Line Transformers	1,817,300	2,125,962
152	MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems	1,738,254	2,056,782
153	MaintenanceOfMeters (597) Maintenance of Meters	7,806,252	7,058,358
154	MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant	733,849	680,573
155	DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154)	832,772,588	616,407,481
156	DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155)	1,156,968,797	726,323,661
157	CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES
158	CustomerAccountsExpensesOperationsAbstract Operation
159	SupervisionCustomerAccountExpenses (901) Supervision	6,941,089	12,819,397
160	MeterReadingExpenses (902) Meter Reading Expenses	5,761,047	6,183,670
161	CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses	163,431,605	156,058,369
162	UncollectibleAccounts (904) Uncollectible Accounts	26,821,384	42,122,468
163	MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses	675,994	1,226,397
164	CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)	202,279,131	215,957,507
165	CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166	CustomerServiceAndInformationalExpensesOperationAbstract Operation
167	SupervisionCustomerServiceAndInformationExpenses (907) Supervision	0	0
168	CustomerAssistanceExpenses (908) Customer Assistance Expenses	442,540,037	512,432,586
169	InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses	0	0
170	MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses	404,461	471,252
171	CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)	442,944,498	512,903,838
172	SalesExpenseAbstract 7. SALES EXPENSES
173	SalesExpenseOperationAbstract Operation
174	SupervisionSalesExpense (911) Supervision	0	0
175	DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses	961,730	1,194,885
176	AdvertisingExpenses (913) Advertising Expenses	0	0
177	MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses	0	0
178	SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)	961,730	1,194,885
179	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
180	AdministrativeAndGeneralExpensesOperationAbstract Operation
181	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	216,675,790	304,370,923
182	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	10,731,390	55,729,129
183	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit	36,224,106	50,102,503
184	OutsideServicesEmployed (923) Outside Services Employed	276,922,321	162,252,920
185	PropertyInsurance (924) Property Insurance	10,118,251	14,161,414
186	InjuriesAndDamages (925) Injuries and Damages	12,202,690,726	190,423,721
187	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	273,560,929	384,675,276
188	FranchiseRequirements (927) Franchise Requirements	89,640,572	102,108,129
189	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	0	0
190	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.	0	0
191	GeneralAdvertisingExpenses (930.1) General Advertising Expenses	0	121,950
192	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	11,017,410	6,306,443
193	RentsAdministrativeAndGeneralExpense (931) Rents	0	0
194	AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193)	13,033,670,503	1,170,047,402
195	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
196	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	4,725,363	8,482,612
197	AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196)	13,038,395,866	1,178,530,014
198	OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)	19,990,444,869	7,974,225,313

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

PURCHASED POWER (Account 555)
Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier’s service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. The data in column (g) through (n) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13. Footnote entries as required and provide explanations following all required data.
					Actual Demand (MW)				POWER EXCHANGES		COST/SETTLEMENT OF POWER
Line No.	NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c)	AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d)	AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e)	AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f)	MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g)	MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h)	EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i)	EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j)	DemandChargesOfPurchasedPower Demand Charges ($) (k)	EnergyChargesOfPurchasedPower Energy Charges ($) (l)	OtherChargesOfPurchasedPower Other Charges ($) (m)	SettlementOfPower Total (k+l+m) of Settlement ($) (n)
1	BIOGAS-CITY OF WATSONVILLE	LU	AB	0.00000	0.05920		27	31,325,510	0	0	82	1,337	0	1,419
2	MONTEREY REGIONAL WATER	LU		0.00000	0.21390		487	100	0	0	2,872	16,633	0	19,505
3	WASTE MANAGEMENT RENEWABLE	LU		0.00000	4.93400		2,580				5,758	94,512		100,270
4	BIOMASS-WHEELABRATOR SHASTA	LU		49.68000	34.28670		1,192				21,870	27,851		5,981
5	HYDRO-CHARCOAL RAVINE	LU		0.00000	0.00050		3				14	114		128
6	EIF HAYPRESS LLC LWR	LU		0.00000	1.54350		6,622				124,678	237,373		362,051
7	EIF HAYPRESS LLC MDL	LU		0.00000	2.07830		9,363				167,766	334,978		502,744
8	EL DORADO MONTGOMERY CREEK	LU	AB	0.00000	1.49590	0.135	5,233				64,650	706,165		770,815
9	FIVE BEARS HYDROELECTRIC	LU	AB	0.00000	0.21400	0.135	282				1,868	10,020		11,888
10	GANSNER HYDRO	LU	AB	0.00000	0.04580		108				553	3,834		4,387
11	HAT CREEK HEREFORD RANCH	LU	AB	0.00000	0.01480		13,108				356,938	555,063		912,001
12	HYDRO PARTNERS CLOVER CREEK	LU	AB	0.00000	0.83990		1,317				5,373	41,539		46,912
13	HYDRO SIERRA DEADWOOD CREEK	LU		0.00000	0.77700		1,906				23,431	62,643		86,074
14	HYPOWER INC.	LU		0.00000	5.16950		28,312				295,160	914,232		1,209,392
15	INDIAN VALLEY HYDRO	LU		0.00000	1.19990		2,385				20,215	81,525		101,740
16	JAMES B. PETER	LU		0.00000	0.00000		26				103	804		907
17	JAMES CRANE HYDRO	LU		0.00000	0.00050		4				10	150		160
18	KINGS RIVER HYDRO	LU		0.00000	0.34220		1,406				38,356	55,517		93,873
19	LOFTON RANCH	LU		0.00000	0.12570		964				6,059	33,463		39,522
20	MALACHA HYDRO L.P.	LU		0.00000	25.40150		47,753				1,538,760	1,867,768		3,406,528
21	NELSON CREEK POWER	LU		0.00000	0.28000		974				12,540	35,810		48,350
22	OLCESE WATER DISTRICT	LU		0.00000	4.37530		23,754				198,636	903,579		1,102,215
23	OLSEN POWER PARTNERS	LU		0.00000	1.75250		6,098				60,387	204,655		265,042
24	ORANGE COVE IRRIGATION DISTRICT	LU		0.00000	0.46400		3,853				82,535	143,847		226,382
25	SANTA CLARA VALLEY WATER DIST.	LU		0.00000	0.35320		2,089					77,630		77,630
26	SCHAADS HYDRO	LU		0.00000	0.11320		365				1,954	12,605		14,559
27	SNOW MOUNTAIN BURNEY CREEK	LU		0.00000	1.24890		3,386				36,361	124,070		160,431
28	SNOW MOUNTAIN COVE	LU		0.00000	2.51720		9,196				143,057	698,793		841,850
29	SNOW MT. PONDEROSA BAILEY CREEK	LU		0.00000	0.54500		1,779				28,766	43,574		72,340
30	SUTTER'S MILL SHAMROCK UTILITIES	LU		0.00000	0.00000						139	2,273		2,412
31	SWISS AMERICA	LU		0.00000	0.03110		212				1,823	7,631		9,454
32	TOM BENNINGHOVEN	LU		0.00000	0.00740		49				225	1,794		2,019
33	SOLAR-VILLA SORRISO SOLAR	LU		0.00000	0.00080		7				25	246		271
34	WIND-DONALD R. CHENOWETH	LU		0.00000	0.00070		6				21	223		244
35	EDF RENEWABLE WINDFARM V, INC (70 MW -	LU		0.00000	0.00000						1,361	41,924		43,285
36	EDF RENEWABLE INC 70 MW C	LU		0.00000	1.67040		3,541				92,854	133,606		226,460
37	EDF RENEWABLE INC 10 MW	LU		0.00000	0.00000		782				1,523	26,570		28,093
38	INTERNATIONAL TURBINE RESEARCH	LU		0.00000	6.66540		10,720				257,011	392,665		649,676
39	THERMAL:			0.00000	0.00000
40	COGEN-1080 CHESTNUT CORP.	LU		0.00000	0.00170		15				58	564		622
41	AIRPORT CLUB	LU		0.00000	0.00210		17				50	626		676
42	ARDEN WOOD BENEVOLENT ASSOC.	LU		0.00000	0.00010		1				4	36		40
43	BERKELEY COGENERATION	LU		22.47000	2.40700		8,799				60,237	147,916		208,153
44	CALPINE KING CITY COGEN	LU		111.00000	121.05810		393,881				24,936,469	14,695,346		39,631,815
45	CHEVRON RICHMOND REFINERY	LU		0.00000	2.78330		1,156				2,639	55,392		58,031
46	COUNTY OF SANTA CRUZ ( WATER ST. JAIL)	LU		0.00000	0.00000							7		7
47	CROCKETT COGEN	LU		240.00000	239.77570		1,393,652				52,220,644	56,180,444		108,401,088
48	ECO SERVICES OPERATIONS LLC	LU		0.00000	0.36770		357				1,029	13,330		14,359
49	FRESNO COGENERATION PARTNERS, LP	LU		33.00000	21.42570		1,683				7,305,734	199,384		7,505,118
50	FRITO-LAY COGEN	LU		0.00000	0.52310		632				3,859	24,677		28,536
51	GREATER VALLEJO RECREATION DIST.	LU		0.00000	0.00380		36				109	1,269		1,378
52	GREENLEAF UNIT 1	LU		49.20000	48.04160		73,004				9,042,139	3,506,775		12,548,914
53	GREENLEAF UNIT 2	LU		49.20000	47.43360		224,224				10,015,038	8,021,211		18,036,249
54	HAYWARD AREA RECREATION AND PARK	LU		0.00000	0.04570		407				1,240	15,020		16,260
55	NIHONMACHI TERRACE	LU		0.00000	0.00130		13				40	487		527
56	ORINDA SENIOR VILLAGE	LU		0.00000	0.00140		14				40	546		586
57	PE KES KINGSBURG LLC	LU		34.50000	13.49420		4,443				8,851,300	311,365		9,162,665
58	PHILLIPS 66	LU		0.00000	8.16550		22,202				127,965	870,675		998,640
59	SATELLITE SENIOR HOMES	LU		0.00000	0.00470		2					57		57
60	SRI INTERNATIONAL	LU		0.00000	1.79630		7,129				16,348	278,781		295,129
61	YUBA CITY COGEN	LU		46.00000	42.79940		10,655				10,444,146	484,681		10,928,827
62	EOR-AERA ENERGY LLC COALINGA	LU		0.00000	1.81400		5,484				27,182	230,290		257,472
63	AERA ENERGY SOUTH BELRIDGE	LU		0.00000	1.33030		4,852				22,710	169,664		192,374
64	BERRY PETROLEUM CO - TANNEHILL	LU		0.00000	12.11800		90,144				675,895	3,464,323		4,140,218
65	CHEVRON USA TAFT/CADET	LU		0.00000	2.06630		4,239				36,949	166,985		203,934
66	CHEVRON USA CYMRIC	LU		0.00000	5.28770		21,550				135,086	825,170		960,256
67	CHEVRON USA COALINGA	LU		0.00000	3.41930		11,252				112,038	420,854		532,892
68	CHEVRON USA INC EASTRIDGE	LU		0.00000	11.35430		14,725				78,562	584,295		662,857
69	CHEVRON USA INC SE KERN RIVER	LU		0.00000	7.94880		4,078				34,728	155,547		190,275
70	CHEVRON MCKITTRICK FHP	LU		0.00000	3.49840		19,701					1,260,401		1,260,401
71	COALINGA COGENERATION COMPANY	LU		37.70000	0.00000						150,000			150,000
72	FREEPORT MCMORAN DOME	LU		0.00000	1.83950		7,808				40,555	279,581		320,136
73	SENTINEL PEAK RESOURCES	LU		0.00000	1.83950		82				2,957	42,290		39,333
74	WESTERN POWER & STEAM INC	LU		17.75000	18.28810		134,424				1,548,892	5,100,979		6,649,871
75	BILATERALS			0.00000	0.00000
76	2041 ALVARES PRISTINE SUN			0.00000	0.00000		552					78,789		78,789
77	2056 JARDINE PRISTINE SUN			0.00000	0.00000		2,240					313,368		313,368
78	2059 SCHERZ			0.00000	0.00000		1,014					143,118		143,118
79	2065 ROGERS PRISTINE SUN			0.00000	0.00000		533					73,308		73,308
80	2081 TERZIAN			0.00000	0.00000		1,459					208,583		208,583
81	2094 BUZZELLE PRISTINE SUN			0.00000	0.00000		590					79,616		79,616
82	2096 COTTON PRISTINE SUN			0.00000	0.00000		1,889					283,192		283,192
83	2097 HELTON PRISTINE SUN			0.00000	0.00000		241					29,133		29,133
84	2102 CHRISTENSEN PRISTINE SUN			0.00000	0.00000		2,183					311,460		311,460
85	2103 HILL PRISTINE SUN			0.00000	0.00000		590					86,747		86,747
86	2105 HART (Oroville Solar)			0.00000	0.00000		1,105					81,335		81,335
87	2113 FITZJARRELL PRISTINE SUN			0.00000	0.00000		601					81,154		81,154
88	2125 JARVIS PRISTINE SUN			0.00000	0.00000		542					79,124		79,124
89	2127 HARRIS PRISTINE SUN			0.00000	0.00000		2,633					389,800		389,800
90	2154 FOOTE (Oroville Solar)			0.00000	0.00000		493					64,740		64,740
91	2158 STROING PRISTINE SUN			0.00000	0.00000		1,166					166,623		166,623
92	2179 SMOTHERMAN			0.00000	0.00000		560					82,424		82,424
93	2184 GRUBER (ENERPARC)			0.00000	0.00000		3,422					344,700		344,700
94	2192 RAMIREZ (Oroville Solar)			0.00000	0.00000		1,028					136,445		136,445
95	2018 REC Sales Oct-Dec Accrual			0.00000	0.00000							16,795,368		16,795,368
96	3 PHASES 2017 REC SALE			0.00000	0.00000							226,397		226,397
97	3 PHASES RENEWABLES INC			0.00000	0.00000						970,300			970,300
98	ABEC #2 LLC			0.00000	0.00000		2,629					524,367		524,367
99	ABEC #3 LLC			0.00000	0.00000		14,907					2,733,671		2,733,671
100	ABEC #4 LLC			0.00000	0.00000		2,574					523,641		523,641
101	ABEC BIDART OLD RIVER			0.00000	0.00000		11,883					1,727,324		1,727,324
102	ABEC BIDART-STOCKDALE LLC			0.00000	0.00000		849					151,259	404	150,855
103	AGUA CALIENTE SOLAR			0.00000	0.00000		727,004					127,047,414		127,047,414
104	ALAMO SOLAR			0.00000	0.00000		52,717					4,549,112		4,549,112
105	ALGONQUIN SANGER POWER LLC			0.00000	0.00000						8,168,240			8,168,240
106	ALGONQUIN SKIC 20 SOLAR, LLC			0.00000	0.00000		48,129					4,275,544		4,275,544
107	ALPAUGH 50, LLC			0.00000	0.00000		120,849					20,121,508		20,121,508
108	ALPAUGH NORTH, LLC			0.00000	0.00000		48,144					7,658,962		7,658,962
109	Anahau Energy, LLC EEI Master			0.00000	0.00000						5,291,500			5,291,500
110	ANGELS POWERHOUSE			0.00000	0.00000		5,831					641,616		641,616
111	APEX 646-460			0.00000	0.00000		1,804					234,362		234,362
112	ARBUCKLE MOUNTAIN HYDRO			0.00000	0.00000		30					2,392		2,392
113	ARLINGTON WIND POWER PROJECT			0.00000	0.00000		223,688					22,757,238		22,757,238
114	ASPIRATION SOLAR G			0.00000	0.00000		22,418					1,484,040		1,484,040
115	ATWELL ISLAND			0.00000	0.00000		39,526					6,563,130		6,563,130
116	AV SOLAR RANCH ONE			0.00000	0.00000		603,741					92,957,348	3,000,000	89,957,348
117	AVENAL SOLAR PROJECT A			0.00000	0.00000		17,391					970,391		970,391
118	AVENAL SOLAR PROJECT B			0.00000	0.00000		16,977					951,949		951,949
119	BADGER CREEK LIMITED			0.00000	0.00000		8,098				3,903,454	155,570		4,059,024
120	BAKER CREEK HYDROELECTRIC PROJECT			0.00000	0.00000		3,250					331,687		331,687
121	BAKERSFIELD 111 LLC			0.00000	0.00000		2,963					388,561		388,561
122	BAKERSFIELD INDUSTRIAL 1			0.00000	0.00000		2,201					158,494		158,494
123	BAKERSFIELD PV 1			0.00000	0.00000		10,763					440,110		440,110
124	BAYSHORE SOLAR A			0.00000	0.00000		59,488					3,317,811		3,317,811
125	BAYSHORE SOLAR B			0.00000	0.00000		60,813					3,364,350		3,364,350
126	BAYSHORE SOLAR C			0.00000	0.00000		58,844					3,279,556		3,279,556
127	BEAR CREEK SOLAR LLC			0.00000	0.00000		3,316					495,458		495,458
128	BEAR MOUNTAIN LIMITED			0.00000	0.00000		38,833				3,903,454	573,310		4,476,764
129	BGC BROKERAGE			0.00000	0.00000								16,170	16,170
130	BIG CREEK WATER WORKS			0.00000	0.00000		6,338					565,095		565,095
131	BLACKSPRING RIDGE 1A			0.00000	0.00000							15,019,220		15,019,220
132	BLACKSPRING RIDGE 1B			0.00000	0.00000							16,224,527		16,224,527
133	BLAKE'S LANDING FARMS INC			0.00000	0.00000		172					13,725		13,725
134	BONNEVILLE POWER ADMINSTRATION (KLONDI			0.00000	0.00000							554,313		554,313
135	BP Energy Company			0.00000	0.00000		107,913				253,600	9,316,573		9,062,973
136	BPA TSA			0.00000	0.00000								5,161	5,161
137	BROWNS VALLEY IRRIGATION DIST			0.00000	0.00000		3,251					258,571		258,571
138	BUCKEYE HYDROELECTRIC PROJECT			0.00000	0.00000		1,486					141,061		141,061
139	BURNEY FOREST PRODUCTS			0.00000	0.00000								9,300	9,300
140	CALAVERAS PUBLIC UTILI. DIST. 1			0.00000	0.00000		483					47,119		47,119
141	CALAVERAS PUBLIC UTILI. DIST. 2			0.00000	0.00000		291					28,176		28,176
142	CALAVERAS PUBLIC UTILI. DIST. 3			0.00000	0.00000		126					12,235		12,235
143	CALPINE ENERGY - AGNEWS, INC			0.00000	0.00000		16,289				5,895,251	308,486		6,203,737
144	CALPINE ENERGY EEI			0.00000	0.00000						1,023,500			1,023,500
145	CALPINE GEYSERS (200/425 MW)			0.00000	0.00000		180,250					16,462,518		16,462,518
146	CALPINE GEYSERS RETAINED ASSET AGREEME			0.00000	0.00000								18,344	18,344
147	CALPINE LOS ESTEROS UPGRADE			0.00000	0.00000		365,125				67,348,231	7,760,890		75,109,121
148	CALPINE PEAKERS			0.00000	0.00000		89,971				31,239,530	3,670,844		34,910,374
149	CALPINE RUSSELL CITY			0.00000	0.00000		1,342,740				144,530,861	20,638,030		165,168,891
150	CALRENEW CLEANTECH			0.00000	0.00000		9,899					2,229,862		2,229,862
151	CAMS DOUBLE C LIMITED			0.00000	0.00000		26,511				5,096,356	549,529	17,252	5,628,633
152	CAMS HIGH SIERRA LIMITED			0.00000	0.00000		28,158				5,073,452	598,394	19,528	5,652,318
153	CAMS KERN FRONT LIMITED			0.00000	0.00000		18,988				5,094,374	692,762	14,072	5,773,064
154	CASTELANELLI BROS BIOGAS			0.00000	0.00000		906					86,857		86,857
155	CASTOR SOLAR PROJECT			0.00000	0.00000		2,619					336,201		336,201
156	CE of Montana			0.00000	0.00000						348,250			348,250
157	CED CORCORAN SOLAR 3 LLC			0.00000	0.00000		52,178					2,554,984		2,554,984
158	CED WHITE RIVER SOLAR, LLC			0.00000	0.00000		1,332					177,441		177,441
159	CEDAR FLAT (Shamrock Utilities)			0.00000	0.00000		993					100,890		100,890
160	CHALK CLIFF LIMITED			0.00000	0.00000		16,765				3,885,559	305,254		4,190,813
161	CID SOLAR LLC RAM 2			0.00000	0.00000		52,849					5,657,262		5,657,262
162	CITY OF SAN JOSE
163	CITY OF SJ"			0.00000	0.00000						240,540			240,540
164	CITY OF SANTA CLARA SVP MUNI			0.00000	0.00000						699,750			699,750
165	CITY OF VERNON			0.00000	0.00000						126,500			126,500
166	CLEAN PWR ALLIANCE			0.00000	0.00000						338,919			338,919
167	CLEANPOWERSF			0.00000	0.00000						5,275,400			5,275,400
168	CLOVER FLAT LFG			0.00000	0.00000		5,199					519,391	2,787	516,604
169	CLOVER LEAF (Shamrock Utilities)			0.00000	0.00000		716					75,797		75,797
170	CLOVERDALE SOLAR 1, LLC			0.00000	0.00000		2,601					383,147		383,147
171	COLUMBIA SOLAR ENERGY LLC			0.00000	0.00000		38,127					3,780,655	200,000	3,580,655
172	COPPER MOUNTAIN 10			0.00000	0.00000		20,587					3,349,717		3,349,717
173	COPPER MOUNTAIN SOLAR 2 (SEMPRA)			0.00000	0.00000		373,073					48,359,434		48,359,434
174	COPPER MOUNTAIN SOLAR 48			0.00000	0.00000		99,882					16,243,373		16,243,373
175	CORAM BRODIE WIND			0.00000	0.00000		275,443					31,679,368		31,679,368
176	CORCORAN SOLAR			0.00000	0.00000		50,114					7,500,814		7,500,814
177	DELANO PV 1 LLC			0.00000	0.00000		2,186					158,367		158,367
178	DESERT CENTER SOLAR FARM			0.00000	0.00000		737,230					116,803,579		116,803,579
179	DIGGER CREEK HYDRO			0.00000	0.00000		3,033					307,728		307,728
180	DIRECT ENERGY BUSINESS MARKETING			0.00000	0.00000						2,219,750			2,219,750
181	DTE STOCKTON			0.00000	0.00000		372,295					48,523,322		48,523,322
182	DTE SUNSHINE GAS LANDFILL			0.00000	0.00000		149,138					17,988,201		17,988,201
183	EAST BAY COMMUNITY ENERGY			0.00000	0.00000						20,935,413	1,738,591		22,674,004
184	EAST BAY COMMUNITY ENERGY AUTHORITY -			0.00000	0.00000							717,059		717,059
185	ECOS ENERGY LLC KETTLEMAN SOLAR			0.00000	0.00000		2,223					321,462		321,462
186	EDF TRADING - BU			0.00000	0.00000						364,500			364,500
187	EDF TRADING 2017 REC SALE			0.00000	0.00000							283,357		283,357
188	EDF Trading EEI			0.00000	0.00000						6,142,972			6,142,972
189	EIF PANOCHE (FIREBAUGH)			0.00000	0.00000		636,160				55,634,546	5,567,591		61,202,137
190	EL DORADO IRRIGATION DISTRICT			0.00000	0.00000		59,377					5,878,544		5,878,544
191	ENERPARC CA1 LLC			0.00000	0.00000		3,594					530,100		530,100
192	EQUUS ENERGY BROKER			0.00000	0.00000								5,040	5,040
193	ETIWANDA POWER PLANT			0.00000	0.00000		50,133					2,199,661		2,199,661
194	EURUS (AVENAL PARK, LLC)			0.00000	0.00000		10,443					2,637,099		2,637,099
195	EURUS (SAND DRAG, LLC)			0.00000	0.00000		35,044					8,767,139		8,767,139
196	EURUS (SUN CITY PROJECT, LLC)			0.00000	0.00000		36,799					9,206,217		9,206,217
197	Exelon			0.00000	0.00000		60,000					2,347,484		2,347,484
198	EXELON GENERATION COMPANY			0.00000	0.00000							4,000,000		4,000,000
199	EXELON GENERATION WSPP			0.00000	0.00000		125,876				7,857,450	6,122,882		1,734,568
200	FALL RIVER MILLS A ACHOMAWI			0.00000	0.00000		3,458					509,515		509,515
201	FALL RIVER MILLS B AHJUMAWI			0.00000	0.00000		3,437					507,643		507,643
202	FPL Energy Power Marketing Inc.			0.00000	0.00000						250,250			250,250
203	FRESH AIR ENERGY IV SONORA 1			0.00000	0.00000		3,596					504,882		504,882
204	FRESNO SOLAR SOUTH			0.00000	0.00000		3,031					394,508		394,508
205	FRESNO SOLAR WEST			0.00000	0.00000		3,221					416,989		416,989
206	GAS TRANSPORT ASSOC WITH PANOCHE ENERG			0.00000	0.00000							1,484,416		1,484,416
207	GENESIS SOLAR ENERGY PROJECT			0.00000	0.00000		621,742					133,270,780	2,360,000	130,910,780
208	GEYSERS 50/250/425 MW			0.00000	0.00000		2,003,824				10,862,500	154,438,678		165,301,178
209	GLOBAL AMPERSAND, CHOWCHILLA			0.00000	0.00000		69,781					7,830,172		7,830,172
210	GLOBAL AMPERSAND, EL NIDO			0.00000	0.00000		67,970					7,527,476		7,527,476
211	GOOSE VALLEY FARMING, LLC			0.00000	0.00000		281					25,477		25,477
212	GREEN LIGHT ENERGY SIRUIS SOLAR			0.00000	0.00000		1,448					185,492		185,492
213	GREEN LIGHT MADERA 1			0.00000	0.00000		2,863					161,114		161,114
214	GWF HANFORD			0.00000	0.00000		15,604				8,369,979	216,350		8,586,329
215	GWF HENRIETTA			0.00000	0.00000		32,573				8,308,350	565,484		8,873,834
216	GWF TRACY REPOWERING PPA			0.00000	0.00000		911,735				66,895,676	10,746,212		77,641,888
217	HALKIRK I WIND PROJECT			0.00000	0.00000							16,851,744	842,587	17,694,331
218	HATCHET RIDGE WIND LLC			0.00000	0.00000		242,474					25,781,312		25,781,312
219	HENRIETTA SOLAR			0.00000	0.00000		252,661					26,281,045		26,281,045
220	HIGH PLAINS RANCH II			0.00000	0.00000		553,146					72,823,849	7,650,000	65,173,849
221	HIGH PLAINS RANCH III			0.00000	0.00000		111,253					15,587,362	1,350,000	14,237,362
222	HOLLISTER SOLAR ECOS ENERGY			0.00000	0.00000		4,076					545,335		545,335
223	IBERDROLA KLONDIKE (AKA PPM KLONDIKE)			0.00000	0.00000		202,019					11,818,140		11,818,140
224	IBERDROLA RENEWABLES (AKA PPM ENERGY)			0.00000	0.00000		19,953					5,732,398		5,732,398
225	ICE Broker Agreement			0.00000	0.00000								107,450	107,450
226	IVANPAH UNIT 1			0.00000	0.00000		239,049					39,116,577	1,000,000	38,116,577
227	IVANPAH UNIT 3			0.00000	0.00000		277,399					45,559,054	1,100,000	44,459,054
228	JACKSON VALLEY IRRIGATION DIST			0.00000	0.00000		801					72,409		72,409
229	KANSAS			0.00000	0.00000		52,264					5,395,223		5,395,223
230	KEKAWAKA CREEK HYDRO RAM 4			0.00000	0.00000		7,513					500,535		500,535
231	KENT SOUTH - PV 2			0.00000	0.00000		52,614					4,553,039		4,553,039
232	KERN RIVER COGEN (KRCC)			0.00000	0.00000		732,322				22,109,935	26,651,081		48,761,016
233	KINGSBURG 1 TULARE PV II LLC			0.00000	0.00000		2,831					398,845		398,845
234	KINGSBURG 2 TULARE PV II LLC			0.00000	0.00000		2,924					407,285		407,285
235	KINGSBURG 3 TULARE PV II LLC			0.00000	0.00000		1,419					198,547		198,547
236	KLONDIKE WIND IIIA POWER			0.00000	0.00000		228,990					17,943,046		17,943,046
237	LA JOYA DEL SOL 1			0.00000	0.00000		3,098					398,205		398,205
238	LASSEN STATION			0.00000	0.00000		3,406					357,114		357,114
239	LEMOORE PV 1, LLC			0.00000	0.00000		3,552					480,912		480,912
240	LIVE OAK LIMITED			0.00000	0.00000		25,146				3,891,874	465,701		4,357,575
241	LOST CREEK 1			0.00000	0.00000		5,523					563,961		563,961
242	LOST CREEK 2			0.00000	0.00000		2,537					257,917		257,917
243	Macquarie Futures			0.00000	0.00000								862,471	862,471
244	MACQUARIE FUTURES USA - EGS-FCM			0.00000	0.00000								830,992	830,992
245	MADERA CHOWCHILLA - SITE 1923			0.00000	0.00000		1,474					129,456		129,456
246	MADERA CHOWCHILLA SITE 1174			0.00000	0.00000		1,379					122,358		122,358
247	MADERA CHOWCHILLA SITE 1302			0.00000	0.00000		825					73,792		73,792
248	MADERA CHOWCHILLA SITE 980			0.00000	0.00000		3,915					347,870		347,870
249	MAMMOTH G1 (ORMAT) - RAM 2			0.00000	0.00000		56,816					4,871,902		4,871,902
250	MAMMOTH G3 (M3 ORMAT) - RAM 1			0.00000	0.00000		85,693					7,774,977		7,774,977
251	MANTECA LAND 1			0.00000	0.00000		1,888					146,515		146,515
252	MARIN CLEAN ENERGY - BU			0.00000	0.00000						220,000			220,000
253	MARIN CLEAN ENERGY EEI			0.00000	0.00000						9,966,458			9,966,458
254	MARIPOSA ENERGY, LLC			0.00000	0.00000		112,215				29,859,433	2,029,011		31,888,444
255	MARSH LANDING			0.00000	0.00000		203,650				118,582,704	5,463,398		124,046,102
256	MATTHEWS DAM HYDRO			0.00000	0.00000		4,398					468,161		468,161
257	MBCPA - BU			0.00000	0.00000						84,990			84,990
258	MCFADDEN HYDRO FACILITY			0.00000	0.00000							303,561		303,561
259	MCKITTRICK LIMITED			0.00000	0.00000		30,290				3,867,158	324,473		4,191,631
260	MERCED 1			0.00000	0.00000		5,332					210,100		210,100
261	MERCED IRRIGATION DISTRICT			0.00000	0.00000							135,965		135,965
262	MERCED SOLAR ECOS ENERGY			0.00000	0.00000		2,678					345,193		345,193
263	MESQUITE SOLAR			0.00000	0.00000		30,332					3,962,762		3,962,762
264	MIDWAY SUNSET COGENERATION COMPANY			0.00000	0.00000		838,496				14,312,723	4,858,988		9,453,735
265	MILL SULPHUR CREEK PROJECT			0.00000	0.00000		1,142					118,605		118,605
266	MISSION SOLAR ECOS ENERGY			0.00000	0.00000		2,708					348,718		348,718
267	MOJAVE SOLAR			0.00000	0.00000		602,251					120,925,541	6,227,437	114,698,104
268	MONTEREY BAY COMMUNITY POWER			0.00000	0.00000						11,484,910			11,484,910
269	MORELOS SOLAR LLC - RAM 3			0.00000	0.00000		38,517					3,500,901		3,500,901
270	Morgan Stanley			0.00000	0.00000		20,000					879,072		879,072
271	MORGAN STANLEY CAPITAL GROUP EEI			0.00000	0.00000		103,029				183,750	3,039,010		3,222,760
272	MT. POSO (RED HAWK)			0.00000	0.00000		242,938					32,289,860	350,000	31,939,860
273	NCPA			0.00000	0.00000						1,481,500			1,481,500
274	NEXTERA DIABLO WINDS			0.00000	0.00000		61,538					3,435,835		3,435,835
275	NEXTERA MONTEZUMA WIND			0.00000	0.00000		95,498					9,645,261	320,000	9,325,261
276	NEXTERA MONTEZUMA WIND II			0.00000	0.00000		214,040					21,837,602		21,837,602
277	NICKEL 1 NLH1 SOLAR			0.00000	0.00000		2,830					377,148		377,148
278	NID CHICAGO PARK			0.00000	0.00000		119,406					10,784,248		10,784,248
279	NID NORTH COMBIE FIT			0.00000	0.00000		1,494					160,739		160,739
280	NID SCOTTS FLAT			0.00000	0.00000		4,321					383,752		383,752
281	NID SOUTH COMBIE FIT			0.00000	0.00000		5,576					520,804		520,804
282	NID-DUTCH FLATS, ROLLINS, BOWMAN			0.00000	0.00000		136,247					12,333,536		12,333,536
283	NORTH SKY RIVER ENERGY CENTER			0.00000	0.00000		441,975					38,407,665		38,407,665
284	NORTH STAR SOLAR			0.00000	0.00000		154,435					19,914,450		19,914,450
285	NRG ALPINE SOLAR			0.00000	0.00000		162,698					23,738,562		23,738,562
286	NRG POWER MARKETING LLC			0.00000	0.00000						35,468			35,468
287	NRG SOLAR KANSAS SOUTH			0.00000	0.00000		48,988					4,657,853		4,657,853
288	OAKLEY EXECUTIVE LLC			0.00000	0.00000		2,219					317,895		317,895
289	OLD RIVER ONE LLC - RAM 3			0.00000	0.00000		50,330					4,251,478		4,251,478
290	ORION SOLAR I LLC			0.00000	0.00000		29,115					3,698,712		3,698,712
291	OROVILLE COGEN TOLLING			0.00000	0.00000		206				1,110,435	1,900		1,108,535
292	ORTIGALITA POWER COMPANY LLC			0.00000	0.00000							3		3
293	PACIFICORP TSA			0.00000	0.00000								7,891	7,891
294	PCWA LINCOLN HYDRO			0.00000	0.00000		1,329					144,031		144,031
295	PEACOCK SOLAR PROJ - GREEN LIGHT			0.00000	0.00000		1,817					243,159		243,159
296	PENINSULA 2017 REC SALE			0.00000	0.00000
297	PENINSULA CLEAN ENERGY			0.00000	0.00000						541,750			541,750
298	PENINSULA CLEAN ENERGY EEI			0.00000	0.00000						4,390,484			4,390,484
299	PILOT POWER GROUP INC			0.00000	0.00000						837,750			837,750
300	PIONEER COMM ENERGY			0.00000	0.00000						1,898,700			1,898,700
301	PLACER COUNTY WATER AGENCY			0.00000	0.00000		375,067					592,893		592,893
302	PORTAL RIDGE SOLAR C PROJECT			0.00000	0.00000		30,107					1,942,471		1,942,471
303	POTRERO HILL ENERGY PRODCERS LLC			0.00000	0.00000		63,121					7,869,023		7,869,023
304	POWEREX SHAPING FIRMING			0.00000	0.00000							1,553,805		1,553,805
305	PUTAH CREEK SOLAR FARMS			0.00000	0.00000		4,706					559,128		559,128
306	REDWOOD 4 SOLAR FARM			0.00000	0.00000		50,557					3,059,308		3,059,308
307	RIPON COGENERATION LLC			0.00000	0.00000		3,463				2,014,950	44,227		2,059,177
308	RISING TREE WIND FARM II LLC - RAM 4			0.00000	0.00000		56,129					3,451,960		3,451,960
309	ROCK CREEK HYDRO			0.00000	0.00000		1,538					131,064		131,064
310	SALMON CREEK HYDROELECTRIC			0.00000	0.00000		1,765					195,997		195,997
311	SAN JOSE CLEAN ENERGY			0.00000	0.00000						157,040			157,040
312	SAN JOSE WATER COX AVE HYDRO			0.00000	0.00000		291					35,294		35,294
313	SAN LUIS BYPASS			0.00000	0.00000		807					84,869		84,869
314	SANTA MARIA II LFG POWER PLANT			0.00000	0.00000		5,574					555,481		555,481
315	SEMPRA GENERATION EEI			0.00000	0.00000						39,000			39,000
316	SEMPRA MESQUITE SOLAR			0.00000	0.00000		392,125					61,771,043		61,771,043
317	SHAFTER SOLAR LLC RAM 3			0.00000	0.00000		50,794					4,831,287		4,831,287
318	SHELL ENERGY NORTH AMERICA			0.00000	0.00000						402,240	6,978		395,262
319	SHILOH I WIND			0.00000	0.00000		178,304					9,869,468		9,869,468
320	SHILOH I WIND PROJECT LLC			0.00000	0.00000		6,183					352,559		352,559
321	SHILOH II WIND (AKA ENXCO)			0.00000	0.00000		39,527					3,434,919		3,434,919
322	SHILOH II WIND PROJECT			0.00000	0.00000		345,755					30,478,099		30,478,099
323	SHILOH III (ENXCO)			0.00000	0.00000		9,190					1,054,521		1,054,521
324	SHILOH III WIND PROJECT			0.00000	0.00000		268,922					30,867,189		30,867,189
325	SHILOH IV			0.00000	0.00000		293,263					26,407,778		26,407,778
326	SIERRA GREEN ENERGY LLC			0.00000	0.00000		134					16,140		16,140
327	SIERRA PACIFIC INDUSTRIES			0.00000	0.00000		335,550					32,140,793	634,866	31,505,927
328	SIERRA PACIFIC POWER TSA			0.00000	0.00000								24,030	24,030
329	SILICON VALLEY CLEAN ENERGY AUTHORITY			0.00000	0.00000							3,390,000		3,390,000
330	SILICON VALLEY CLEAN ENERGY EEI			0.00000	0.00000						10,635,980			10,635,980
331	SILVER SPRINGS			0.00000	0.00000		1,890					198,672		198,672
332	SMUD WSPP			0.00000	0.00000						4,318,830			4,318,830
333	SO CAL EDISON EEI AGREEMENT			0.00000	0.00000						1,510,000			1,510,000
334	SONOMA CLEAN POWER AUTHORITY			0.00000	0.00000						1,945,305			1,945,305
335	SOUTH FEATHER WATER AND POWER AGENCY			0.00000	0.00000		234,421				3,376,794	9,033,377		12,410,171
336	SOUTH FEATHER WATER AND POWER AGENCY -			0.00000	0.00000		17,463				242,902	1,016,177		1,259,079
337	SOUTH SUTTER WATER DISTRICT			0.00000	0.00000		28					2,342		2,342
338	SR Solis Oro Loma Teresina Solar Proje			0.00000	0.00000		26,244					1,291,908		1,291,908
339	SR Solis Oro Loma Teresina Solar Proje			0.00000	0.00000		26,032					1,280,840		1,280,840
340	STARWOOD POWER MIDWAY, LLC			0.00000	0.00000		49,957				13,465,564	785,524		14,251,088
341	SUN HARVEST SOLAR, LLC (NDP1)			0.00000	0.00000		3,060					303,138		303,138
342	SUNRAY 2			0.00000	0.00000		59,938					3,578,614		3,578,614
343	SUNRISE POWER COMPANY LLC			0.00000	0.00000						14,767,200			14,767,200
344	SUTTERS MILL HYDROELECTRIC PLANT			0.00000	0.00000		723					75,003		75,003
345	TESORO REFINING & MARKETING LLC			0.00000	0.00000		90,266				779,462	4,937,060		5,716,522
346	THE ENERGY AUTHORITY - BU			0.00000	0.00000						89,920			89,920
347	THE ENERGY AUTHORITY EEI			0.00000	0.00000						1,213,300			1,213,300
348	THREE FORKS			0.00000	0.00000		5,210					519,304		519,304
349	TOPAZ SOLAR FARM			0.00000	0.00000		1,646,016					217,496,672	731	217,497,403
350	TORO SLO LANDFILL			0.00000	0.00000		10,244					1,143,956		1,143,956
351	TRANQUILLITY 8 AMARILLO			0.00000	0.00000		60,257					3,659,933		3,659,933
352	TRANSALTA ENREGY MARKETING US			0.00000	0.00000		538,274				549,550	20,874,970		20,325,420
353	TUNNEL HILL HYDRO			0.00000	0.00000		2,424					237,217		237,217
354	TWIN VALLEY HYDRO			0.00000	0.00000		1,449					166,971		166,971
355	VANTAGE WIND (POWEREX S&F)			0.00000	0.00000						193,088	9,315,820		9,122,732
356	VANTAGE WIND ENERGY LLC			0.00000	0.00000		243,974					24,998,512	1,524,000	23,474,512
357	VASCO WINDS (NEXTERA)			0.00000	0.00000		233,730					25,248,586		25,248,586
358	VINTNER SOLAR PROJECT			0.00000	0.00000		3,679					538,161		538,161
359	WADHAM ENERGY LP			0.00000	0.00000		57,290					4,881,747		4,881,747
360	WATER WHEEL RANCH			0.00000	0.00000		1,817					195,412		195,412
361	WECC WREGIS Fees			0.00000	0.00000							117,491		117,491
362	WEST ANTELOPE - RAM 1			0.00000	0.00000		39,130					3,413,748		3,413,748
363	WESTERN ANTELOPE BLUE SKY RANCH A - RA			0.00000	0.00000		53,901					3,693,052		3,693,052
364	WESTLANDS SOLAR FARMS LLC			0.00000	0.00000		43,794					5,747,956		5,747,956
365	WESTSIDE SOLAR			0.00000	0.00000		53,328					3,351,144		3,351,144
366	WHEELABRATOR SHASTA BIOMASS			0.00000	0.00000								3,300	3,300
367	WHEELABRATOR SHASTA BIORAM			0.00000	0.00000								6,000	6,000
368	WHITE RIVER SOLAR 2			0.00000	0.00000		49,361					4,874,910		4,874,910
369	WHITE RIVER SOLAR CED			0.00000	0.00000		49,923					7,689,785		7,689,785
370	WIND RESOURCE 1 (CALWIND) - RAM 1			0.00000	0.00000		14,005					1,041,388		1,041,388
371	WIND RESOURCE 2 (CALWIND) - RAM 2			0.00000	0.00000		47,599					3,557,582		3,557,582
372	WOLFSEN BYPASS FIT			0.00000	0.00000		2,892					289,593		289,593
373	WOODLAND BIOMASS			0.00000	0.00000		190,679					19,358,392		19,358,392
374	WOODMERE SOLAR RAM 4			0.00000	0.00000		35,627					2,574,253		2,574,253
375	YCWA MINI HYDRO			0.00000	0.00000		1,161					126,572		126,572
376	YOLO COUNTY GRASSLAND 3			0.00000	0.00000		2,049					259,464		259,464
377	YOLO COUNTY GRASSLAND 4			0.00000	0.00000		2,199					279,869		279,869
378	ZERO WASTE ENERGY DEVELOPMENT COMPANY			0.00000	0.00000		4,380					570,019	1,643	568,376
379	Pipeline charges			0.00000	0.00000
380	RUBY PIPELINE			0.00000	0.00000								12,686,997	12,686,997
381	WILLIAMS FIELD SERVICES -			0.00000	0.00000								6,325	6,325
382	SOUTHERN CA GAS - BU			0.00000	0.00000								10,762	10,762
383	Other charges			0.00000	0.00000
384	Irrigation districts			0.00000	0.00000								9,010,298	9,010,298
385	Liberty Utilities			0.00000	0.00000		5,040						862,378	862,378
386	ISO charges for storage cost			0.00000	0.00000								220,207	220,207
387	ISO charges ( net of storage cost but			0.00000	0.00000		5,863,083						257,845,224	257,845,224
388	Gas purchases, storage cost & forex			0.00000	0.00000								99,908,760	99,908,760
389	CARB fees			0.00000	0.00000								620,611	620,611
390	Consultancy fees			0.00000	0.00000								338,215	338,215
391	Gas Hedges & brokers fees			0.00000	0.00000								18,364,404	18,364,404
392	RECS from customers			0.00000	0.00000
393	Rounding issues in columns l												1,906	1,906
15	TOTAL						31,325,610				701,694,986	2,418,783,649	376,365,951	3,496,844,586

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c). In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. Report in column (i) and (j) the total megawatthours received and delivered. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. Footnote entries and provide explanations following all required data.
									TRANSFER OF ENERGY		REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Line No.	PaymentByCompanyOrPublicAuthority Payment By (Company of Public Authority) (Footnote Affiliation) (a)	TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName Energy Received From (Company of Public Authority) (Footnote Affiliation) (b)	TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c)	StatisticalClassificationCode Statistical Classification (d)	RateScheduleTariffNumber Ferc Rate Schedule of Tariff Number (e)	TransmissionPointOfReceipt Point of Receipt (Substation or Other Designation) (f)	TransmissionPointOfDelivery Point of Delivery (Substation or Other Designation) (g)	BillingDemand Billing Demand (MW) (h)	TransmissionOfElectricityForOthersEnergyReceived Megawatt Hours Received (i)	TransmissionOfElectricityForOthersEnergyDelivered Megawatt Hours Delivered (j)	Demand Charges ($) (k)	Energy Charges ($) (l)	Other Charges ($) (m)	RevenuesFromTransmissionOfElectricityForOthers Total Revenues ($) (k+l+m) (n)
1	TRANSMISSION AGENCY OF	Various	Various	LFP	142	Midway	Various	0	0	0	0	0	0	0
2	NORTHERN CALIFORNIA (TANC)	Various	Various	LFP	143	Midway	Various	233	366,570	359,638	0	1,845,837	0	1,845,837
35	TOTAL							233	366,570	359,638	0	1,845,837	0	1,845,837

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

TRANSMISSION OF ELECTRICITY BY ISO/RTOs
Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a). In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided. In column (d) report the revenue amounts as shown on bills or vouchers. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.	Payment Received by (Transmission Owner Name) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Total Revenue by Rate Schedule or Tariff (d)	Total Revenue (e)
1	Name1	FNO	123	101	201
2	Name2	LFP	456	99	98
40	TOTAL			200	299

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. Enter ""TOTAL"" in column (a) as the last line. Footnote entries and provide explanations following all required data.
			TRANSFER OF ENERGY		EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.	NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c)	TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d)	DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e)	EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f)	OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g)	ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h)
1	TRANSMISSION PROJECT	OS	100	100	1,000	500	350,010	351,510
2	PACIFICORP	OS	100	100	149,118	500	88,602	238,220
3	ADMINISTRATION	OS	100	100	2,256	0	0	2,256
4	INTERTIE	OS	100	100	1,000	1,000	359,499	357,499
	TOTAL		400	400	151,374	0	798,111	949,485

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.	Description (a)	Amount (b)
1	IndustryAssociationDues Industry Association Dues	7
2	NuclearPowerResearchExpenses Nuclear Power Research Expenses	1,000
3	OtherExperimentalAndGeneralResearchExpenses Other Experimental and General Research Expenses	1,000
4	PublicationAndDistributionExpensesForSecuritiesToStockholders Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities	2,000
5	OtherMiscellaneousGeneralExpenses Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6	Clearing Account Adjustments	935,948
7	Intervenor Compensation	6,062,538
8	MCI-PG&E Exchange Rights	691,661
9	Bank Service Fees	3,097,911
10	Consulting Serv, Outside Attorney Fees, Contracts	220,882
11	Union Negotiation Adjustment	164,631
12	Non-PO Credit Memo's	49,525
13	Misc cash receipt (recovery of unclaimed funds)	86,289
14	Write off from miscellaneous reconciliations	20,072
15	Other miscellaneous adjustments	282
46	MiscellaneousGeneralExpenses TOTAL	11,017,410

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
Report in section A for the year the amounts for : (b) Depreciation Expense (Account 403; (c) Depreciation Expense for Asset Retirement Costs (Account 403.1; (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405). Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification Listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
	A. Summary of Depreciation and Amortization Charges
Line No.	FunctionalClassificationAxis Functional Classification (a)	DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b)	DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c)	AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d)	AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e)	DepreciationAndAmortization Total (f)
1	Intangible Plant	100	100	100	100	400
2	Steam Production Plant	100	100	100	100	400
3	Nuclear Production Plant	100	100	100	100	400
4	Hydraulic Production Plant-Conventional	100	100	100	100	400
5	Hydraulic Production Plant-Pumped Storage	100	100	100	100	400
6	Other Production Plant	100	100	100	100	400
7	Transmission Plant	100	100	100	100	400
8	Distribution Plant	100	100	100	100	400
9	Regional Transmission and Market Operation	100	100	100	100	400
10	General Plant	100	100	100	100	400
11	Common Plant-Electric	100	100	100	100	400
12	TOTAL	1,100	1,100	1,100	1,100	4,400

B. Basis for Amortization Charges
The basis used to compute the charges is the ending plant balance. The basis is different from the preceding year due to net plant additions throughout the year. The rates have been updated in accordance with 2017 GRC authorized rates. The rates used to compute amortization charges for ‘Intangible Plant – Electric’ (Account 404) are as follows: EIP30201 Intangible Plant: Franchise 2.19%; EIP30301 Intangible Plant: USBR 0%; EIP30303 Intangible Plant: Software 2.11% The rates used to compute amortization charges for ‘Common Plant – Electric’ (Account 404) are as follows: CMP30302 Intangible Plant: Software 21.45%; CMP30304 Intangible Plant: Software 6.61% For FERC reporting purposes, common amortization expense is allocated to electric and gas amortization as common amortization expense is not reported on the FERC forms. The rate used to allocate the common amortization expense to electric is 64.65%. Amortization of the Other Electric Plant (Account 405) - These amortization amounts represent the 2017 GRC authorized amounts to record for the recovery of the URG regulatory asset. In connection with the Chapter 11 Settlement Agreement, the CPUC authorized the Utility to recover $1.2 billion of costs related to the Utility's retained generation assets. The individual components of these regulatory assets are being amortized over the respective lives of the underlying generation facilities or recovery period, consistent with the period over which the related revenues are recognized.

	C. Factors Used in Estimating Depreciation Charges
Line No.	AccountNumberFactorsUsedInEstimatingDepreciationCharges Account No. (a)	DepreciablePlantBase Depreciable Plant Base (in Thousands) (b)	UtilityPlantEstimatedAverageServiceLife Estimated Avg. Service Life (c)	UtilityPlantNetSalvageValuePercentage Net Salvage (Percent) (d)	UtilityPlantAppliedDepreciationRate Applied Depr. Rates (Percent) (e)	MortalityCurveType Mortality Curve Type (f)	UtilityPlantWeightedAverageRemainingLife Average Remaining Life (g)
12	310.02	4,801	10 years	1	2.18	SQ	15 years
13	311	113,671	(a) 75 years	2	3.46	R1	(be) 20 years
14	312	277,962	(b) 50 years	3	3.69	R1	(bf) 19 years
15	314	257,380	(c) 40 years	1	3.56	R2.5	(bg) 19 years
16	315	52,626	(d) 45 years	2	3.55	R2.5	(bh) 20 years
17	316	28,349	(e) 40 years	3	3.77	S0.5	(bi) 18 years
18	Subtotal	734,789
19	330	17,311	20 years	50	1.9	SQ	12 years
20	331	525,846	(f) 80 years	2	1.72	R2	(bj) 14 years
21	332	2,124,218	(g) 120 years	3	1.6	R2.5	(bk) 18 years
22	333	1,007,802	(h) 81 years	3	3.1	R1	(bl) 15 years
23	334	296,609	(i) 65 years	6	3.03	R1.5	(bm) 16 years
24	335	102,422	(j) 60 years	9	3.39	S0.5	(bn) 16 years
25	336	93,136	(k) 88 years	2	2.48	S1.5	(bo) 17 years
26	Subtotal	4,167,344
27	321	1,085,290	(l) 100 years	1	1.55	R1	(bp) 6 years
28	322	3,569,330	(m) 65 years	1	2.7	S1	(bq) 6 years
29	323	1,172,601	(n) 50 years	1	1.54	S2	(br) 6 years
30	324	844,039	(o) 75 years		1.6	R1.5	(bs) 6 years
31	325	1,152,130	(p) 50 years	1	5.69	S1	(bt) 6 years
32	Subtotal	7,823,390
33	340.02	3,121			0.64	SQ
34	341	210,804	(q) 59 years	1	3.69	R1,SQ	(bu) 20 years
35	342	11,271	(r) 50 years	2	3.69	R1	(bv) 19 years
36	343	227,881	(s) 40 years	3	3.57	R2.5	(bw) 20 years
37	344	353,878	(t) 27 years	1	4.35	R2.5,SQ	(bx) 18 years
38	345	213,715	(u) 31 years	2	5.71	R2.5,S2.5,SQ	(by) 16 years
39	346	98,646	(v) 35 years	3	3.84	S0.5,SQ	(bz) 18 years
40	Subtotal	1,119,316
41	350.02	247,241	(w) 42 years		4.06	R4	(ca) 26 years
42	352	536,335	(x) 65 years	20	1.8	R3	(cb) 56 years
43	353	6,478,163	(y) 2 years		0.08	R1.5	(cc) 1 year
44	354	961,640	(z) 75 years	66	2.25	R4	(cd) 55 years
45	355	1,384,181	(aa) 52 years	65	2.99	R1.5	(ce) 43 years
46	356	1,670,014	(ab) 65 years	70	2.57	R2	(cf) 49 years
47	357	511,098	(ac) 65 years		1.52	R4	(cg) 54 years
48	358	274,014	(ad) 55 years	10	1.99	R3	(ch) 42 years
49	359	103,204	(ae) 60 years	10	1.91	R1.5	(ci) 51 years
50	Subtotal	12,165,890
51	352.01	4,891	(af) 65 years		1.43	R3	(cj) 6 years
52	353.01	89,972	(ag) 98 years	19	7.05	R2	(ck) 12 years
53	Subtotal	94,863
54	360.02	122,527	(ah) 41 years		2.12	SQ	(cl) 19 years
55	361	323,045	(ai) 65 years	20	1.78	R3	(cm) 46 years
56	362	3,514,657	(aj) 46 years	40	3.06	R1.5	(cn) 32 years
57	363	33,497	(ak) 15 years		6.46	R2,S3	(co) 9 years
58	364	4,847,361	(al) 44 years	150	6.03	R1.5	(cp) 31 years
59	365	4,776,896	(am) 46 years	125	5.05	R2	(cq) 32 years
60	366	3,001,225	(an) 62 years	50	2.6	R4	(cr) 44 years
61	367	4,804,342	(ao) 47 years	65	3.35	R3	(cs) 31 years
62	368	3,790,010	(ap) 32 years	28	4.4	R2.5,R3	(ct) 21 years
63	369	3,423,955	(aq) 47 years	67	3.5	R2.5,R4	(cu) 28 years
64	370	1,201,281	(ar) 20 years	15	6.21	R1.5	(cv) 13 years
65	371	28,071	(as) 39 years	1	0.09	S1	(cw) 5 years
66	372	895	(at) 25 years			L1
67	373	254,680	(au) 28 years	23	3.25	R0.5,S1.5,L0,S1	(cx) 10 years
68	Subtotal	30,122,442
69	389.02	415	(av) 59 years		2.74	SQ	(cy) 31 years
70	390	11,777	(aw) 50 years	10	1.62	R2	(cz) 30 years
71	391	10,927	(ax) 20 years		6.2	SQ	(da) 11 years
72	394	145,209	(ay) 25 years		3.85	SQ	(db) 17 years
73	395	15,907	(az) 20 years		5.37	SQ	(dc) 13 years
74	397	351,873	(ba) 15 years		6.25	SQ	(dd) 12 years
75	398	25,736	(bb) 20 years		13.04	SQ	(de) 17 years
76	Subtotal	561,844
77	391.01	4,504	(bc) 20 years		5.23	SQ	(df) 16 years
78	398.01	15,863	(bd) 20 years		5.39	SQ	(dg) 16 years
79	Subtotal	20,367
80	Total	56,810,245

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

FOOTNOTE DATA

(a) Concept: UtilityPlantEstimatedAverageServiceLife
75
(b) Concept: UtilityPlantEstimatedAverageServiceLife
50
(c) Concept: UtilityPlantEstimatedAverageServiceLife
40
(d) Concept: UtilityPlantEstimatedAverageServiceLife
45
(e) Concept: UtilityPlantEstimatedAverageServiceLife
40
(f) Concept: UtilityPlantEstimatedAverageServiceLife
80
(g) Concept: UtilityPlantEstimatedAverageServiceLife
120
(h) Concept: UtilityPlantEstimatedAverageServiceLife
81
(i) Concept: UtilityPlantEstimatedAverageServiceLife
65
(j) Concept: UtilityPlantEstimatedAverageServiceLife
60
(k) Concept: UtilityPlantEstimatedAverageServiceLife
88
(l) Concept: UtilityPlantEstimatedAverageServiceLife
100
(m) Concept: UtilityPlantEstimatedAverageServiceLife
65
(n) Concept: UtilityPlantEstimatedAverageServiceLife
50
(o) Concept: UtilityPlantEstimatedAverageServiceLife
75
(p) Concept: UtilityPlantEstimatedAverageServiceLife
50
(q) Concept: UtilityPlantEstimatedAverageServiceLife
59
(r) Concept: UtilityPlantEstimatedAverageServiceLife
50
(s) Concept: UtilityPlantEstimatedAverageServiceLife
40
(t) Concept: UtilityPlantEstimatedAverageServiceLife
27
(u) Concept: UtilityPlantEstimatedAverageServiceLife
31
(v) Concept: UtilityPlantEstimatedAverageServiceLife
35
(w) Concept: UtilityPlantEstimatedAverageServiceLife
42
(x) Concept: UtilityPlantEstimatedAverageServiceLife
65
(y) Concept: UtilityPlantEstimatedAverageServiceLife
2
(z) Concept: UtilityPlantEstimatedAverageServiceLife
75
(aa) Concept: UtilityPlantEstimatedAverageServiceLife
52
(ab) Concept: UtilityPlantEstimatedAverageServiceLife
65
(ac) Concept: UtilityPlantEstimatedAverageServiceLife
65
(ad) Concept: UtilityPlantEstimatedAverageServiceLife
55
(ae) Concept: UtilityPlantEstimatedAverageServiceLife
60
(af) Concept: UtilityPlantEstimatedAverageServiceLife
65
(ag) Concept: UtilityPlantEstimatedAverageServiceLife
98
(ah) Concept: UtilityPlantEstimatedAverageServiceLife
41
(ai) Concept: UtilityPlantEstimatedAverageServiceLife
65
(aj) Concept: UtilityPlantEstimatedAverageServiceLife
46
(ak) Concept: UtilityPlantEstimatedAverageServiceLife
15
(al) Concept: UtilityPlantEstimatedAverageServiceLife
44
(am) Concept: UtilityPlantEstimatedAverageServiceLife
46
(an) Concept: UtilityPlantEstimatedAverageServiceLife
62
(ao) Concept: UtilityPlantEstimatedAverageServiceLife
47
(ap) Concept: UtilityPlantEstimatedAverageServiceLife
32
(aq) Concept: UtilityPlantEstimatedAverageServiceLife
47
(ar) Concept: UtilityPlantEstimatedAverageServiceLife
20
(as) Concept: UtilityPlantEstimatedAverageServiceLife
39
(at) Concept: UtilityPlantEstimatedAverageServiceLife
25
(au) Concept: UtilityPlantEstimatedAverageServiceLife
28
(av) Concept: UtilityPlantEstimatedAverageServiceLife
59
(aw) Concept: UtilityPlantEstimatedAverageServiceLife
50
(ax) Concept: UtilityPlantEstimatedAverageServiceLife
20
(ay) Concept: UtilityPlantEstimatedAverageServiceLife
25
(az) Concept: UtilityPlantEstimatedAverageServiceLife
20
(ba) Concept: UtilityPlantEstimatedAverageServiceLife
15
(bb) Concept: UtilityPlantEstimatedAverageServiceLife
20
(bc) Concept: UtilityPlantEstimatedAverageServiceLife
20
(bd) Concept: UtilityPlantEstimatedAverageServiceLife
20
(be) Concept: UtilityPlantWeightedAverageRemainingLife
19.7
(bf) Concept: UtilityPlantWeightedAverageRemainingLife
18.9
(bg) Concept: UtilityPlantWeightedAverageRemainingLife
19.3
(bh) Concept: UtilityPlantWeightedAverageRemainingLife
19.7
(bi) Concept: UtilityPlantWeightedAverageRemainingLife
18.2
(bj) Concept: UtilityPlantWeightedAverageRemainingLife
13.8
(bk) Concept: UtilityPlantWeightedAverageRemainingLife
18.3
(bl) Concept: UtilityPlantWeightedAverageRemainingLife
14.6
(bm) Concept: UtilityPlantWeightedAverageRemainingLife
15.7
(bn) Concept: UtilityPlantWeightedAverageRemainingLife
15.6
(bo) Concept: UtilityPlantWeightedAverageRemainingLife
17.1
(bp) Concept: UtilityPlantWeightedAverageRemainingLife
6.3
(bq) Concept: UtilityPlantWeightedAverageRemainingLife
5.9
(br) Concept: UtilityPlantWeightedAverageRemainingLife
5.6
(bs) Concept: UtilityPlantWeightedAverageRemainingLife
6.1
(bt) Concept: UtilityPlantWeightedAverageRemainingLife
6.2
(bu) Concept: UtilityPlantWeightedAverageRemainingLife
19.6
(bv) Concept: UtilityPlantWeightedAverageRemainingLife
19
(bw) Concept: UtilityPlantWeightedAverageRemainingLife
19.5
(bx) Concept: UtilityPlantWeightedAverageRemainingLife
18.4
(by) Concept: UtilityPlantWeightedAverageRemainingLife
15.6
(bz) Concept: UtilityPlantWeightedAverageRemainingLife
18.3
(ca) Concept: UtilityPlantWeightedAverageRemainingLife
26.3
(cb) Concept: UtilityPlantWeightedAverageRemainingLife
55.5
(cc) Concept: UtilityPlantWeightedAverageRemainingLife
0.8
(cd) Concept: UtilityPlantWeightedAverageRemainingLife
55.3
(ce) Concept: UtilityPlantWeightedAverageRemainingLife
42.6
(cf) Concept: UtilityPlantWeightedAverageRemainingLife
49.3
(cg) Concept: UtilityPlantWeightedAverageRemainingLife
53.8
(ch) Concept: UtilityPlantWeightedAverageRemainingLife
42
(ci) Concept: UtilityPlantWeightedAverageRemainingLife
50.9
(cj) Concept: UtilityPlantWeightedAverageRemainingLife
6.4
(ck) Concept: UtilityPlantWeightedAverageRemainingLife
12.3
(cl) Concept: UtilityPlantWeightedAverageRemainingLife
19.3
(cm) Concept: UtilityPlantWeightedAverageRemainingLife
46.5
(cn) Concept: UtilityPlantWeightedAverageRemainingLife
32.5
(co) Concept: UtilityPlantWeightedAverageRemainingLife
9.2
(cp) Concept: UtilityPlantWeightedAverageRemainingLife
30.9
(cq) Concept: UtilityPlantWeightedAverageRemainingLife
31.6
(cr) Concept: UtilityPlantWeightedAverageRemainingLife
43.8
(cs) Concept: UtilityPlantWeightedAverageRemainingLife
30.8
(ct) Concept: UtilityPlantWeightedAverageRemainingLife
21
(cu) Concept: UtilityPlantWeightedAverageRemainingLife
27.5
(cv) Concept: UtilityPlantWeightedAverageRemainingLife
13.2
(cw) Concept: UtilityPlantWeightedAverageRemainingLife
4.6
(cx) Concept: UtilityPlantWeightedAverageRemainingLife
10
(cy) Concept: UtilityPlantWeightedAverageRemainingLife
30.9
(cz) Concept: UtilityPlantWeightedAverageRemainingLife
30.4
(da) Concept: UtilityPlantWeightedAverageRemainingLife
10.9
(db) Concept: UtilityPlantWeightedAverageRemainingLife
17.3
(dc) Concept: UtilityPlantWeightedAverageRemainingLife
12.9
(dd) Concept: UtilityPlantWeightedAverageRemainingLife
12.5
(de) Concept: UtilityPlantWeightedAverageRemainingLife
17.2
(df) Concept: UtilityPlantWeightedAverageRemainingLife
16.5
(dg) Concept: UtilityPlantWeightedAverageRemainingLife
15.9

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

REGULATORY COMMISSION EXPENSES
Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization. List in column (f), (g), and (h) expenses incurred during year which were charged currently to income, plant, or other accounts. Minor items (less than $25,000) may be grouped.
						EXPENSES INCURRED DURING YEAR				AMORTIZED DURING YEAR
						CURRENTLY CHARGED TO
Line No.	RegulatoryCommissionDescription Description (Furnish name of regulatory commission or body the docket or case number and a description of the case) (a)	RegulatoryExpensesAssessedByRegulatoryCommission Assessed by Regulatory Commission (b)	RegulatoryExpensesOfUtility Expenses of Utility (c)	RegulatoryCommissionExpensesAmount Total Expenses for Current Year (d)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 at Beginning of Year (e)	NameOfDepartmentRegulatoryCommissionExpensesCharged Department (f)	AccountNumberRegulatoryCommissionExpensesCharged Account No. (g)	RegulatoryComissionExpensesIncurredAndCharged Amount (h)	RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets Deferred to Account 182.3 (i)	DeferredRegulatoryCommissionExpensesAmortizedInContraAccount Contra Account (j)	DeferredRegulatoryCommissionExpensesAmortized Amount (k)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 End of Year (l)
1	ABC	100	100	200	500	Electric	524	0	1,000	523	1,000	500
2	CDE	100	100	200	500	GAS	525	0	1,000	526	1,000	500
46	TOTAL	200	200	400	1,000			0	2,000		2,000	1,000

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts). Indicate in column (a) the applicable classification, as shown below: Classifications: Electric R, D and D Performed Internally: Generation hydroelectric Recreation fish and wildlife Other hydroelectric Fossil-fuel steam Internal combustion or gas turbine Nuclear Unconventional generation Siting and heat rejection Transmission Overhead Underground Distribution Regional Transmission and Market Operation Environment (other than equipment) Other (Classify and include items in excess of $50,000.) Total Cost Incurred Electric, R, D and D Performed Externally: Research Support to the electrical Research Council or the Electric Power Research Institute Research Support to Edison Electric Institute Research Support to Nuclear Power Groups Research Support to Others (Classify) Total Cost Incurred Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e). Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est."" Report separately research and related testing facilities operated by the respondent.
					AMOUNTS CHARGED IN CURRENT YEAR
Line No.	ResearchDevelopmentAndDemonstrationClassification Classification (a)	ResearchDevelopmentAndDemonstrationDescription Description (b)	ResearchDevelopmentAndDemonstrationCostsIncurredInternally Costs Incurred Internally Current Year (c)	ResearchDevelopmentAndDemonstrationCostsIncurredExternally Costs Incurred Externally Current Year (d)	AccountNumberForResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Account (e)	ResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Amount (f)	ResearchDevelopmentAndDemonstrationExpenditures Unamortized Accumulation (g)
1	A2, A3	Electric Program Investment Charge	10,284,310	100	408	250,978	1,000
2	A4, A5	Customer Energy Services -	3,501,062	200	408	27,430	2,000

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

DISTRIBUTION OF SALARIES AND WAGES
Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.
Line No.	Classification (a)	Direct Payroll Distribution (b)	Allocation of Payroll Charged for Clearing Accounts (c)	Total (d)
1	SalariesAndWagesElectricAbstract Electric
2	SalariesAndWagesElectricOperationAbstract Operation
3	SalariesAndWagesElectricOperationProduction Production	330,993,100	10	330,993,110
4	SalariesAndWagesElectricOperationTransmission Transmission	79,824,930	10	79,824,940
5	SalariesAndWagesElectricOperationRegionalMarket Regional Market	0	10	10
6	SalariesAndWagesElectricOperationDistribution Distribution	175,719,058	10	175,719,068
7	SalariesAndWagesElectricOperationCustomerAccounts Customer Accounts	113,609,934	10	113,609,944
8	SalariesAndWagesElectricOperationCustomerServiceAndInformational Customer Service and Informational	56,998,283	10	56,998,293
9	SalariesAndWagesElectricOperationSales Sales	651,164	10	651,174
10	SalariesAndWagesElectricOperationAdministrativeAndGeneral Administrative and General	216,549,578	70	216,549,508
11	SalariesAndWagesElectricOperation TOTAL Operation (Enter Total of lines 3 thru 10)	974,346,047	0	974,346,047
12	SalariesAndWagesElectricMaintenanceAbstract Maintenance
13	SalariesAndWagesElectricMaintenanceProduction Production	99,428,025	10	99,428,035
14	SalariesAndWagesElectricMaintenanceTransmission Transmission	38,444,457	10	38,444,467
15	SalariesAndWagesElectricMaintenanceRegionalMarket Regional Market	0	10	10
16	SalariesAndWagesElectricMaintenanceDistribution Distribution	171,069,015	10	171,069,025
17	SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral Administrative and General	3	40	37
18	SalariesAndWagesElectricMaintenance TOTAL Maintenance (Total of lines 13 thru 17)	308,941,500	0	308,941,500
19	SalariesAndWagesElectricOperationAndMaintenanceAbstract Total Operation and Maintenance
20	SalariesAndWagesElectricProduction Production (Enter Total of lines 3 and 13)	430,421,125	20	430,421,145
21	SalariesAndWagesElectricTransmission Transmission (Enter Total of lines 4 and 14)	118,269,387	20	118,269,407
22	SalariesAndWagesElectricRegionalMarket Regional Market (Enter Total of Lines 5 and 15)	0	20	20
23	SalariesAndWagesElectricDistribution Distribution (Enter Total of lines 6 and 16)	346,788,073	20	346,788,093
24	SalariesAndWagesElectricCustomerAccounts Customer Accounts (Transcribe from line 7)	113,609,934	10	113,609,944
25	SalariesAndWagesElectricCustomerServiceAndInformational Customer Service and Informational (Transcribe from line 8)	56,998,283	10	56,998,293
26	SalariesAndWagesElectricSales Sales (Transcribe from line 9)	651,164	10	651,174
27	SalariesAndWagesElectricAdministrativeAndGeneral Administrative and General (Enter Total of lines 10 and 17)	216,549,581	110	216,549,471
28	SalariesAndWagesElectricOperationAndMaintenance TOTAL Oper. and Maint. (Total of lines 20 thru 27)	1,283,287,547	0	1,283,287,547
29	SalariesAndWagesGasAbstract Gas
30	SalariesAndWagesGasOperationAbstract Operation
31	SalariesAndWagesGasOperationProductionManufacturedGas Production - Manufactured Gas	0	10	10
32	SalariesAndWagesGasOperationProductionNaturalGas Production-Nat. Gas (Including Expl. And Dev.)	2,634,683	10	2,634,693
33	SalariesAndWagesGasOperationOtherGasSupply Other Gas Supply	0	10	10
34	SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing Storage, LNG Terminaling and Processing	5,539,415	10	5,539,425
35	SalariesAndWagesGasOperationTransmission Transmission	96,675,038	10	96,675,048
36	SalariesAndWagesGasOperationDistribution Distribution	158,177,895	10	158,177,905
37	SalariesAndWagesGasCustomerAccounts Customer Accounts	74,115,974	10	74,115,984
59	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational	14,454,403	10	14,454,413
39	SalariesAndWagesGasSales Sales	608,866	10	608,876
40	SalariesAndWagesGasOperationAdministrativeAndGeneral Administrative and General	105,505,118	90	105,505,028
41	SalariesAndWagesGasOperation TOTAL Operation (Enter Total of lines 31 thru 40)	457,711,392	0	457,711,392
42	SalariesAndWagesGasMaintenanceAbstract Maintenance
43	SalariesAndWagesGasMaintenanceProductionManufacturedGas Production - Manufactured Gas	0	10	10
44	SalariesAndWagesGasMaintenanceProductionNaturalGas Production-Natural Gas (Including Exploration and Development)	249,993	10	250,003
45	SalariesAndWagesGasMaintenanceOtherGasSupply Other Gas Supply	0	10	10
46	SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing	1,552,205	10	1,552,215
47	SalariesAndWagesGasMaintenanceTransmission Transmission	55,191,848	10	55,191,858
48	SalariesAndWagesGasMaintenanceDistribution Distribution	84,850,684	10	84,850,694
49	SalariesAndWagesGasMaintenanceAdministrativeAndGeneral Administrative and General	1	50	49
50	SalariesAndWagesGasMaintenance TOTAL Maint. (Enter Total of lines 43 thru 49)	141,844,731	10	141,844,741
51	SalariesAndWagesGasOperationAndMaintenanceAbstract Total Operation and Maintenance
52	SalariesAndWagesGasProductionManufacturedGas Production-Manufactured Gas (Enter Total of lines 31 and 43)	0	20	20
53	SalariesAndWagesGasProductionNaturalGas Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,	2,884,676	20	2,884,696
54	SalariesAndWagesGasOtherGasSupply Other Gas Supply (Enter Total of lines 33 and 45)	0	20	20
55	SalariesAndWagesGasStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing (Total of lines 31 thru	7,091,620	20	7,091,640
56	SalariesAndWagesGasTransmission Transmission (Lines 35 and 47)	151,866,886	20	151,866,906
57	SalariesAndWagesGasDistribution Distribution (Lines 36 and 48)	243,028,579	20	243,028,599
58	SalariesAndWagesGasCustomerAccounts Customer Accounts (Line 37)	74,115,974	10	74,115,984
38	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational (Line 38)	14,454,403	10	14,454,413
39	SalariesAndWagesGasSales Sales (Line 39)	608,866	10	608,876
61	SalariesAndWagesGasAdministrativeAndGeneral Administrative and General (Lines 40 and 49)	105,505,119	140	105,504,979
62	SalariesAndWagesGasOperationAndMaintenance TOTAL Operation and Maint. (Total of lines 52 thru 61)	599,556,123	10	599,556,133
63	SalariesAndWagesOtherUtilityDepartmentsAbstract Other Utility Departments
64	SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance Operation and Maintenance	0	0	0
65	SalariesAndWagesOperationsAndMaintenance TOTAL All Utility Dept. (Total of lines 28, 62, and 64)	1,882,843,670	10	1,882,843,680
66	SalariesAndWagesUtilityPlantAbstract Utility Plant
67	SalariesAndWagesUtilityPlantConstructionAbstract Construction (By Utility Departments)
68	SalariesAndWagesUtilityPlantConstructionElectricPlant Electric Plant	781,939,241	10	781,939,251
69	SalariesAndWagesUtilityPlantConstructionGasPlant Gas Plant	422,493,640	10	422,493,650
70	SalariesAndWagesUtilityPlantConstructionOther Other (provide details in footnote):	158,619,223	20	158,619,203
71	SalariesAndWagesUtilityPlantConstruction TOTAL Construction (Total of lines 68 thru 70)	1,363,052,104	0	1,363,052,104
72	SalariesAndWagesPlantRemovalAbstract Plant Removal (By Utility Departments)
73	SalariesAndWagesPlantRemovalElectricPlant Electric Plant	65,534,708	0	65,534,708
74	SalariesAndWagesPlantRemovalGasPlant Gas Plant	25,198,754	0	25,198,754
75	SalariesAndWagesPlantRemovalOther Other (provide details in footnote):	1,065,193	0	1,065,193
76	SalariesAndWagesPlantRemoval TOTAL Plant Removal (Total of lines 73 thru 75)	91,798,655	0	91,798,655
77	SalariesAndWagesOtherAccountsAbstract Other Accounts (Specify, provide details in footnote):
78	SalariesAndWagesOtherAccountsDescription Other Non-Operating Salaries and Wages	10,690,997	0	10,690,997
79	SalariesAndWagesOtherAccountsDescription Other Balance Sheet Salaries and Wages	13,605,364	0	13,605,364
80	SalariesAndWagesOtherAccountsDescription
81	SalariesAndWagesOtherAccountsDescription
82	SalariesAndWagesOtherAccountsDescription
83	SalariesAndWagesOtherAccountsDescription
84	SalariesAndWagesOtherAccountsDescription
85	SalariesAndWagesOtherAccountsDescription
86	SalariesAndWagesOtherAccountsDescription
87	SalariesAndWagesOtherAccountsDescription
88	SalariesAndWagesOtherAccountsDescription
89	SalariesAndWagesOtherAccountsDescription
90	SalariesAndWagesOtherAccountsDescription
91	SalariesAndWagesOtherAccountsDescription
92	SalariesAndWagesOtherAccountsDescription
93	SalariesAndWagesOtherAccountsDescription
94	SalariesAndWagesOtherAccountsDescription
95	SalariesAndWagesOtherAccounts TOTAL Other Accounts	24,296,361	0	24,296,361
96	SalariesAndWagesGeneralExpense TOTAL SALARIES AND WAGES	3,361,990,790	10	3,361,990,800

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

COMMON UTILITY PLANT AND EXPENSES
Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the Common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation. Give date of approval by the Commission for use of the common utility plant classification and reference to order of the Commission or other authorization.
1. ORGANIZATION Buckeye Partners, L.P. (“Buckeye”) is a master limited partnership organized in 1986 under the laws of the state of Delaware. Buckeye’s principal line of business is the transportation, terminalling, storage and handling of refined petroleum products in the United States and the Caribbean, for integrated oil companies, refined product marketing companies and end users of petroleum products, on a fee basis through facilities owned and jointly owned by Buckeye. Buckeye conducts all of its operations through subsidiary entities, which include Buckeye Pipe Line Transportation Company, LLC (the “Company”), as well as joint ventures. Buckeye owns a 100% ownership interest in the Company. The Company is the sole member (100% owner) of Buckeye Linden Pipe Line Company LLC. Buckeye Linden Pipe Line Company LLC was formed as a Delaware limited liability company on October 16, 2013 and commenced operations in June 2014. Buckeye Linden Pipe Line Company LLC provides b-directional pipeline transportation service between Perth Amboy, New Jersey and Linden, New Jersey, thereby offering shippers enhanced connectivity and service optionality in the New York Harbor.

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.	Description of Item(s) (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	Energy
2	Net Purchases (Account 555)	100	200	300	400
2.1	Net Purchases (Account 555.1)	100	200	300	400
3	Net Sales (Account 447)	100	200	300	400
4	Transmission Rights	100	200	300	400
5	Ancillary Services	100	200	300	400
6	Other Items (list separately)
7	Grid Management Charges	100	200	300	400
8	FERC Fees	100	200	300	400
46	TOTAL	700	1,400	2,100	2,800

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff. In columns for usage, report usage-related billing determinant and the unit of measure. On line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year. On line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year. On line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year. On line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year. On lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period. On line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
		Amount Purchased for the Year			Amount Sold for the Year
		Usage - Related Billing Determinant			Usage - Related Billing Determinant
Line No.	Type of Ancillary Service (a)	Number of Units (b)	Unit of Measure (c)	Dollar (d)	Number of Units (e)	Unit of Measure (f)	Dollars (g)
1	Scheduling, System Control and Dispatch	10	Various	100	10	N/A	200
2	Reactive Supply and Voltage	10	Various	100	10	kW-Month	200
3	Regulation and Frequency Response	10	Various	100	10	kW-Month	200
4	Energy Imbalance	10	Various	100	10	kWh	200
5	Operating Reserve - Spinning	10	Various	100	10	kW-Month	200
6	Operating Reserve - Supplement	10	Various	100	10	kW-Month	200
7	Other	10	Various	100	10	Various	200
8	Total (Lines 1 thru 7)	70		700	70		1,400

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Firm Network Service for Self (e)	Firm Network Service for Others (f)	Long-Term Firm Point-to-point Reservations (g)	Other Long-Term Firm Service (h)	Short-Term Firm Point-to-point Reservation (i)	Other Service (j)
	NAME OF SYSTEM: PACIFIC GAS AND ELECTRIC COMPANY-0
1	January	13,520	8	18	8,128	100	100	50	100	5,342
2	February	14,095	20	18	8,911	100	100		100	5,184
3	March	13,009	5	10	7,762	100	100		100	5,247
4	Total for Quarter 1				24,801	300	300	50	300	15,773
5	April	13,395	23	10	7,404	100	100	60	100	5,931
6	May	16,268	29	18	9,717	100	100	100	100	6,451
7	June	18,048	23	18	10,439	100	100	100	100	7,509
8	Total for Quarter 2				27,560	300	300	260	300	19,891
9	July	18,973	25	18	10,876	100	100	75	100	8,022
10	August	18,633	9	18	10,338	100	100	75	100	8,220
11	September	16,455	7	1	8,826	100	100	100	100	7,529
12	Total for Quarter 3				30,040	300	300	250	300	23,771
13	October	14,354	2	2	6,778	100	100	100	100	7,476
14	November	13,142	14	18	6,192	100	100	100	100	6,850
15	December	13,770	4	12	5,165	100	100	100	100	8,505
16	Total for Quarter 4				18,135	300	300	300	300	22,831
17	Total				100,536	1,200	1,200	860	1,200	82,266
	NAME OF SYSTEM: PACIFIC GAS AND ELECTRIC COMPANY-2
1	January	13,520	8	18	8,128		100	50	100	5,342
2	February
3	March
4	Total for Quarter 1
5	April
6	May
7	June
8	Total for Quarter 2
9	July
10	August
11	September
12	Total for Quarter 3
13	October
14	November
15	December
16	Total for Quarter 4
17	Total

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

Monthly ISO/RTO Transmission System Peak Load
Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f). Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Import into ISO/RTO (e)	Exports from ISO/RTO (f)	Through and Out Service (g)	Network Service Usage (h)	Point-to-Point Service Usage (i)	Total Usage (j)
	NAME OF SYSTEM: EDRP
1	January	100,000	17	8	10,000	20,000	30,000	40,000	50,000	90,000
2	February	100,002	16	9	10,002	20,002	30,002	40,002	50,002	90,004
3	March	100,003	18	9	10,003	20,003	30,003	40,003	50,003	90,006
4	Total for Quarter 1				30,005	60,005	90,005	120,005	150,005	270,010
5	April	100,000	17	8	10,000	20,000	30,000	40,000	50,000	90,000
6	May	100,002	16	9	10,002	20,002	30,002	40,002	50,002	90,004
7	June	100,003	18	9	10,003	20,003	30,003	40,003	50,003	90,006
8	Total for Quarter 2				30,005	60,005	90,005	120,005	150,005	270,010
9	July	100,000	17	8	10,000	20,000	30,000	40,000	50,000	90,000
10	August	100,002	16	9	10,002	20,002	30,002	40,002	50,002	90,004
11	September	100,003	18	9	10,003	20,003	30,003	40,003	50,003	90,006
12	Total for Quarter 3				30,005	60,005	90,005	120,005	150,005	270,010
13	October	100,000	17	8	10,000	20,000	30,000	40,000	50,000	90,000
14	November	100,002	16	9	10,002	20,002	30,002	40,002	50,002	90,004
15	December	100,003	18	9	10,003	20,003	30,003	40,003	50,003	90,006
16	Total for Quarter 4				30,005	60,005	90,005	120,005	150,005	270,010
17	Total Year to Date/Year				120,020	240,020	360,020	480,020	600,020	1,080,040

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2019-04-16

Year/Period of Report

End of:

2018

ELECTRIC ENERGY ACCOUNT
Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.
Line No.	Item (a)	MegaWatt Hours (b)	Line No.	Item (a)	MegaWatt Hours (b)
1	SOURCES OF ENERGY		21	DISPOSITION OF ENERGY
2	Generation (Excluding Station Use):		22	Sales to Ultimate Consumers (Including Interdepartmental Sales)	80,066,264
3	Steam	5,931,611	23	Requirements Sales for Resale (See instruction 4, page 311.)	10,790,942
4	Nuclear	18,265,519	24	Non-Requirements Sales for Resale (See instruction 4, page 311.)
5	Hydro-Conventional	7,826,709	25	Energy Furnished Without Charge
6	Hydro-Pumped Storage	784,053	26	Energy Used by the Company (Electric Dept Only, Excluding Station Use)
7	Other	31,260,711	27	Total Energy Losses	3,331,574
8	Less Energy for Pumping	1,212,365	27.1	Total Energy Stored
9	Net Generation (Enter Total of lines 3 through 8)	62,856,238	28	TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES	94,188,780
10	Purchases (other than for Energy Storage)	31,325,610
10.1	Purchases for Energy Storage
11	Power Exchanges:
12	Received
13	Delivered
14	Net Exchanges (Line 12 minus line 13)
15	Transmission For Other (Wheeling)
16	Received	366,570
17	Delivered	359,638
18	Net Transmission for Other (Line 16 minus line 17)	6,932
19	Transmission By Others Losses
20	TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)	94,188,780

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

MONTHLY PEAKS AND OUTPUT
Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system. Report in column (b) by month the system’s output in Megawatt hours for each month. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.	MonthAxis Month (a)	EnergyActivity Total Monthly Energy (b)	NonRequiredSalesForResaleEnergy Monthly Non-Requirement Sales for Resale & Associated Losses (c)	MonthlyPeakLoad Monthly Peak - Megawatts (d)	DayOfMonthlyPeak Monthly Peak - Day of Month (e)	HourOfMonthlyPeak Monthly Peak - Hour (f)
	NAME OF SYSTEM: PACFIC GAS AND ELECTRIC COMPANY-0
29	January	5,029,823	111	11,901	8	19
30	February	4,581,182	111	12,624	20	19
31	March	4,859,705	111	11,406	5	20
32	April	4,665,634	111	12,046	23	21
33	May	5,154,051	111	14,705	29	19
34	June	5,677,493	111	16,428	23	19
35	July	6,634,933	111	17,263	25	19
36	August	6,251,443	111	16,770	9	19
37	September	5,383,907	111	14,729	7	18
38	October	5,305,835	111	12,813	2	20
39	November	4,841,750	111	11,642	14	19
40	December	5,253,233	111	12,315	4	19
41	Total	63,638,989	1,332

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

Steam Electric Generating Plant Statistics

1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mct.
7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20.
8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
9. Items under Cost of Plant are based on U. S. of A. Accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.
10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No.	Item (a)	Plant Name: Colusa Gen Station	Plant Name: Diablo Canyon 1& 2	Plant Name: Gateway Gen Station	Plant Name: Humboldt Gen Station
1	PlantKind Kind of Plant (Internal Comb, Gas Turb, Nuclear)	Combined Cycle	Nuclear	Combined Cycle	Internal Comb Recip
2	PlantConstructionType Type of Constr (Conventional, Outdoor, Boiler, etc)	Outdoor	Conventional	Outdoor	Indoor
3	YearPlantOriginallyConstructed Year Originally Constructed	2010	1968	2009	2010
4	YearLastUnitOfPlantInstalled Year Last Unit was Installed	2010	1986	2009	2011
5	InstalledCapacityOfPlant Total Installed Cap (Max Gen Name Plate Ratings-MW)	711.45	2,323	619.65	162.7
6	NetPeakDemandOnPlant Net Peak Demand on Plant - MW (60 minutes)	657	2,240	580	163
7	PlantHoursConnectedToLoad Plant Hours Connected to Load	6,088	8,760	6,735	8,643
8	NetContinuousPlantCapability Net Continuous Plant Capability (Megawatts)	0	0	0	0
9	NetContinuousPlantCapabilityNotLimitedByCondenserWater When Not Limited by Condenser Water	0	2,240	0	0
10	NetContinuousPlantCapabilityLimitedByCondenserWater When Limited by Condenser Water	0	2,240	0	0
11	PlantAverageNumberOfEmployees Average Number of Employees	22	1,303	22	19
12	NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh	2,991,759,812	18,265,519,000	2,939,850,866	384,780,571
13	CostOfLandAndLandRightsSteamProduction Cost of Plant: Land and Land Rights	7,889,274	22,726,560	5,040,000	161,399
14	CostOfStructuresAndImprovementsSteamProduction Structures and Improvements	115,958,181	1,089,216,494	72,443,812	67,447,178
15	CostOfEquipmentSteamProduction Equipment Costs	544,344,962	6,783,305,893	383,958,736	152,579,352
16	AssetRetirementCostsSteamProduction Asset Retirement Costs	3,912,558	2,701,010,462	3,004,029	1,925,852
17	CostOfPlant Total cost (total 13 thru 20)	672,104,975	10,596,259,409	464,446,577	222,113,781
18	CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 17/5) Including	944.6974	4,561.4548	749.5305	1,365.1738
19	OperationSupervisionAndEngineeringExpense Production Expenses: Oper, Supv, & Engr	257,077	4,025,966	257,077	78,872
20	FuelSteamPowerGeneration Fuel	85,252,370	129,114,087	86,205,401	14,613,788
21	CoolantsAndWater Coolants and Water (Nuclear Plants Only)	0	37,292,499	0	0
22	SteamExpensesSteamPowerGeneration Steam Expenses	0	38,815,499	16,174	0
23	SteamFromOtherSources Steam From Other Sources	0	0	0	0
24	SteamTransferredCredit Steam Transferred (Cr)	0	0	0	0
25	ElectricExpensesSteamPowerGeneration Electric Expenses	3,355,754	1,867,685	3,753,644	3,492,951
26	MiscellaneousSteamPowerExpenses Misc Steam (or Nuclear) Power Expenses	687,396	334,859,486	896,002	989,204
27	RentsSteamPowerGeneration Rents	0	0	0	0
28	Allowances Allowances	16,636,516	0	16,631,614	2,384,413
29	MaintenanceSupervisionAndEngineeringSteamPowerGeneration Maintenance Supervision and Engineering	70,112	2,782,594	70,112	21,510
30	MaintenanceOfStructuresSteamPowerGeneration Maintenance of Structures	1,903,977	3,442,055	59,850	204,863
31	MaintenanceOfBoilerPlantSteamPowerGeneration Maintenance of Boiler (or reactor) Plant	700,898	26,816,759	703,572	73,824
32	MaintenanceOfElectricPlantSteamPowerGeneration Maintenance of Electric Plant	2,950,795	36,172,375	3,627,718	5,609,397
33	MaintenanceOfMiscellaneousSteamPlant Maintenance of Misc Steam (or Nuclear) Plant	3,033,692	83,619,837	1,282,815	0
34	PowerProductionExpensesSteamPower Total Production Expenses	114,848,587	531,569,168	113,503,979	27,468,822
35	ExpensesPerNetKilowattHour Expenses per Net kWh	0.0384	0.0291	0.0386	0.0714

35	FuelKindAxis Plant Name	Colusa Gen Station	Diablo Canyon 1& 2	Gateway Gen Station	Humboldt Gen Station	Humboldt Gen Station
36	FuelKind Fuel Kind	Gas	Nuclear	Gas	Gas	Oil
37	FuelUnit Fuel Unit	Mcf	g	Mcf	Mcf	bbl
38	QuantityOfFuelBurned Quantity (Units) of Fuel Burned	20,823,676	2,303	20,357,260	3,225,039	2,734
39	FuelBurnedAverageHeatContent Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)	1,039,167		1,041,167	1,040,917	5,795,804
40	AverageCostOfFuelPerUnitAsDelivered Avg Cost of Fuel/unit, as Delvd f.o.b. during year	4.32		4.22	4.15	100.63
41	AverageCostOfFuelPerUnitBurned Average Cost of Fuel per Unit Burned	4.59	55.847	4.49	5.48
42	AverageCostOfFuelBurnedPerMillionBritishThermalUnit Average Cost of Fuel Burned per Million BTU	4.42	0.682	4.31	5.27	17.43
43	AverageCostOfFuelBurnedPerKilowattHourNetGeneration Average Cost of Fuel Burned per kWh Net Gen	0.03	0.007	0.03	0.05	0.14
44	AverageBritishThermalUnitPerKilowattHourNetGeneration Average BTU per kWh Net Generation	7,233	10,327.208	7,210	8,885	8,089

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

Hydroelectric Generating Plant Statistics

Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number.
If net peak demand for 60 minutes is not available, give that which is available specifying period.
If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant.
The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.

Line No.	Item (a)	FERC Licensed Project No. 1354 Plant Name: A.G. WISHON	FERC Licensed Project No. 175 Plant Name: BALCH NO. 1	FERC Licensed Project No. 175 Plant Name: BALCH NO. 2	FERC Licensed Project No. 2105 Plant Name: BELDEN	FERC Licensed Project No. 619 Plant Name: BUCKS CREEK	FERC Licensed Project No. 2105 Plant Name: BUTT VALLEY	FERC Licensed Project No. 2105 Plant Name: CARIBOU NO. 1	FERC Licensed Project No. 2105 Plant Name: CARIBOU NO. 2	FERC Licensed Project No. 1121 Plant Name: COLEMAN	FERC Licensed Project No. 1962 Plant Name: CRESTA	FERC Licensed Project No. 803 Plant Name: DE SABLA	FERC Licensed Project No. 2310 Plant Name: DRUM NO. 1	FERC Licensed Project No. 2310 Plant Name: DRUM NO. 2	FERC Licensed Project No. 2310 Plant Name: DUTCH FLAT	FERC Licensed Project No. 137 Plant Name: ELECTRA	FERC Licensed Project No. 1988 Plant Name: HAAS	FERC Licensed Project No. 2130 Plant Name: HALSEY	FERC Licensed Project No. 2661 Plant Name: HAT CREEK NO. 1	FERC Licensed Project No. 2661 Plant Name: HAT CREEK NO. 2	FERC Licensed Project No. 2106 Plant Name: JAMES B. BLACK	FERC Licensed Project No. 96 Plant Name: KERCKHOFF NO. 1	FERC Licensed Project No. 96 Plant Name: KERCKHOFF NO. 2	FERC Licensed Project No. 1988 Plant Name: KINGS RIVER	FERC Licensed Project No. 1403 Plant Name: NARROWS	FERC Licensed Project No. 2310 Plant Name: NEWCASTLE	FERC Licensed Project No. 233 Plant Name: PIT NO. 3	FERC Licensed Project No. 233 Plant Name: PIT NO. 4	FERC Licensed Project No. 233 Plant Name: PIT NO. 5	FERC Licensed Project No. 2106 Plant Name: PIT NO. 6	FERC Licensed Project No. 2106 Plant Name: PIT NO. 7	FERC Licensed Project No. 2687 Plant Name: PIT NO.1	FERC Licensed Project No. 2107 Plant Name: POE	FERC Licensed Project No. 1962 Plant Name: ROCK CREEK	FERC Licensed Project No. 137 Plant Name: SALT SPRINGS	FERC Licensed Project No. 2130 Plant Name: STANISLAUS	FERC Licensed Project No. 137 Plant Name: TIGER CREEK	FERC Licensed Project No. 137 Plant Name: WEST POINT	FERC Licensed Project No. 2310 Plant Name: WISE NO. 1
1	PlantKind Kind of Plant (Run-of-River or Storage)	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage	R of R/Storage
2	PlantConstructionType Plant Construction type (Conventional or Outdoor)	Conventional	Conventional	Outdoor	Outdoor	Conventional	Outdoor	Conventional	Outdoor	Conventional	Conventional	Outdoor	Conventional	Outdoor	Conventional	Conventional	Conventional	Conventional	Conventional	Conventional	Outdoor	Conventional	Underground	Semi-Outdoor	Conventional	Conventional	Conventional	Conventional	Conventional	Outdoor	Outdoor	Conventional	Outdoor	Conventional	Conventional	Outdoor	Conventional	Conventional	Conventional
3	YearPlantOriginallyConstructed Year Originally Constructed	1910	1927	1958	1969	1928	1958	1921	1958	1979	1949	1963	1913	1965	1943	1948	1958	1916	1921	1921	1965	1920	1983	1962	1942	1986	1925	1955	1944	1965	1965	1922	1958	1950	1931	1963	1931	1948	1917
4	YearLastUnitOfPlantInstalled Year Last Unit was Installed	1910	1927	1958	1969	1928	1958	1924	1958	1979	1950	1963	1928	1965	1943	1948	1958	1916	1921	1921	1966	1920	1983	1962	1942	1986	1925	1955	1944	1965	1965	1922	1958	1950	1953	1963	1931	1948	1917
5	InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW)	12.8	31	97.2	117.9	66	40	73.85	117.9	12.15	73.8	18.45	49.2	53.1	22	102.5	135	13.6	10	10	168.66	22.72	139.5	48.6	10.2	12.7	80.19	103.5	141.84	79.2	109.8	69.3	142.83	125.37	42.03	81.9	52.28	13.6	13.6
6	NetPeakDemandOnPlant Net Peak Demand on Plant-Megawatts (60 minutes)	20	34	105	125	65	41	75	120	13	70	19	54	50	22	98	144	11	9	9	172	25	155	52	12	12	70	95	160	80	112	61	120	126	44	91	58	15	14
7	PlantHoursConnectedToLoad Plant Hours Connect to Load	6,585	7,972	8,727	5,882	8,410	4,736	6,717	7,976	8,445	7,073	7,690	3,181	8,147	6,876	5,693	7,610	7,123	8,377	8,601	8,709		5,775	7,410	2,314	3,102	6,570	8,758		8,596	8,256	8,614	7,967	7,119	7,564	7,965	7,644	7,942	7,939
8	NetPlantCapabilityAbstract Net Plant Capability (in megawatts)
9	NetPlantCapabilityUnderMostFavorableOperatingConditions (a) Under Most Favorable Oper Conditions	20	34	105	125	65	41	75	120	13	70	19	54	50	22	98	144	11	9	9	172	25	155	52	12	12	70	95	160	80	112	61	120	119	44	91	58	15	14
10	NetPlantCapabilityUnderMostAdverseOperatingConditions (b) Under the Most Adverse Oper Conditions	12	34	104	125	53	38	74	119	5	72	19	54	49	23	98	138	11	4	9	172		151	52	12		70	95	160	80	112	61	120	119	34	91	58	13	14
11	PlantAverageNumberOfEmployees Average Number of Employees
12	NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh	25,652,329	82,111,021	401,299,232	235,266,815	128,911,667	57,118,200	110,532,743	360,239,676	45,302,645	187,135,206	59,656,524	83,913,780	230,525,842	65,434,392	318,290,353	360,886,120	360,886,120	36,812,536	31,284,521	542,644,584		327,205,316	132,080,338	22,728,278	10,786,767	257,432,979	400,071,744	612,975,367	267,438,940	357,690,402	227,075,869	447,646,495	322,644,207	125,695,957	333,256,359	227,420,171	69,020,934	65,589,885
13	CostOfPlantAbstract Cost of Plant
14	CostOfLandAndLandRightsHydroelectricProduction Land and Land Rights	976,875	8,165	2,630	640,218	810,543	398,183	330,012	384,372	183,058	1,364,764	146,825	1,571,285	441,826	785,641	735,286	30,588	30,588	1,047,218	733,666	568,139	6,969	584,910	15,682	274,399	2,066,271	3,791,145	312,988	687,742	387,337	323,678	2,307,798	821,303	1,777,666	221,450	428,932	2,572,625	150,912	823,681
15	CostOfStructuresAndImprovementsHydroelectricProduction Structures and Improvements	1,528,365	854,160	5,192,179	11,727,773	1,474,672	3,151,323	6,709,663	11,189,102	1,704,073	5,714,160	3,122,920	5,541,698	1,142,045	2,115,430	2,610,434	11,737,499	11,737,499	2,985,501	759,980	766,934	1,651,408	39,045,952	5,271,515	1,173,893	6,583,663	9,206,074	4,300,149	21,149,838	6,941,414	6,856,399	2,253,094	4,046,851	21,460,445	2,486,698	6,477,282	8,123,675	1,039,104	4,096,375
16	CostOfReservoirsDamsAndWaterwaysHydroelectricProduction Reservoirs, Dams, and Waterways	51,024,316	9,448,057	7,126,485	58,173,965	21,114,877	36,503,597	28,499,090	36,168,942	23,741,590	23,843,112	41,913,456	39,678,065	11,721,651	19,247,540	27,559,897	29,603,124	29,603,124	28,366,638	2,775,286	66,249,996	3,325,126	90,039,658	20,171,097	1,220,149	47,616,591	68,460,657	41,021,512	46,537,842	36,377,850	31,436,620	13,046,575	59,968,899	47,873,280	33,803,923	36,736,275	54,661,888	5,959,695	17,299,241
17	EquipmentCostsHydroelectricProduction Equipment Costs	6,364,363	9,802,804	38,968,422	63,607,879	22,420,669	15,512,934	29,651,344	34,736,018	13,332,433	11,848,381	6,170,443	23,339,876	8,187,291	15,746,022	24,856,303	41,123,297	41,123,297	10,025,561	2,822,191	18,207,990	6,167,177	52,285,342	13,981,486	7,129,685	8,338,520	29,942,674	38,028,307	90,880,556	13,377,803	11,787,529	38,723,193	38,904,520	106,581,651	13,510,239	20,380,012	26,815,105	7,585,844	10,714,439
18	CostOfRoadsRailroadsAndBridgesHydroelectricProduction Roads, Railroads, and Bridges	29,468	1,327,037	1,739,338	479,445	3,068,244	2,679,316	5,360,063	17,594	1,870,299	135,388	2,441,056	1,410,081	479,135	394,378	1,407,837	797,929	797,929	267,475	1,171,981	2,073,884	6,186	7,536,660	354,839	506,708	3,056,166	7,126,541	3,913,417	9,456,338	687,395	406,204	1,448,928	1,626,548	354,708	1,528,393	1,142,259	7,729,944	285,168	212,689
19	AssetRetirementCostsHydroelectricProduction Asset Retirement Costs
20	CostOfPlant Total cost (total 13 thru 20)	59,923,387	21,440,223	53,029,054	134,629,280	48,889,005	58,245,353	70,550,172	82,496,028	40,831,453	42,905,805	53,794,700	71,541,005	21,971,948	38,289,011	57,169,757	83,292,437	83,292,437	42,692,393	8,263,104	87,866,943	11,156,866	189,492,522	39,794,619	10,304,834	67,661,211	118,527,091	87,576,373	168,712,316	57,771,799	50,810,430	57,779,588	105,368,121	178,047,750	51,550,703	65,164,760	99,903,237	15,020,723	33,146,425
21	CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 20 / 5)	4,681.5146	691.6201	545.5664	1,141.8938	740.7425	1,456.1338	955.3172	699.7119	3,360.6134	581.3795	2,915.7019	1,454.0855	413.7843	1,740.4096	557.7537	616.981	6,124.4439	4,269.2393	826.3104	520.9708	491.0592	1,358.3693	818.8193	1,010.2778	5,327.6544	1,478.0782	846.1485	1,189.4551	729.4419	462.7544	833.7603	737.717	1,420.1783	1,226.5216	795.6625	1,910.9265	1,104.4649	2,437.2371
22	ProductionExpensesAbstract Production Expenses
23	OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering
24	WaterForPower Water for Power	226,010	3,425	9,227	109,846	123,794	39,605	68,036	105,665	816	5,115	514	40,807	37,531	17,510	133,967	12,341	9,502			29,023	1,430	5,622	4,862	275,357	9,866	47,633	55,627		29,023	29,023	102,586	5,115	5,115	6,768	443,972	7,791	2,466	11,686
25	HydraulicExpenses Hydraulic Expenses		10,255	31,671	15,060	9,739	16,203	10,626	14,616	915	15,680	26,225	177,263	174,879	188,829	27,411	43,435	4,155	541	541	24,631			15,685	750		18,141	19,732	23,867	18,777	20,813	17,569	17,821	15,149	40,675	99,843	20,754	8,514	753
26	ElectricExpensesHydraulicPowerGeneration Electric Expenses	141,132	141,901	222,402	325,229	152,309	331,157	1,216,193	311,043	408,911	150,542	710,981	412,909	276,612	373,186	1,188,342	556,293	80,343	236,960	222,193	295,071	120,285	294,966	148,958	60,759	26,667	611,456	347,785	491,392	239,460	260,382	280,102	160,193	1,305,645	1,220,312	2,159,136	805,139	265,700	544,347
27	MiscellaneousHydraulicPowerGenerationExpenses Misc Hydraulic Power Generation Expenses	1,101,147	61,751	189,223	23,493	380,933	568	993	1,557	178,071	268,200	6,414,625	7,945	7,308	3,416	87,461	26,448	1,859	1,060,857	1,060,857	262,179	250,398	1,503,660	5,276	162,775	1,929	193,482	208,709	242,382	214,354	231,740	890,136	441,670	503,409	145,550	455,979	57,930	25,814	2,283
28	RentsHydraulicPowerGeneration Rents	4,223	28,076	86,622	15,455	21,222	5,090	9,285	14,838	9	20,367	37,840	52,689	48,459	22,609	358	30,946	12,269	2,626	2,626	11,574	64,673	394,577	11,194		12,739	136	136	136	11,574	11,574		9,078	36,660	191	98,596	220	70	15,089
29	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration Maintenance Supervision and Engineering
30	MaintenanceOfStructuresHydraulicPowerGeneration Maintenance of Structures	37,196	46,779	144,781	39,202	104,521	19,463	173,963	37,777	126,828	145,717	129,091	12,081	10,751	7,976	264,892	293,460	60,478	6,708	3,781	10,544	48,693	16,962	68,975	5,163	5,090	2,452	6,532	1,913,381	3,117	8,835	2,189	139,354	214,260	188,819	1,323,933	244,804	53,419	8,319
31	MaintenanceOfReservoirsDamsAndWaterways Maintenance of Reservoirs, Dams, and Waterways	15,931	76,354	217,457	164,300	155,089	256,689	162,686	81,701	891,380	910,723	671,745	66,665	57,047	54,137	501,819	248,746	286,018	24,517	45,520	25,025	10,878	90,326	93,735	12,731	216,058	25,981	30,753	1,837,724	1,650	67,350	187,003	141,098	1,166,484	7,890,183	551,243	607,423	161,253	250,741
32	MaintenanceOfElectricPlantHydraulicPowerGeneration Maintenance of Electric Plant	144,810	107,740	238,068	219,749	79,078	220,079	515,227	197,617	209,817	407,226	742,172	123,476	65,920	62,417	517,527	859,834	89,897	83,446	50,291	213,236	48,543	519,602	144,568	151,270	114,850	781,487	324,107	996,140	151,601	577,602	210,328	613,095	360,826	359,088	523,463	394,602	243,258	76,288
33	MaintenanceOfMiscellaneousHydraulicPlant Maintenance of Misc Hydraulic Plant	56	491,536	1,369,778	146,665	79,279	76,687	176,542	82,765	1,028,538	62,920	1,205,012	90,744	86,076	57,551	10,747	1,735,782	174,827	12,594	33,359	24,451	49,312	313,706	588,886	15,945	168,341	178,998	22,194	142,918	28,067	10,650	50,070	147,657	84,633	5,848	21,893	7,008	2,152	170,446
34	PowerProductionExpensesHydraulicPower Total Production Expenses (total 23 thru 33)	1,670,505	967,817	2,509,229	1,058,999	1,105,964	965,541	2,333,551	847,579	2,845,285	1,986,490	9,938,205	984,579	764,583	787,631	2,732,524	3,807,285	719,348	1,428,249	1,419,168	895,734	594,212	3,139,421	1,082,139	684,750	555,540	1,859,766	1,015,575	2,140,106	697,623	1,217,969	1,739,983	1,675,081	3,692,181	9,857,434	5,678,058	2,145,671	762,646	1,079,952
35	ExpensesPerNetKilowattHour Expenses per net kWh	0.0651	0.0118	0.0063	0.0045	0.0086	0.0169	0.0211	0.0024	0.0628	0.0106	0.1666	0.0117	0.0033	0.012	0.0086	0.0105	0.002	0.0388	0.0454	0.0017		0.0096	0.0082	0.0301	0.0515	0.0072	0.0025	0.0035	0.0026	0.0034	0.0077	0.0037	0.0114	0.0784	0.017	0.0094	0.011	0.0165

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

Pumped Storage Generating Plant Statistics
Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings). If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number. If net peak demand for 60 minutes is not available, give the which is available, specifying period. If a group of employees attends more than one generating plant, report on line 8 the approximate average number of employees assignable to each plant. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses." Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No.	Item (a)	FERC Licensed Project No. 2735 Plant Name: HELMS PUMPED STORAGE
1	PlantConstructionType Type of Plant Construction (Conventional or Outdoor)	Underground
2	YearPlantOriginallyConstructed Year Originally Constructed	1984
3	YearLastUnitOfPlantInstalled Year Last Unit was Installed	1984
4	InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW)	1,053
5	NetPeakDemandOnPlant Net Peak Demaind on Plant-Megawatts (60 minutes)	1,050
6	PlantHoursConnectedToLoad Plant Hours Connect to Load While Generating	2,811
7	NetContinuousPlantCapability Net Plant Capability (in megawatts)	1,212
8	PlantAverageNumberOfEmployees Average Number of Employees	20
9	NetGenerationExcludingPlantUse Generation, Exclusive of Plant Use - kWh	1,212,364,607
10	EnergyUsedForPumping Energy Used for Pumping	784,053,024
11	NetOutputForLoad Net Output for Load (line 9 - line 10) - Kwh	428,311,583
12	CostOfPlantAbstract Cost of Plant
13	CostOfLandAndLandRightsPumpedStoragePlant Land and Land Rights	751,302
14	CostOfStructuresAndImprovementsPumpedStoragePlant Structures and Improvements	185,627,148
15	CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant Reservoirs, Dams, and Waterways	450,931,223
16	CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant Water Wheels, Turbines, and Generators	273,553,164
17	CostOfAccessoryElectricEquipmentPumpedStoragePlant Accessory Electric Equipment	61,165,589
18	CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant Miscellaneous Powerplant Equipment	25,902,828
19	CostOfRoadsRailroadsAndBridgesPumpedStoragePlant Roads, Railroads, and Bridges	8,781,047
20	AssetRetirementCostsPumpedStoragePlant Asset Retirement Costs	0
21	CostOfPlant Total cost (total 13 thru 20)	1,006,712,301
22	CostPerKilowattOfInstalledCapacity Cost per KW of installed cap (line 21 / 4)	956.0421
23	ProductionExpensesAbstract Production Expenses
24	OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering	15,098
25	WaterForPower Water for Power	343,813
26	PumpedStorageExpenses Pumped Storage Expenses	13,239
27	ElectricExpensesPumpedStoragePlant Electric Expenses	1,898,701
28	MiscellaneousPumpedStoragePowerGenerationExpenses Misc Pumped Storage Power generation Expenses	2,101,242
29	RentsPumpedStoragePlant Rents	44,587
30	MaintenanceSupervisionAndEngineeringPumpedStoragePlant Maintenance Supervision and Engineering	1,028
31	MaintenanceOfStructuresPumpedStoragePlant Maintenance of Structures	492,977
32	MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant Maintenance of Reservoirs, Dams, and Waterways	523,237
33	MaintenanceOfElectricPlantPumpedStoragePlant Maintenance of Electric Plant	3,139,730
34	MaintenanceOfMiscellaneousPumpedStoragePlant Maintenance of Misc Pumped Storage Plant	1,174,188
35	PowerProductionExpenseBeforePumpingExpenses Production Exp Before Pumping Exp (24 thru 34)	9,747,840
36	PumpingExpenses Pumping Expenses	0
37	PowerProductionExpensesPumpedStoragePlant Total Production Exp (total 35 and 36)	9,747,840
38	ExpensesPerNetKilowattHour Expenses per kWh (line 37 / 9)	0.008
39	ExpensesPerNetKilowattHourGenerationAndPumping Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))	0.0049

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

GENERATING PLANT STATISTICS (Small Plants)
Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating). Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 403. If net peak demand for 60 minutes is not available, give the which is available, specifying period. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
									Production Expenses
Line No.	PlantName Name of Plant (a)	YearPlantOriginallyConstructed Year Orig. Const. (b)	InstalledCapacityOfPlant Installed Capacity Name Plate Rating (MW) (c)	NetPeakDemandOnPlant Net Peak Demand MW (60 min) (d)	NetGenerationExcludingPlantUse Net Generation Excluding Plant Use (e)	CostOfPlant Cost of Plant (f)	PlantCostPerMw Plant Cost (Incl Asset Retire. Costs) Per MW (g)	OperatingExpensesExcludingFuel Operation Exc'l. Fuel (h)	FuelProductionExpenses Fuel Production Expenses (i)	MaintenanceProductionExpenses Maintenance Production Expenses (j)	FuelKind Kind of Fuel (k)	FuelCostPerMmbtus Fuel Costs (in cents (per Million Btu) (l)	GenerationType Generation Type (m)
1	HYDROELECTRIC GENERATING PLANTS:	1979	7.65	8	999	20,395,346	2,666,058	565,747	1,000	1,665,751	Water	888
2	Alta FERC No.2310	1902	1	1	3,433,609	13,634,782	13,634,782	473,285	1,000	168,542	Water
3	Centerville FERC No.803	1904	6.4	6.4		17,463,863	2,728,729	4,578,183		1,535,036	Water
4	Chili Bar FERC No.2155	1965	7.02	7	27,228,445	18,075,458	2,574,852	244,807		500,828	Water
5	Coal Canyon	1907				7,575,676		80,538		166,093	Water
6	Cow Creek FERC No.606	1907	1.44	1.8	3,745,421	3,182,941	2,210,376	599,246		760,391	Water
7	Crane Valley FERC No.1354	1919	0.99	0.9	164,934	23,258,096	23,493,026	143,070		324,827	Water
8	Deer Creek FERC No.2310	1908	5.5	5.7	19,144,298	87,621,177	15,931,123	79,345		800,176	Water
9	Hamilton Branch	1921	5.39	4.8	4,459,717	8,588,805	1,593,470	329,025		242,458	Water
10	Inskip FERC No.1121	1979	7.65	8	999	20,395,346	2,666,058	565,747	1,000	1,665,751	Water	888
11	Kern Canyon FERC No. 178	1921	9.54	11.5	999	12,783,346	1,339,973	219,723	1,000	23,179	Water	888
12	Kilarc FERC No.606	1904	3	1.6	8,327,693	4,332,045	1,444,015	651,369	1,000	995,956	Water
13	Lime Saddle	1906	2	2	3,017,132	17,455,558	6,252,102	7,201,744	1,000	2,600,320	Water
14	Oak Flat FERC No.2105	1985	1.4	1.3	2,329,025	8,783,381	6,273,844	234,414	1,000	124,139	Water
15	Phoenix FERC No.1061	1940	1.6	2	5,653,449	15,380,576	9,612,860	314,765	1,000	520,069	Water
16	Potter Valley FERC No.77	1910	9.46	9.2	13,090,222	49,156,531	5,196,251	2,294,948	1,000	651,598	Water
17	San Joaquin No. 1-A FERC No.1354	1919	0.42	0.4		32,149,806	76,547,157	87,621	1,000	119,918	Water
18	San Joaquin No. 2 FERC No.1354	1917	2.88	3.2	354,930	33,153,732	11,511,713	270,693	1,000	83,938	Water
19	San Joaquin No. 3 FERC No.1354	1923	4	4.2		27,525,753	6,881,438	339,866	1,000	97,591	Water
20	South FERC No.1121	1979	6.75	7	25,089,079	16,992,536	2,517,413	610,803	1,000	1,295,775	Water
21	Spaulding No. 1 FERC No.2310	1928	7.04	7	4,491,409	41,924,150	5,955,135	509,726	1,000	250,474	Water
22	Spaulding No. 2 FERC No.2310	1928	3.7	4.4	8,860,840	18,521,493	5,005,809	477,656	1,000	127,861	Water
23	Spaulding No. 3 FERC No.2310	1929	6.61	5.8		15,054,898	2,277,594	486,954		173,348	Water
24	Spring Gap FERC No.2130	1921	6	7	29,954,655	12,171,407	2,028,568	360,510		591,597	Water
25	Toadtown FERC No.803	1986	1.8	1.5	3,519,807	7,287,347	4,048,526	3,679,455		1,149,569	Water
26	Tule FERC No.1333	1914	4.5	6.4		15,026,350	3,339,189	125,923		315,448	Water
27	Volta No.1 FERC No.1121	1980	8.55	9	49,310,273	17,552,924	2,052,974	802,146		1,752,044	Water
28	Volta No.2 FERC No.1121	1981	0.95	0.9	5,326,779	3,105,076	3,268,501	631,006		535,040	Water
29	Wise II FERC No.2310	1986	2.87	3.2		13,170,152	4,588,903	11,404		338,816	Water
30	Miscellaneous Minor					16,701,986					Water
31	AT&T PARK SOLAR ARRAYS	2007	0.11	0.1	130,251	1,990,928	17,936,287			37,749	Solar
32	SF SERVICE CENTER SOLAR ARRAY 1 & 2	2007	0.18	0.2	61,799	72,959	405,327			6,252	Solar
33	Vaca Dixon Solar Station	2009	2	2	4,068,953	10,881,965	5,440,983	30,371		12,108	Solar
34	Five Points - Schindler Solar Station #1	2011	15	15	28,699,174	54,818,128	3,654,542	74,716		97,869	Solar
35	Westside - Schindler Solar Station #2	2011	15	15	28,707,717	48,312,358	3,220,824	73,474		193,073	Solar
36	Stroud Solar Station	2011	20	20	37,339,126	62,321,706	3,116,085	79,928		136,135	Solar
37	Cantua Solar Station	2012	20	20	42,223,391	56,349,026	2,817,451	41,083		360,795	Solar
38	Giffen Solar Station	2012	10	10	18,948,350	31,412,761	3,141,276	43,481		60,308	Solar
39	Huron Solar Station	2012	20	20	41,312,760	61,197,254	3,059,863	59,963		249,295	Solar
40	Gates Solar Station	2013	20	20	43,311,245	65,649,055	3,282,453	35,884		69,204	Solar
41	West Gates Solar Station	2013	10	10	21,698,973	77,128,541	7,712,854	43,254		68,180	Solar
42	Guernsey Solar Station	2013	20	20	43,716,766	35,775,278	1,788,764	190,920		214,138	Solar
43	San Francisco State	2011	1.6	1.6	11,119,388	8,504,503	5,315,314	257,698		280,948	Natural Gas
44	California State University East Bay	2011	1.4	1.4	4,801,495	6,582,640	4,701,886	129,892		166,927	Natural Gas
45	Downieville Diesel Plant	1966	0.75			95,289					Diesel
46	Grass Valley Mobile Diesel Generator	1971	0.25			38,497					Diesel
47	Sierra City Mobile Diesel Generator	1972	0.33			49,054					Diesel

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

ENERGY STORAGE OPERATIONS (Large Plants)
Large Plants are plants of 10,000 KW or more. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy. In column (k) report the MWHs sold. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No.	Name of the Energy Storage Project (a)	Functional Classification (b)	Location of the Project (c)	MWHs (d)	MWHs delivered to the grid to support Production (e)	MWHs delivered to the grid to support Transmission (f)	MWHs delivered to the grid to support Transmission (g)	MWHs Lost During Conversion, Storage and Discharge of Energy Production (h)	MWHs Lost During Conversion, Storage and Discharge of Energy Transmission (i)	MWHs Lost During Conversion, Storage and Discharge of Energy Distribution (j)	MWHs Sold (k)	Revenues from Energy Storage Operations (l)	Power Purchased for Storage Operations (555.1) (Dollars) (m)	Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars) (n)	Other Costs Associated with Self-Generated Power (Dollars) (o)	Project Costs included in (p)	Production (Dollars) (q)	Transmission (Dollars) (r)	Distribution (Dollars) (s)
1	A Project	Production	New York, NY	1,000	2,000	3,000	4,000	100	200	300	600	10	20	30	40	101	60	70	80
2	B Project	Transmission	Boston, MA	1,000	2,000	3,000	4,000	100	200	300	600	10	20	30	40	102	60	70	80
35	TOTAL			2,000	4,000	6,000	8,000	200	400	600	1,200	20	40	60	80		120	140	160

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

TRANSMISSION LINE STATISTICS
Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. Report data by individual lines for all voltages if so required by a State commission. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g). Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
	DESIGNATION		VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase)			LENGTH (Pole miles) - (In the case of underground lines report circuit miles)				COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way)			EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No.	TransmissionLineStartPoint From	TransmissionLineEndPoint To	OperatingVoltageOfTransmissionLine Operating	DesignedVoltageOfTransmissionLine Designated	SupportingStructureOfTransmissionLineType Type of Supporting Structure	LengthForStandAloneTransmissionLines On Structure of Line Designated	LengthForTransmissionLinesAggregatedWithOtherStructures On Structures of Another Line	NumberOfTransmissionCircuits Number of Circuits	SizeOfConductorAndMaterial Size of Conductor and Material	CostOfLandAndLandRightsTransmissionLines Land	ConstructionAndOtherCostsTransmissionLines Construction Costs	OverallCostOfTransmissionLine Total Costs	OperatingExpensesOfTransmissionLine Operation Expenses	MaintenanceExpensesOfTransmissionLine Maintenance Expenses	RentExpensesOfTransmissionLine Rents	OverallExpensesOfTransmissionLine Total Expenses
	(a)	(b)	(c)	(d)	(e)	(f)	(g)	(h)	(i)	(j)	(k)	(l)	(m)	(n)	(o)	(p)
1	DIABLO	GATES #1	500	500	T	79.23		1	2300 - AAC - BUND
2	DIABLO	MIDWAY #2	500	500	T	84.07		1	2300 - AAC - BUND
3	DIABLO	MIDWAY #3	500	500	T	84.67		1	2300 - AAC - BUND
4	DIABLO UNIT #1		500	500	T	0.54		1	2300 - AAC - BUND
5	DIABLO UNIT #2		500	500	T	0.57		1	2300 - AAC - BUND
6	GATES	MIDWAY	500	500	T SSP	63.78		1	2300 - AAC - BUND
7	LOS BANOS	GATES #1	500	500	T	80.85		1	2300 - AAC - BUND
8	LOS BANOS	MIDWAY #2	500	500	T	144.82		1	2300 - AAC - BUND
9	MALIN	ROUND MTN #2	500	500	T OTHERS	46.9		1	2300 - AAC - BUND
10	MIDWAY	WHIRLWIND	500	500	T	52.77		1	2156 - ACSR - BUN
11	MOSS LANDING	LOS BANOS	500	500	T SSP	51.33		1	2300 - AAC - BUND
12	MOSS LANDING	METCALF	500	500	T	34.98		1	2300 - AAC - BUND
13	ROUND MTN	TABLE MTN #1	500	500	T SSP	89.03		1	2300 - AAC - BUND
14	ROUND MTN	TABLE MTN #2	500	500	T SSP	89.02		1	2300 - AAC - BUND
15	TABLE MTN	TESLA	500	500	T OTHERS	134.99		1	2300 - AAC - BUND
16	TABLE MTN	VACA	500	500	T	83.3		1	2300 - AAC - BUND
17	TESLA	LOS BANOS #1	500	500	T	57.14		1	2300 - AAC - BUND
18	TESLA	METCALF	500	500	T	35.31		1	2300 - AAC - BUND
19	TESLA	TRACY	500	500	T SSP	1.13		1	2300 - AAC - BUND
20	TRACY	LOS BANOS	500	500	T SSP	56.23		1	2300 - AAC - BUND
21	VACA	TESLA	500	500	T	57		1	2300 - AAC - BUND
22	ARCO	MIDWAY	230	230	T SSP	43.36		1	795 - ACSR - SING
23	ATLANTIC	GOLD HILL	230	230	T	11.11		1	1113 - AAC - SING
24	BAHIA	MORAGA	230	230	T	26.92		1	954 - ACSR - SING
25	BAKERSFIELD #1 TAP		230	230	T SSP	6.67		1	1113 - AAC - SING
26	BAKERSFIELD #2 TAP		230	230	T	7.01		1	1113 - AAC - SING
27	BALCH	MCCALL	230	230		39.76		1	954 - AAC - SINGL
28	BELDEN TAP		230	230	SSP	0.02		1	795 - ACSR - SING
29	BELLOTA	COTTLE	230	230	T	19.87		1	1113 - AAC - SING
30	BELLOTA	TESLA #2	230	230	SSP	37.94		1	954 - ACSS - SING
31	BELLOTA	WARNERVILLE	230	230	SSP	22.47		1	954 - ACSR - SING
32	BELLOTA	WEBER	230	230	T SSP	14.26		1	954 - ACSS - SING
33	BIRDS LANDING SW STA	SHILOH	230	230	SSP	0.11		1	954 - AAC - SINGL
34	BIRDS LANDING SW STA	CONTRA COSTA PP	230	230	T SSP	10.2		1	1113 - ACSS - SIN
35	BIRDS LANDING SW STA	CONTRA COSTA SUB	230	230	T SSP	9.46		1	1113 - ACSS - SIN
36	BIRDS LANDING SW STA	RUSSELL	230	230	SSP	0.11		1	1431 - AAC - SING
37	BLACK TAP		230	230	T	0.51		1	795 - ACSR - SING
38	BORDEN	GREGG	230	230	SSP	6.21		1	1113 - AAC - SING
39	BOTTLE ROCK TAP D.W.R.		230	230	T	1.07		1	1113 - AAC - SING
40	BRENTWOOD	KELSO	230	230	T SSP	16.41		1	1113 - AAC - SING
41	BRIGHTON	BELLOTA	230	230	T	42.51		1	2300 - AAC - SING
42	BUCKS CREEK	ROCK CREEK-CRESTA	230	230	T SSP OTHERS	9.39		1	795 - ACSR - SING
43	BUENA VISTA PUMPING PLANT #		230	230	T	1.18		1	1113 - AAC - SING
44	BUENA VISTA PUMPING PLANT #		230	230	T	1.21		1	1113 - AAC - SING
45	BURNEY FOREST PRODUCTS TAP		230	230	T	0.04		1	795 - ACSR - SING
46	CALIENTE SW STA	MIDWAY #1	230	230	T SSP	27.17		1	954 - ACSS - SING
47	CALIENTE SW STA	MIDWAY #2	230	230	T	27.16		1	954 - ACSS - SING
48	CALIFORNIA FLATS SW STA	GATES	230	230	T SSP OTHERS	22.57		1	1113 - AAC - SING
49	CAMANCHE PUMPING PLANT TAP		230	230	T SSP	0.45		1	1113 - AAC - SING
50	CARBERRY SW STA	ROUND MTN	230	230	T SSP	12.61		1	500 - CU - SINGLE
51	CARIBOU	TABLE MTN	230	230	T SSP OTHERS S	54.34		1	954 - AAC - SINGL
52	CASTRO VALLEY	NEWARK	230	230	T	22.71		1	954 - AAC - SINGL
53	COBURN	LAS AGUILAS SW STA	230	230	T SSP	63.97		1	1113 - AAC - SING
54	COLGATE	RIO OSO	230	230	T	40.89		1	795 - ACSS - SING
55	CONTRA COSTA	BRENTWOOD	230	230	T SSP	10.06		1	954 - ACSR - SING
56	CONTRA COSTA	DELTA SWITCHYARD	230	230	T	18.46		1	954 - ACSR - SING
57	CONTRA COSTA	LAS POSITAS	230	230	T SSP	23.83		1	954 - ACSS - SING
58	CONTRA COSTA	LONE TREE	230	230		5.62		1	954 - ACSS - SING
59	CONTRA COSTA	MORAGA #1	230	230	T SSP	26.76		1	954 - ACSS - SING
60	CONTRA COSTA	MORAGA #2	230	230	T SSP	26.84		1	954 - ACSS - SING
61	CONTRA COSTA PP	CONTRA COSTA SUB	230	230	T	1.89		1	1113 - ACSS - SIN
62	CORTINA	VACA	230	230	T	53.29		1	954 - ACSR - SING
63	COTTLE	MELONES	230	230	T SSP	25.94		1	795 - ACSR - SING
64	COTTONWOOD	DELEVAN #1	230	230	T SSP	71.55		1	954 - ACSR - SING
65	COTTONWOOD	GLENN	230	230	T	48.33		1	643.7 - SINGLE 95
66	COTTONWOOD	LOGAN CREEK	230	230	T	59.28		1	643.7 - SINGLE 11
67	COTTONWOOD	DELEVAN #2	230	230	T	71.54		1	643.7 - SINGLE 95
68	COVE ROAD TAP		230	230	SSP	0.11		1	1113 - AAC - SING
69	COYOTE SW STA	METCALF	230	230	T	0.88		1	2300 - AAC - BUND
70	CRESTA	RIO OSO	230	230	T SSP	64.78		1	795 - ACSR - SING
71	DELEVAN	VACA #2	230	230	T	71.07		1	954 - ACSR - SING
72	DELEVAN	CORTINA	230	230	T	17.97		1	954 - ACSR - SING
73	DELEVAN	VACA #3	230	230	T	71.08		1	954 - ACSR - SING
74	DELEVAN	VACA #1	230	230	T	71.04		1	954 - ACSR - SING
75	DELTA SWITCHING YARD	TESLA	230	230	T	7.7		1	954 - ACSR - SING
76	DIABLO	MESA	230	230	T	40.34		1	1113 - AAC - SING
77	DIABLO PP STANDBY SUPPLY		230	230	T	0.46		1	1113 - AAC - SING
78	DOS AMIGOS PUMPING PLANT	PANOCHE	230	230	T SSP	23.68		1	795 - ACSR - SING
79	EASTSHORE	SAN MATEO	230	230	SSP	12.43		1	954 - ACSS - SING
80	EIGHT MILE ROAD	TESLA	230	230	T SSP OTHERS	26.64		1	1113 - AAC - SING
81	EIGHT MILE ROAD	STAGG	230	230	T SSP	7.2		1	1113 - AAC - SING
82	ELECTRA	BELLOTA	230	230	T SSP	29.23		1	643.7 - SINGLE 50
83	FIGARDEN #1 TAP		230	230	N/A	0.85		1	1250 KCMIL - ALUM
84	FIGARDEN #2 TAP		230	230	N/A	0.83		1	1250 KCMIL - ALUM
85	FULTON	LAKEVILLE-IGNACIO	230	230		15.84		1	2300 - AAC - SING
86	FULTON	IGNACIO #1	230	230	T SSP	40.73		1	2300 - AAC - SING
87	FULTON	LAKEVILLE	230	230	T SSP	25.51		1	1113 - AAC - SING
88	FULTON	LAKEVILLE	230	230	N/A	1.19		1	3500 KCMIL - ALUM
89	GATES	MUSTANG SW STA #1	230	230	T SSP	13.17		1	1113 - ACSS - SIN
90	GATES	MUSTANG SW STA #2	230	230	T SSP	13.18		1	1113 - ACSS - SIN
91	GATES	ARCO	230	230	T	35.18		1	1113 - AAC - SING
92	GATES	PANOCHE #1	230	230	T SSP	43.79		1	795 - ACSR - SING
93	GATES	PANOCHE #2	230	230	T SSP	43.8		1	795 - ACSR - SING
94	GATES	MIDWAY	230	230	T SSP	63.86		1	795 - ACSR - SING
95	GEYSERS #12	FULTON	230	230	T SSP OTHERS	24.09		1	1113 - AAC - SING
96	GEYSERS #13 TAP		230	230	T	2.06		1	1431 - AAC - SING
97	GEYSERS #16 TAP		230	230	T	1.29		1	1113 - AAC - SING
98	GEYSERS #17	FULTON	230	230	T SSP	26.14		1	1113 - AAC - SING
99	GEYSERS #18 TAP		230	230	T SSP	0.75		1	1113 - AAC - SING
100	GEYSERS #20 TAP		230	230		0.03		1	1431 - AAC - SING
101	GEYSERS #9	LAKEVILLE	230	230	SSP	41.71		1	2300 - AAC - BUND
102	GEYSERS #9	LAKEVILLE	230	230	N/A	1.24		1	3500 KCMIL - ALUM
103	GLENN	DELEVAN	230	230	SSP	37.42		1	954 - ACSR - SING
104	GOLD HILL	EIGHT MILE ROAD	230	230	T SSP	48.8		1	1113 - AAC - SING
105	GOLD HILL	LODI STIG	230	230	T	46.67		1	1113 - AAC - SING
106	GREGG	ASHLAN	230	230	T SSP OTHERS	7		1	795 - ACSR - SING
107	GREGG	HERNDON #1	230	230	T	0.6		1	1113 - AAC - BUND
108	GREGG	HERNDON #2	230	230	T	0.63		1	1113 - AAC - BUND
109	H	Z #1	230	230	N/A	6.92		1	2500 KCMIL - CU
110	H	Z #2	230	230	N/A	6.96		1	2500 KCMIL - CU
111	HAAS	MCCALL	230	230	T SSP	44.21		1	954 - AAC - SINGL
112	HELM	MCCALL	230	230	T	30.84		1	1113 - ACSS - SIN
113	HELMS	GREGG #1	230	230	T	60.67		1	1431 - AAC - BUND
114	HELMS	GREGG #2	230	230	T	60.68		1	1431 - AAC - BUND
115	HERNDON	ASHLAN	230	230	T SSP	6.39		1	795 - ACSR - SING
116	HERNDON	KEARNEY	230	230	T	10.82		1	1113 - AAC - SING
117	HICKS	METCALF	230	230	T SSP	9.07		1	954 - ACSS - SING
118	IGNACIO	SOBRANTE	230	230	T SSP	42.49		1	2300 - AAC - BUND
119	JEFFERSON	MARTIN	230	230	SSP	3.31		1	954 - ACSS - SING
120	JEFFERSON	MARTIN	230	230	N/A	24.41		1	2500 KCMIL - CU
121	KELSO	TESLA	230	230	T SSP	7.95		1	954 - ACSS - SING
122	LAKEVILLE	IGNACIO #2	230	230	T	14.53		1	1113 - AAC - SING
123	LAKEVILLE	IGNACIO #1	230	230	T SSP	15.49		1	2300 - AAC - BUND
124	LAKEVILLE	SOBRANTE #2	230	230	SSP	47.89		1	2156 - ACSS - SIN
125	LAKEVILLE	TULUCAY	230	230	T SSP OTHERS	17.22		1	1 - UNKNOWN - UNK
126	LAKEVILLE	TULUCAY	230	230	T SSP OTHERS	0.06		1	1 - UNKNOWN - UNK
127	LAMBIE SW STA	BIRDS LANDING SW STA	230	230	T	7.04		1	1113 - ACSS - SIN
128	LAS AGUILAS SW STA	PANOCHE #2	230	230	SSP	17.44		1	795 - ACSR - SING
129	LAS AGUILAS SW STA	PANOCHE #1	230	230	T SSP	17.44		1	795 - ACSR - SING
130	LAS POSITAS	NEWARK	230	230	T SSP	20.93		1	795 - ACSR - SING
131	LOCKEFORD	BELLOTA	230	230	T	12.32		1	2300 - AAC - SING
132	LODI STIG	EIGHT MILE ROAD	230	230	T SSP	2.18		1	1113 - AAC - SING
133	LOGAN CREEK	DELEVAN	230	230	T	12.35		1	954 - ACSR - SING
134	LONE TREE	CAYETANO	230	230	T SSP	15.4		1	954 - ACSS - SING
135	LONE TREE	CAYETANO	230	230	N/A	2.3		1	2000 KCMIL - CU
136	LOS BANOS	DOS AMIGOS	230	230	T	14.31		1	795 - ACSR - SING
137	LOS BANOS	PANOCHE #1	230	230	T OTHERS	37.18		1	1113 - AAC - SING
138	LOS BANOS	PANOCHE #2	230	230	T SSP	37.13		1	1113 - AAC - SING
139	LOS BANOS	SAN LUIS PUMPS #1	230	230	T	3.43		1	1113 - AAC - SING
140	LOS BANOS	SAN LUIS PUMPS #2	230	230	T	3.43		1	1113 - AAC - SING
141	LOS BANOS	QUINTO SW STA	230	230	T	12.06		1	795 - ACSS - PARA
142	LOS ESTEROS	METCALF	230	230	T SSP	63.25		1	795 - ACSR - PARA
143	LOS ESTEROS	METCALF	230	230	N/A	2.73		1	2500 KCMIL - CU
144	MALACHA TAP		230	230	T	0.12		1	954 - ACSR - SING
145	MELONES	WILSON	230	230	T SSP	61.61		1	795 - ACSR - SING
146	METCALF	MONTA VISTA #3	230	230		28.59		1	2300 - AAC - BUND
147	METCALF	MOSS LANDING #1	230	230	T SSP	35.76		1	954 - ACSS - SING
148	METCALF	MOSS LANDING #2	230	230	SSP	35.76		1	954 - ACSS - SING
149	MIDDLE FORK	GOLD HILL	230	230	T SSP OTHERS S	44.08		1	1113 - AAC - SING
150	MIDWAY	KERN #1	230	230	T SSP	41.75		1	795 - ACSR - SING
151	MIDWAY	KERN #3	230	230	T	20.88		1	1113 - AAC - SING
152	MIDWAY	KERN #4	230	230	T SSP	20.84		1	1113 - AAC - BUND
153	MIDWAY	WHEELER RIDGE #1	230	230	T	52.68		1	1113 - AAC - SING
154	MIDWAY	SUNSET	230	230	T	0.57		1	1431 - AAC - SING
155	MIDWAY	WHEELER RIDGE #2	230	230		52.65		1	1113 - AAC - SING
156	MONTA VISTA	COYOTE SW STA	230	230	T	27.83		1	2300 - AAC - BUND
157	MONTA VISTA	HICKS	230	230	T SSP	13.27		1	954 - ACSS - SING
158	MONTA VISTA	JEFFERSON #1	230	230	T SSP	19.72		1	1113 - AAC - SING
159	MONTA VISTA	JEFFERSON #2	230	230	SSP	19.73		1	1113 - AAC - SING
160	MONTA VISTA	SARATOGA	230	230	T SSP	5.49		1	1113 - AAC - SING
161	MONTEZUMA SW STA	BIRDS LANDING SW STA	230	230	SSP OTHERS	0.54		1	1431 - AAC - SING
162	MORAGA	CASTRO VALLEY	230	230	T	14.92		1	954 - ACSR - SING
163	MORRO BAY	DIABLO	230	230		15.78		1	1113 - AAC - SING
164	MORRO BAY	CALIFORNIA FLATS SW STA	230	230	T SSP OTHERS	46.19		1	954 - AAC - SINGL
165	MORRO BAY	MESA	230	230	T	35.27		1	1113 - AAC - SING
166	MORRO BAY	SOLAR SW STA #1	230	230	T SSP	45.55		1	954 - ACSS - SING
167	MORRO BAY	SOLAR SW STA #2	230	230	T SSP	45.56		1	954 - ACSS - SING
168	MORRO BAY	TEMPLETON	230	230	T SSP	16.43		1	954 - AAC - SINGL
169	MOSS LANDING	COBURN	230	230	T SSP SWP	64.03		1	795 - ACSR - SING
170	MOSS LANDING	LAS AGUILAS SW STA	230	230	SSP	51.89		1	795 - ACSR - SING
171	MOSS LANDING INTERPLANT 230		230	230	T	0.13		1	2300 - AAC - SING
172	MOSS LANDING TX BK 1	230 SWITCHYARD	230	230	SWP OTHERS	0.24		1	1113 - AAC - SING
173	MOSS LANDING TX BK 2	230 SWITCHYARD	230	230	T SSP	0.16		1	500 - SINGLE
174	MUSTANG SW STA	GREGG	230	230	T SSP	45.47		1	1113 - ACSS - SIN
175	MUSTANG SW STA	MCCALL	230	230	T SSP	42.11		1	1113 - ACSS - SIN
176	NEWARK	LOS ESTEROS	230	230	SSP	5.65		1	1113 - AAC - BUND
177	NEWARK	RAVENSWOOD	230	230	T	8.91		1	954 - ACSS - BUND
178	NEWARK	LOS ESTEROS	230	230	N/A	2.75		1	2500 KCMIL - CU
179	NEWARK E	F BUS TIE	230	230		0.22		1	1113 - AAC - BUND
180	NORTH DUBLIN	CAYETANO	230	230	T	3.02		1	954 - ACSS - SING
181	NORTH DUBLIN	VINEYARD	230	230	T	12.46		1	954 - ACSS - SING
182	NORTH DUBLIN	CAYETANO	230	230	N/A	2.81		1	2000 KCMIL - CU
183	NORTH DUBLIN	VINEYARD	230	230	N/A	11.07		1
184	PALERMO	COLGATE	230	230	T SSP	29.6		1	795 - ACSS - SING
185	PANOCHE	PANOCHE ENERGY CENTER	230	230	SSP	0.09		1	1113 - AAC - BUND
186	PANOCHE	TRANQUILLITY SW STA #1	230	230	T SSP	12.14		1	1113 - ACSS - SIN
187	PANOCHE	TRANQUILLITY SW STA #2	230	230	T SSP	12.14		1	1113 - ACSS - SIN
188	PARKWAY	MORAGA	230	230	T	23.64		1	954 - ACSR - SING
189	PEABODY	BIRDS LANDING SW STA	230	230	T SSP SWP	19.85		1	1113 - ACSS - SIN
190	PIT #1	COTTONWOOD	230	230	T SSP OTHERS S	59.75		1	500 - CU - SINGLE
191	PIT #3	PIT #1	230	230	T SSP OTHERS	22.69		1	518 - ACSR - SING
192	PIT #3	CARBERRY SW STA	230	230	T SSP	10.91		1	795 - ACSR - SING
193	PIT #4 TAP		230	230	T SSP	7.03		1	795 - ACSR - SING
194	PIT #5	ROUND MTN #1	230	230	T OTHERS SWP	13.12		1	795 - ACSR - SING
195	PIT #5	ROUND MTN #2	230	230	T SSP OTHERS S	13.11		1	795 - ACSR - SING
196	PIT #6 JCT	ROUND MTN	230	230	T SSP OTHERS S	8.15		1	795 - ACSR - SING
197	PIT #6 TAP		230	230	T OTHERS SWP	3.43		1	795 - ACSR - SING
198	PIT #7 TAP		230	230	T OTHERS SWP	3.59		1	795 - ACSR - SING
199	PITTSBURG	EASTSHORE	230	230	T SSP SWP	34.92		1	954 - ACSS - SING
200	PITTSBURG	SAN MATEO	230	230	T SSP OTHERS	47.4		1	954 - ACSS - SING
201	PITTSBURG	TASSAJARA	230	230	SSP	17.36		1	954 - ACSS - SING
202	PITTSBURG	SAN RAMON	230	230	T SSP SWP	21.66		1	954 - ACSS - SING
203	PITTSBURG	TESORO	230	230		11.27		1	2300 - AAC - BUND
204	PITTSBURG	TESLA #1	230	230	T SSP	31.35		1	1113 - AAC 954 -
205	PITTSBURG	TESLA #2	230	230	T SSP SWP	31.32		1	954 - ACSS - SING
206	PITTSBURG	TIDEWATER	230	230	T	11.27		1	2300 - AAC - BUND
207	POE	RIO OSO	230	230	T SSP OTHERS	56.09		1	795 - ACSR - SING
208	QUINTO SW STA	WESTLEY	230	230	T	57.55		1	795 - ACSS - PARA
209	RALPH TAP		230	230	SSP	0.06		1	1113 - AAC - SING
210	RANCHO SECO	BELLOTA #1	230	230	T	27.39		1	2300 - AAC - SING
211	RANCHO SECO	BELLOTA #2	230	230		27.36		1	2300 - AAC - SING
212	RAVENSWOOD	SAN MATEO #2	230	230	SSP	11.88		1	1113 - AAC - BUND
213	RAVENSWOOD	SAN MATEO #1	230	230	T SSP	11.89		1	1113 - AAC - BUND
214	RIO OSO	ATLANTIC	230	230	T SSP	17.68		1	1113 - AAC - SING
215	RIO OSO	BRIGHTON	230	230	T	27.17		1	795 - ACSR - SING
216	RIO OSO	GOLD HILL	230	230	T	28.63		1	1113 - AAC - SING
217	RIO OSO	LOCKEFORD	230	230	T	65.13		1	1113 - AAC - SING
218	ROCK CREEK	POE	230	230	T SSP SWP	26.98		1	795 - ACSR - SING
219	ROSSMOOR #1 TAP		230	230	T	0.69		1	1113 - AAC - SING
220	ROSSMOOR #2 TAP		230	230	T	0.66		1	1113 - AAC - SING
221	ROUND MTN	COTTONWOOD #2	230	230	T OTHERS	33.67		1	795 - ACSR - SING
222	ROUND MTN	COTTONWOOD #3	230	230	T SSP	33.36		1	500 - CU - SINGLE
223	RUSSELL CITY ENERGY CENTER	EASTSHORE #1	230	230	SSP	1.19		1	1113 - AAC - BUND
224	RUSSELL CITY ENERGY CENTER	EASTSHORE #2	230	230	SSP	1.2		1	1113 - AAC - BUND
225	SAN MATEO	MARTIN	230	230	N/A	13		1	3500 KCMIL
226	SAN RAMON	MORAGA	230	230	T SSP SWP	22.24		1	954 - ACSR - SING
227	SAN RAMON RESEARCH CENTER T		230	230	T SSP	3.27		1	1113 - AAC - SING
228	SANTA FE GEOTHERMAL TAP		230	230	T SSP	1.04		1	1113 - AAC - SING
229	SARATOGA	VASONA	230	230	T SSP	3.41		1	954 - ACSS - SING
230	SHILOH II	BIRDS LANDING SW STA	230	230	SSP	3.56		1	1431 - AAC - SING
231	SOLAR SW STA	CALIENTE SW STA #1	230	230	T	8.22		1	954 - ACSS - SING
232	SOLAR SW STA	CALIENTE SW STA #2	230	230	T	8.22		1	954 - ACSS - SING
233	SPI (BURNEY) TAP		230	230	T	0.05		1	795 - ACSR - SING
234	STAGG	TESLA	230	230		23.64		1	1113 - AAC - SING
235	STOCKDALE #1 TAP		230	230	T SSP	6.23		1	795 - ACSR - SING
236	STOCKDALE #2 TAP		230	230	T	6.14		1	1113 - AAC - SING
237	TABLE MTN	PALERMO	230	230	T OTHERS	14.57		1	795 - ACSS - SING
238	TABLE MTN	RIO OSO	230	230		50.17		1	795 - ACSS - SING
239	TASSAJARA	NEWARK	230	230	T SSP OTHERS	31.8		1	954 - AAC - SINGL
240	TEMPLETON	GATES	230	230	T	52.18		1	1113 - AAC - SING
241	TES TAP		230	230	T SSP	3.28		1	1113 - AAC - SING
242	TESLA	NEWARK #2	230	230	T SSP SWP	40.88		1	954 - ACSS - PARA
243	TESLA	NEWARK #1	230	230	T	28.19		1	2300 - AAC - BUND
244	TESLA	RAVENSWOOD	230	230	SSP	37.14		1	2300 - AAC - BUND
245	TESLA	TRACY #1	230	230	T	5.68		1	954 - ACSS - SING
246	TESLA	TRACY #2	230	230		5.68		1	954 - ACSS - SING
247	TESLA	WESTLEY	230	230	T	45.06		1	795 - ACSR - BUND
248	TESORO	SOBRANTE	230	230		12.32		1	2300 - AAC - BUND
249	TIDEWATER	SOBRANTE	230	230	T SSP	12.32		1	2300 - AAC - BUND
250	TIGER CREEK	ELECTRA	230	230	T OTHERS	13.65		1	1113 - AAC - SING
251	TIGER CREEK	VALLEY SPRINGS	230	230	T OTHERS	24.22		1	1113 - AAC - SING
252	TRANQUILLITY SW STA	HELM	230	230	T SSP	12.68		1	1113 - ACSS - SIN
253	TRANQUILLITY SW STA	KEARNEY	230	230	T SSP	36.9		1	1113 - ACSS - SIN
254	TULUCAY	VACA	230	230	T SSP	23.63		1	954 - ACSR - SING
255	US WINDPOWER #3 TAP		230	230	SSP	0.06		1	1113 - AAC - SING
256	VACA	BAHIA	230	230	T SSP	33.9		1	954 - ACSR - SING
257	VACA	PEABODY	230	230	T SSP	9.69		1	1113 - ACSS - SIN
258	VACA	LAKEVILLE #1	230	230	T SSP	40.93		1	954 - ACSR - SING
259	VACA	LAMBIE SW STA	230	230	T	13.95		1	1113 - ACSS - SIN
260	VACA	PARKWAY	230	230	T SSP	27.76		1	954 - ACSR - SING
261	VACA DIXON	MORAGA #1	230	230	T	3.08		1	954 - ACSS - SING
262	VALLEY SPRINGS	BELLOTA	230	230	T	20.67		1	643.7 - SINGLE 50
263	VASONA	METCALF	230	230	T SSP	13.29		1	954 - ACSS - SING
264	VINEYARD	NEWARK	230	230	T	14.36		1	795 - ACSR - SING
265	VINEYARD	NEWARK	230	230	N/A	5.94		1	2000 KCMIL - CU
266	WARNERVILLE	WILSON	230	230		38.4		1	954 - ACSR - SING
267	WEBER	TESLA	230	230	T	23.71		1	954 - ACSS - SING
268	WHEELER RIDGE PUMPING PLANT		230	230	T	0.25		1	1113 - AAC - SING
269	WHEELER RIDGE PUMPING PLANT		230	230		0.23		1	1113 - AAC - SING
270	WILSON	GREGG	230	230	T SSP	41.44		1	795 - ACSR - SING
271	WILSON	BORDEN	230	230	T SSP	35.37		1	500 - SINGLE 1113
272	WIND GAP PUMPING PLANT #1 T		230	230	T	1.64		1	1113 - AAC - SING
273	WIND GAP PUMPING PLANT #2 T		230	230		1.62		1	1113 - AAC - SING
274	WINDMASTER TAP		230	230	SSP	0.11		1	1113 - AAC - SING
275	ZA	1	230	230	N/A	3.41		1	2000 KCMIL - CU
276	7TH STANDARD	KERN	115	115	T SSP OTHERS S	6.75		1	715.5 - AAC - SIN
277	A	P #1	115	115	N/A	2.46		1	3500 KCMIL - CU
278	A	H-W #1	115	115	N/A	4.95		1	1250 KCMIL - CU
279	A	X #1	115	115	N/A	2.67		1	1250 KCMIL
280	A	Y #1	115	115	N/A	3.33		1	1250 KCMIL - CU
281	A	Y #2	115	115	N/A	2.85		1	3000 KCMIL - ALUM
282	A	H-W #2	115	115	N/A	5.06		1	1250 KCMIL
283	ADOBE SW STA	LAMONT	115	115	T SSP SWP	21.2		1	715.5 - AAC - SIN
284	AEC SITE #1 TAP		115	115	T OTHERS SWP	1.6		1	4/0 - AAC - SINGL
285	AEC SITE #2 TAP		115	115	SWP SSP	2.16		1
286	AGNEW TAP		115	115	SWP SSP	1.32		1	715.5 - AAC - SIN
287	AIR PRODUCTS TAP		115	115	SWP	0.29		1	4/0 - AAC - SINGL
288	AMERIGAS TAP		115	115	SWP SSP	0.49		1	715.5 - AAC - SIN
289	AMES DISTRIBUTION	AMES	115	115	SSP	0.1		1	715.5 - AAC - SIN
290	APPLE HILL #1 TAP		115	115	SWP SSP	1.42		1	4/0 - AAC - SINGL
291	APPLE HILL #2 TAP		115	115	SWP SSP	1.43		1	397.5 - AAC - SIN
292	APPLIED MATERIALS	BRITTON	115	115	SSP	0.47		1	477 - ACSS - SING
293	APPLIED MATERIALS	BRITTON	115	115	N/A	0.74		1	2500 KCMIL - CU
294	ARVIN EDISON TAP		115	115	SWP	1.06		1	397.5 - AAC - SIN
295	ATLANTIC	PLEASANT GROVE #1	115	115	T SSP SWP	5.33		1	477 - ACSS - SING
296	ATLANTIC	PLEASANT GROVE #2	115	115	SWP SSP	5.36		1	715.5 - AAC - SIN
297	ATWATER	EL CAPITAN	115	115	T SSP	7.31		1	715.5 - AAC - SIN
298	ATWATER	LIVINGSTON-MERCED	115	115	SWP SSP	24.26		1	715.5 - AAC - SIN
299	ATWATER	CRESSEY	115	115	SWP SSP	5.91		1	715.5 - AAC - SIN
300	BADGER CREEK (PSE) TAP		115	115	SWP	1.07		1	715.5 - AAC - SIN
301	BAIR	BELMONT	115	115	SSP	3.64		1	477 - ACSS - SING
302	BALCH	SANGER	115	115	T SSP OTHERS	35.62		1	715.5 - AAC - SIN
303	BARKER SLOUGH TAP		115	115	SWP	1.62		1	4/0 - AAC - SINGL
304	BARTON	AIRWAYS-SANGER	115	115	T SSP OTHERS	11.65		1	2300 - AAC - SING
305	BEAR MTN TAP		115	115	SWP SSP	1.27		1	715.5 - AAC - SIN
306	BEARDSLEY TAP		115	115	T OTHERS SWP	2.2		1	4/0 - ACSR - SING
307	BELL	PLACER	115	115	T SWP	7.94		1	715.5 - AAC - SIN
308	BELLOTA	RIVERBANK-MELONES SW STA	115	115	T SSP OTHERS S	44.65		1	715.5 - AAC - SIN
309	BELLOTA	RIVERBANK	115	115	SWP SSP OTHERS	18.87		1	715.5 - AAC - SIN
310	BELRIDGE TAP		115	115	SWP SSP	6.94		1	715.5 - AAC - SIN
311	BIG BEND	CLAYTON #1	115		T SWP	0.02		1
312	BOGUE	RIO OSO	115	115	T SSP	21.24		1	1113 - AAC - SING
313	BOLLMAN #1 TAP		115	115	T SSP	2.14		1	4/0 - AAC - SINGL
314	BOLLMAN #2 TAP		115	115	T SSP	2.19		1	4/0 - AAC - SINGL
315	BOLTHOUSE FARMS TAP		115	115	SWP	0.11		1	4/0 - AAC - SINGL
316	BRIDGEVILLE	COTTONWOOD	115	115	T SSP OTHERS S	86.06		1	397.5 - ACSR - SI
317	BRIGHTON	CLAYTON #1	115	115	T	6.72		1	3/0 - CU - SINGLE
318	BRIGHTON	CLAYTON #2	115	115		6.72		1	3/0 - CU - SINGLE
319	BRIGHTON	DAVIS	115	115	T SSP OTHERS S	42.73		1	715.5 - AAC - SIN
320	BRIGHTON	DAVIS	115	115	T SSP OTHERS S	17.36		1	715.5 - AAC - SIN
321	BRIGHTON	GRAND ISLAND #1	115	115	T SSP OTHERS S	24.99		1	715.5 - AAC - SIN
322	BRIGHTON	GRAND ISLAND #1	115	115	T SSP OTHERS S	0.14		1	715.5 - AAC - SIN
323	BRIGHTON	GRAND ISLAND #2	115	115	SWP SSP	25.04		1	715.5 - AAC - SIN
324	BRIGHTON	GRAND ISLAND #2	115	115	SWP SSP	0.14		1	715.5 - AAC - SIN
325	BRITTON	MONTA VISTA	115	115	SSP	7.17		1	477 - ACSS - SING
326	BRUNSWICK #1 TAP		115	115	T	6.98		1	397.5 - ACSR - SI
327	BRUNSWICK #2 TAP		115	115	T	7		1	397.5 - ACSR - SI
328	BUELLTON TAP		115	115	SWP	1.75		1	397.5 - AAC - SIN
329	BUTTE	SYCAMORE CREEK	115	115	SWP SSP	18.17		1	715.5 - AAC - SIN
330	BUTTE VALLEY	CARIBOU	115	115	T SSP OTHERS S	7.42		1	795 - ACSR - SING
331	C	X #3	115	115	N/A	3.67		1	3500 KCMIL - CU
332	C	L #1	115	115	N/A	1.1		1	3000 KCMIL
333	C	X #2	115	115	N/A	3.38		1	1250 KCMIL - CU
334	CABRILLO	SANTA YNEZ SW STA	115	115	SWP SSP	14.59		1	715.5 - AAC - SIN
335	CAL PEAK	VACA	115	115	SWP	0.11		1	715.5 - AAC - SIN
336	CAL WATER TAP		115	115	SWP SSP	2.15		1	715.5 - AAC - SIN
337	CALIFORNIA AVE	MCCALL	115	115	T SSP SWP	23.66		1	477 - ACSS - SING
338	CALLENDER SW STA	MESA	115	115	T SSP SWP	13.77		1	715.5 - AAC - SIN
339	CAMANCHE TAP		115	115	SWP	6.71		1	4/0 - AAC - SINGL
340	CAMP EVERS	PAUL SWEET	115	115	SWP SSP OTHERS	5.22		1	715.5 - AAC - SIN
341	CANTUA TAP		115	115	SWP SSP OTHERS	1.83		1	397.5 - AAC - SIN
342	CARIBOU	PALERMO	115	115	T SSP OTHERS S	54.89		1	715.5 - AAC - SIN
343	CARQUINEZ #1 TAP		115	115	T SSP	0.51		1	397.5 - AAC - SIN
344	CARQUINEZ #2 TAP		115	115	SSP	0.52		1	397.5 - AAC - SIN
345	CARRIZO PLAINS TAP		115	115	SSP	0.04		1	715.5 - AAC - SIN
346	CASCADE	COTTONWOOD	115	115	T SSP OTHERS S	19.46		1	250 - CU - SINGLE
347	CAWELO C TAP		115	115	SWP SSP	1.33		1	397.5 - AAC - SIN
348	CERTAINTEED TAP		115	115	SWP SSP	2.53		1	397.5 - AAC - SIN
349	CHARCA	FAMOSO	115	115	SWP SSP	7.15		1	250 - CU - SINGLE
350	CHCF TAP		115	115	SWP SSP	3		1	397.5 - AAC - SIN
351	CHENEY #1 TAP		115	115	T SSP SWP	4.1		1	397.5 - ACSR - SI
352	CHENEY #2 TAP		115	115	SWP SSP	1.97		1	397.5 - AAC - SIN
353	CHINESE CAMP (ULTRA POWER)		115	115	SWP	2.07		1	4/0 - ACSR - SING
354	CHOWCHILLA	KERCKHOFF	115	115	T SSP OTHERS S	42.52		1	715.5 - AAC - SIN
355	CHOWCHILLA #1 TAP		115	115	SWP	1.25		1	397.5 - AAC - SIN
356	CHRISTIE	SOBRANTE	115	115	T	7.84		1	715.5 - AAC - SIN
357	CITY #1 TAP		115	115	SWP	0.07		1	397.5 - AAC - SIN
358	CITY #2 TAP		115	115	SWP SSP OTHERS	1.37		1	397.5 - AAC - SIN
359	CLAYTON	MEADOW LANE	115	115	SWP SSP	7.06		1	715.5 - AAC - SIN
360	COLES LEVEE TAP		115	115	SWP	0.22		1	4/0 - AAC - SINGL
361	COLUMBIA SOLAR 115kV TAP		115	115	SWP SSP	0.45		1	4/0 - AAC - SINGL
362	CONTRA COSTA #1		115	115	T SSP	11.15		1	1113 - AAC - SING
363	CONTRA COSTA #2		115	115		1.41		1	3/0 - CU - SINGLE
364	COOLEY LANDING	PALO ALTO	115	115	SWP SSP	2.72		1	715.5 - AAC - SIN
365	CORCORAN	OLIVE SW STA	115	115	T SSP	36.83		1	1113 - AAC - SING
366	CORONA	LAKEVILLE	115	115	SWP SSP	5.79		1	477 - ACSS - SING
367	CORTINA	MENDOCINO #1	115	115	T SWP	60.95		1	397.5 - ACSR - SI
368	COTTONWOOD	PANORAMA	115	115	SWP SSP	2.95		1	397.5 - AAC - SIN
369	CRAG VIEW	CASCADE	115	115	T OTHERS SWP	21.6		1	250 - CU - SINGLE
370	CRAZY HORSE CANYON	SAN BENITO	115	115	T SSP	8.95		1	477 - ACSS - SING
371	CRAZY HORSE CANYON	HOLLISTER	115	115	SSP	17.23		1	2/0 - CU - SINGLE
372	CRAZY HORSE CANYON	SALINAS-SOLEDAD #1	115	115	T SSP	35.35		1	3/0 - CU - SINGLE
373	CRAZY HORSE CANYON	SALINAS-SOLEDAD #2	115	115	T SSP	35.41		1	477 - ACSS - SING
374	CYMRIC TAP		115	115	SWP	0.18		1	397.5 - AAC - SIN
375	D	L #1	115	115	N/A	2.31		1	3000 KCMIL
376	DAIRYLAND	MENDOTA	115	115	T SSP SWP	28.69		1	477 - ACSS - SING
377	DANISH CREAMERY TAP		115	115	SWP	1.2		1	4/0 - AAC - SINGL
378	DE FRANCESCO TAP		115	115	SWP SSP	1.02		1	4/0 - AAC - SINGL
379	DEEPWATER #1 TAP		115	115	T SSP	2.29		1	715.5 - AAC - SIN
380	DEEPWATER #2 TAP		115	115	SWP SSP	2.45		1	715.5 - AAC - SIN
381	DISCOVERY TAP		115	115	SWP	2.1		1	715.5 - AAC - SIN
382	DIVIDE	CABRILLO #2	115	115	SWP SSP OTHERS	11.55		1	715.5 - AAC - SIN
383	DIVIDE	CABRILLO #1	115	115	SWP SSP OTHERS	14.6		1	715.5 - AAC - SIN
384	DIXON LANDING	MCKEE	115	115	SWP SSP	8.3		1	477 - ACSS - SING
385	DOLAN RD #1 TAP		115	115	T SSP	0.32		1	266.8 - AAC - SIN
386	DOLAN RD #2 TAP		115	115	T SSP	0.33		1	266.8 - AAC - SIN
387	DONNELLS	CURTIS	115	115	T SSP OTHERS S	26.81		1	397.5 - ACSR - SI
388	DOUBLE C (PSE) TAP		115	115	SWP	0.06		1	715.5 - AAC - SIN
389	DRUM	RIO OSO #1	115	115	T SSP OTHERS	44.64		1	266.8 - AAC - SIN
390	DRUM	RIO OSO #2	115	115	T SSP OTHERS	44.65		1	266.8 - AAC - SIN
391	DRUM	SUMMIT #1	115	115	T SSP OTHERS S	27.36		1	397.5 - ACSR - SI
392	DRUM	SUMMIT #2	115	115	T SSP OTHERS S	28.36		1	397.5 - ACSR - SI
393	DRUM	HIGGINS	115	115	T SSP OTHERS S	47.75		1	715.5 - AAC - SIN
394	DRUM PH #2 TAP		115	115	SWP SSP	0.09		1	250 - CU - SINGLE
395	DUMBARTON	NEWARK	115	115	T SSP	7.14		1	795 - ACSS - SING
396	DUTCH FLAT #2 TAP		115	115	T OTHERS SWP	0.43		1
397	EAGLE ROCK	CORTINA	115	115	SWP SSP OTHERS	43.38		1	715.5 - AAC - SIN
398	EAGLE ROCK	REDBUD	115	115	T SSP OTHERS S	23.31		1	715.5 - AAC - SIN
399	EAGLE ROCK	FULTON-SILVERADO	115	115	T SSP	46.94		1	715.5 - AAC - SIN
400	EAST GRAND	SAN MATEO	115	115	T SSP OTHERS	7.89		1	477 - ACSS - SING
401	EAST GRAND	SAN MATEO	115	115	N/A	0.22		1	3000 KCMIL - ALUM
402	EASTSHORE	DUMBARTON	115	115	T SSP	12.38		1	477 - ACSS - BUND
403	EASTSHORE	MT EDEN #1	115	115	T	1.04		1	715.5 - AAC - SIN
404	EASTSHORE	MT EDEN #2	115	115		1		1	715.5 - AAC - SIN
405	EASTSHORE	CERBERUS	115	115	SSP	0.48		1	397.5 - AAC - SIN
406	EBMUD TAP		115	115	OTHERS	0.02		1
407	EBMUD TAP		115	115	N/A	0.94		1	500 KCMIL
408	EDES #1 TAP		115	115	SWP SSP	0.05		1	715.5 - AAC - SIN
409	EDES #2 TAP		115	115	T SWP	0.04		1	715.5 - AAC - SIN
410	EL CAPITAN	WILSON	115	115	T SSP	8.12		1	715.5 - AAC - SIN
411	EL DORADO	MISSOURI FLAT #1	115	115	T SSP OTHERS S	14.43		1	715.5 - AAC - SIN
412	EL DORADO	MISSOURI FLAT #2	115	115	SWP SSP	14.41		1	715.5 - AAC - SIN
413	EL PATIO	SAN JOSE A	115	115	T SSP SWP	7.08		1	715.5 - AAC - PAR
414	ELLIS TAP		115	115	SWP	0.17		1	4/0 - AAC - SINGL
415	EXCELSIOR SW STA	FIVE POINTS PV	115	115		0.03		1
416	EXCELSIOR SW STA	SCHINDLER #1	115	115	T SSP	5.24		1	715.5 - AAC 397.5
417	EXCELSIOR SW STA	SCHINDLER #2	115	115	SSP	5.23		1	715.5 - AAC 397.5
418	EXCHEQUER	LE GRAND	115	115	SWP SSP OTHERS	29.75		1	266.8 - AAC - SIN
419	FAIRVIEW	MARTINEZ SW STA	115	115	SWP	0.1		1
420	FAIRWAY #1 TAP		115	115	SWP SSP OTHERS	2.83		1	266.8 - AAC - SIN
421	FAIRWAY #2 TAP		115	115		1.52		1	397.5 - AAC - SIN
422	FELLOWS	MIDSUN	115	115	SWP SSP OTHERS	4.73		1	715.5 - AAC - SIN
423	FELLOWS	TAFT	115	115	T SSP OTHERS S	7.93		1	715.5 - AAC - SIN
424	FIBREBOARD STANDARD TAP		115	115	SWP	0.02		1
425	FIBREBOARD TAP		115	115	T SSP SWP	1.03		1	4/0 - AAC - SINGL
426	FLINT TAP		115	115	T SSP SWP	1.96		1	4/0 - AAC - SINGL
427	FMC	SAN JOSE B	115	115	SSP	1.61		1	795 - ACSS - SING
428	FORBESTOWN TAP		115	115	SWP SSP OTHERS	0.22		1	397.5 - ACSR - SI
429	FRITO LAY TAP		115	115	SWP SSP	0.53		1	4/0 - AAC - SINGL
430	FROGTOWN #1 TAP		115	115	T	0.12		1	2/0 - CU - SINGLE
431	FROGTOWN #2 TAP		115	115		0.11		1	2/0 - CU - SINGLE
432	FULTON	PUEBLO	115	115	T SSP OTHERS S	59.9		1	715.5 - AAC - SIN
433	FULTON	SANTA ROSA #1	115	115	T SSP SWP	6.69		1	477 - ACSS - SING
434	FULTON	SANTA ROSA #2	115	115	SWP SSP	6.29		1	477 - ACSS - SING
435	FULTON JCT	VACA	115	115	T SSP	11.93		1	477 - ACSS - SING
436	GALLO	LIVINGSTON	115	115	SWP SSP	4.2		1	715.5 - AAC - SIN
437	GALLO	CRESSEY	115	115	SWP SSP	14.43		1	715.5 - AAC - SIN
438	GEYSERS #11	EAGLE ROCK	115	115	SSP	0.64		1	1113 - AAC - SING
439	GEYSERS #3	CLOVERDALE	115	115	T SSP OTHERS S	12.07		1	715.5 - AAC - SIN
440	GEYSERS #3	EAGLE ROCK	115	115	SWP SSP OTHERS	1.77		1	715.5 - AAC - SIN
441	GEYSERS #5	GEYSERS #3	115	115	SWP	0.49		1	715.5 - AAC - SIN
442	GEYSERS #7	EAGLE ROCK	115	115	T SSP OTHERS S	1.4		1	715.5 - AAC - SIN
443	GILL RANCH TAP		115	115	SWP SSP	9.15		1	715.5 - AAC - SIN
444	GILROY ENERGY TAP		115	115	SWP	0.28		1	715.5 - AAC - BUN
445	GISH TAP		115	115	SWP	0.96		1	1 - UNKNOWN - UNK
446	GOLD HILL	BELLOTA-LOCKEFORD	115	115	T SSP	87.28		1	715.5 - AAC - SIN
447	GOLD HILL	CLARKSVILLE	115	115	T SSP	5.77		1	477 - ACSS - SING
448	GOLDEN VALLEY TAP		115	115	SWP SSP	1.59		1	4/0 - AAC - SINGL
449	GOLDTREE TAP		115	115	SWP	2.3		1	397.5 - AAC - SIN
450	GRANT	EASTSHORE #1	115	115	T SSP	4.33		1	715.5 - AAC - SIN
451	GRANT	EASTSHORE #2	115	115	T	4.2		1	715.5 - AAC - SIN
452	GREEN VALLEY	CAMP EVERS	115	115	T SSP OTHERS S	18.59		1	715.5 - AAC - SIN
453	GREEN VALLEY	LLAGAS	115	115	T SSP OTHERS S	24.85		1	715.5 - AAC - SIN
454	GREEN VALLEY	PAUL SWEET	115	115	T SSP OTHERS S	16.03		1	715.5 - AAC - SIN
455	GREENLEAF #1 TAP		115	115	SWP SSP	4.84		1	715.5 - AAC - SIN
456	GRIZZLY TAP (SVP)		115	115	T SWP	0.16		1
457	GUARDIAN #1 TAP		115	115	SWP	0.75		1	4/0 - AAC - SINGL
458	GUARDIAN #2 TAP		115	115	SWP	0.13		1	4/0 - AAC - SINGL
459	GWF	KINGSBURG	115	115	SWP SSP	21.62		1	1113 - AAC - SING
460	H	P #3	115	115	T OTHERS	0.17		1	715.5 - AAC - SIN
461	H	P #4	115	115	N/A	5.16		1	3500 KCMIL - CU
462	H	P #1	115	115	N/A	3.8		1	1000 KCMIL - CU
463	H	Y #1	115	115	N/A	7.23		1	1250 KCMIL - CU
464	H	P #3	115	115	N/A	3.59		1	1250 KCMIL - CU
465	HEINZ TAP		115		SWP	0.79		1	4/0 - AAC - SINGL
466	HENRIETTA	LEPRINO SW STA	115	115	SWP SSP	6.03		1	1113 - AAC - SING
467	HERNDON	BARTON	115	115	T SSP OTHERS S	12.68		1	477 - ACSS 1431 -
468	HERNDON	BULLARD #1	115	115	T SSP	11.43		1	954 - ACSS - SING
469	HERNDON	BULLARD #2	115	115	SWP SSP	11.42		1	954 - ACSS - SING
470	HERNDON	MANCHESTER	115	115	SWP SSP	9.27		1	1431 - AAC - SING
471	HERNDON	WOODWARD	115	115	T SSP SWP	12.97		1	1113 - AAC - SING
472	HIGGINS	BELL	115	115	T SSP SWP	18.77		1	715.5 - AAC - SIN
473	HONCUT TAP		115	115	T SSP	1.65		1	4/0 - AAC - SINGL
474	HOWLAND ROAD TAP		115	115	SWP	0.9		1	4/0 - AAC - SINGL
475	HUMBOLDT	BRIDGEVILLE	115	115	T SSP OTHERS S	30.28		1	397.5 - ACSR - SI
476	HUMBOLDT	TRINITY	115	115	T SSP OTHERS S	68.57		1	4/0 - ACSR - SING
477	HUMBOLDT BAY	HUMBOLDT #1	115	115	T SSP	6.31		1	397.5 - AAC - SIN
478	IBM BAILEY AVE TAP		115	115	SWP SSP	2		1	397.5 - AAC - SIN
479	IBM HARRY RD #1 TAP		115	115	T	0.58		1	397.5 - AAC - SIN
480	IBM HARRY RD #2 TAP		115	115	SSP	0.58		1	397.5 - AAC - SIN
481	IGNACIO	MARE ISLAND #1	115	115	T SSP SWP	39.48		1	715.5 - AAC - SIN
482	IGNACIO	MARE ISLAND #2	115	115	T OTHERS	43.08		1	715.5 - AAC - SIN
483	IGNACIO	SAN RAFAEL #1	115	115	T SSP	11.54		1	715.5 - AAC - SIN
484	IGNACIO	SAN RAFAEL #3	115	115	SWP OTHERS	8.65		1	715.5 - AAC - SIN
485	IMHOFF TAP		115	115	SWP SSP	1.43		1	2 - UNKNOWN - UNK
486	INGRAM CREEK TAP		115	115	SWP SSP	0.5		1	4/0 - AAC - SINGL
487	JAMESON CANYON PUMPING PLAN		115	115	SWP SSP	0.19		1	4/0 - AAC - SINGL
488	JARVIS	CRYOGENICS	115	115	T	0.03		1	715.5 - AAC - SIN
489	JESSUP TAP		115	115	SWP SSP OTHERS	0.86		1	397.5 - ACSR - SI
490	K	D #1	115	115	N/A	2.44		1	2000 KCMIL - CU
491	K	D #2	115	115	N/A	2.57		1	3000 KCMIL - CU
492	KAMM TAP		115	115	SWP OTHERS	0.52		1	4/0 - AAC - SINGL
493	KANAKA TAP		115	115	SWP SSP OTHERS	2.59		1	4/0 - ACSR - SING
494	KANSAS PV	LEPRINO SW STA	115	115	SSP	0.17		1	1113 - AAC - SING
495	KERCKHOFF	CLOVIS-SANGER #1	115	115	T SSP OTHERS S	37.05		1	715.5 - AAC - SIN
496	KERCKHOFF	CLOVIS-SANGER #2	115	115	T SSP SWP	32.05		1	715.5 - AAC - SIN
497	KERCKHOFF #1	KERCKHOFF #2	115	115	T SSP	1.58		1	AAC - SINGLE 266.
498	KERN	KERN FRONT	115	115	SWP SSP OTHERS	12.52		1	715.5 - AAC - SIN
499	KERN	TEVIS-STOCKDALE-LAMONT	115	115	T SSP OTHERS S	21.52		1	715.5 - AAC - SIN
500	KERN	LIVE OAK	115	115	T SSP SWP	10.74		1	715.5 - AAC - SIN
501	KERN	MAGUNDEN-WITCO	115	115	T SSP OTHERS S	19.58		1	715.5 - AAC - SIN
502	KERN	ROSEDALE	115	115	T SSP SWP	1.71		1	715.5 - AAC - SIN
503	KERN	TEVIS-STOCKDALE	115	115	T SSP SWP	19.74		1	715.5 - AAC - SIN
504	KERN	TEVIS-STOCKDALE (21KV)	115	115	T SSP SWP	0.67		1	715.5 - AAC - SIN
505	KERN	WESTPARK #1	115	115	T SSP	3.84		1	715.5 - AAC - SIN
506	KERN	WESTPARK #2	115	115	T	3.83		1	715.5 - AAC - SIN
507	KERN OIL	DEXZEL	115	115	SWP	0.44		1	715.5 - AAC - SIN
508	KERN OIL	WITCO	115	115	T SSP	4.2		1	715.5 - AAC - SIN
509	KERNWATER TAP		115	115	SWP SSP	0.67		1	4/0 - AAC - SINGL
510	KIFER	FMC	115	115	T SSP	6.01		1	715.5 - AAC - SIN
511	KIFER	FMC	115	115	N/A	1.11		1
512	KINGS RIVER	SANGER-REEDLEY	115	115	T SSP SWP	43.35		1	715.5 - AAC - SIN
513	KINGSBURG	CORCORAN #1	115	115	T SSP	27.16		1	715.5 - AAC - SIN
514	KINGSBURG	WAUKENA SW STA	115	115	T	24.94		1	715.5 - AAC - SIN
515	KINGSBURG COGEN TAP		115	115	SWP	1.22		1	397.5 - AAC - SIN
516	KM GREEN TAP		115	115	SSP	0.2		1	397.5 - ACSR - SI
517	KYOHO TAP		115	115	SWP SSP	2.2		1	397.5 - AAC - SIN
518	LAKEVILLE	SONOMA #1	115	115	SWP SSP	6.68		1	477 - ACSS - SING
519	LAKEVILLE	SONOMA #2	115	115	SWP SSP	7.18		1	477 - ACSS - SING
520	LAKEVILLE	SONOMA #1	115	115	N/A	0.55		1	2500 KCMIL - CU
521	LAKEWOOD	MEADOW LANE-CLAYTON	115	115	T SSP SWP	9.55		1	715.5 - AAC - SIN
522	LAKEWOOD	CLAYTON	115	115	SSP	5.52		1	477 - ACSS - SING
523	LAMMERS	KASSON	115	115	T SSP SWP	8.23		1	477 - ACSS - SING
524	LAMONT	GRIMMWAY MALAGA	115	115	SWP SSP	3.55		1	4/0 - AAC - SINGL
525	LAS PALMAS TAP		115	115	SWP SSP	0.85		1	4/0 - AAC - SINGL
526	LAS PLUMAS TAP		115	115	SWP SSP	0.48		1	1113 - AAC - SING
527	LAWRENCE	MONTA VISTA	115	115	T SSP SWP	9.44		1	250 - CU - SINGLE
528	LAWRENCE LIVERMORE LAB #1 T		115	115	T SSP SWP	9		1	954 - ACSS - SING
529	LAWRENCE LIVERMORE LAB #2 T		115	115	T SWP	9.41		1	2/0 - CU - SINGLE
530	LE GRAND	DAIRYLAND	115	115	T SSP SWP	11.4		1	715.5 - AAC - SIN
531	LE GRAND	CHOWCHILLA	115	115	T SSP SWP	10.94		1	1113 - AAC - SING
532	LEPRINO FOODS	LEPRINO SW STA	115	115	SWP SSP	6.41		1	715.5 - AAC - SIN
533	LEPRINO FOODS (TRACY) TAP		115	115	SWP	0.02		1	4/0 - AAC - SINGL
534	LEPRINO SW STA	HENRIETTA PV	115	115	SSP	0.06		1	1113 - AAC - SING
535	LEPRINO SW STA	GWF HANFORD SW STA	115	115	SWP SSP	12.38		1	1113 - AAC - SING
536	LERDO	KERN OIL-7TH STANDARD	115	115	T SSP OTHERS S	16.35		1	715.5 - AAC - SIN
537	LERDO	FAMOSO	115	115	T SSP SWP	13.45		1	715.5 - AAC - SIN
538	LINCOLN	PLEASANT GROVE	115	115	SWP SSP OTHERS	7.38		1	715.5 - AAC - SIN
539	LINDE TAP		115	115	SWP SSP	0.62		1	397.5 - AAC - SIN
540	LIVE OAK	KERN OIL	115	115	T	4.4		1	715.5 - AAC - SIN
541	LIVE OAK TAP		115	115	SWP	3.97		1	715.5 - AAC - SIN
542	LLAGAS	GILROY FOODS	115	115	SWP	1.98		1	715.5 - AAC - BUN
543	LLAGAS	HOLLISTER	115	115	T SSP SWP	21.56		1	3/0 - CU - SINGLE
544	LOCKHEED #1 TAP		115	115	SWP SSP	1.72		1	397.5 - AAC - SIN
545	LOCKHEED #2 TAP		115	115	SWP SSP OTHERS	1.28		1	397.5 - AAC - SIN
546	LOS ESTEROS	MONTAGUE	115	115	SSP	4.64		1	795 - ACSS - SING
547	LOS ESTEROS	TRIMBLE	115	115	SSP	3.73		1	795 - ACSS - SING
548	LOS ESTEROS	AGNEW	115	115	SWP SSP	1.37		1	715.5 - AAC - SIN
549	LOS ESTEROS	NORTECH	115	115	SSP	1.98		1	715.5 - AAC - BUN
550	LOWER LAKE	HOMESTAKE	115	115	SWP SSP	16.12		1	4/0 - AAC - SINGL
551	LUCERNE #1 TAP		115	115	SWP	0.23		1	4/0 - ACSR - SING
552	LUCERNE #2 TAP		115	115	SWP SSP	0.23		1	4/0 - ACSR - SING
553	MABURY TAP		115	115	SWP SSP	2.81		1	715.5 - AAC - SIN
554	MADISON	VACA	115	115	T SSP OTHERS S	22.99		1	3/0 - CU - SINGLE
555	MALAGA	KRCD	115	115	SWP	0.99		1	1113 - AAC - SING
556	MANCHESTER	AIRWAYS-SANGER	115	115	T SSP	15.07		1	1431 - AAC - SING
557	MANTECA	VIERRA	115	115	T SSP SWP	3.98		1	477 - ACSS - SING
558	MANVILLE TAP		115	115	SWP SSP OTHERS	5.54		1	715.5 - AAC - SIN
559	MARTIN	DALY CITY #1	115	115	T	3.93		1	397.5 - AAC - SIN
560	MARTIN	DALY CITY #2	115	115		3.93		1	397.5 - AAC - SIN
561	MARTIN	EAST GRAND	115	115	T SSP SWP	3.96		1	477 - ACSS - SING
562	MARTIN	MILLBRAE #1	115	115	T SSP	7.28		1	477 - ACSS - SING
563	MARTIN	SF AIRPORT	115	115	T SSP	5.43		1	477 - ACSS - SING
564	MARTIN	MILLBRAE #1	115	115	N/A	0.22		1	3000 KCMIL - ALUM
565	MARTIN	SF AIRPORT	115	115	N/A	0.23		1	3000 KCMIL - ALUM
566	MARTINEZ	SHELL OIL #1	115	115		0.04		1	715.5 - AAC - SIN
567	MARTINEZ	SHELL OIL #2	115	115		0.06		1	715.5 - AAC - SIN
568	MARTINEZ	SOBRANTE	115	115	SSP	16.4		1	715.5 - AAC - SIN
569	MCCALL	KINGSBURG #1	115	115	T SSP SWP	11.65		1	715.5 - AAC - SIN
570	MCCALL	KINGSBURG #2	115	115	SSP	11.57		1	715.5 - AAC - SIN
571	MCCALL	MALAGA	115	115	T SSP SWP	10.96		1	715.5 - AAC - SIN
572	MCCALL	REEDLEY	115	115	T SSP OTHERS S	15.2		1	1113 - AAC - SING
573	MCCALL	SANGER #1	115	115	T SSP	9.23		1	477 - ACSS - SING
574	MCCALL	SANGER #2	115	115		9.2		1	477 - ACSS - SING
575	MCCALL	SANGER #3	115	115	SWP	8.3		1	1113 - AAC - SING
576	MCCALL	WEST FRESNO #2	115	115	T SSP	19.61		1	477 - ACSS - SING
577	MCKEE	PIERCY	115	115	T	7.75		1	477 - ACSS - SING
578	MELONES	CURTIS	115	115	SWP SSP OTHERS	14.8		1	715.5 - AAC - SIN
579	MELONES	RACETRACK	115	115	SWP SSP	10.2		1	397.5 - AAC - SIN
580	MENDOCINO	REDBUD	115	115		34.83		1	397.5 - ACSR - SI
581	MENDOCINO	UKIAH	115	115	T SSP OTHERS S	9.83		1	715.5 - AAC - SIN
582	MENDOTA	NORTH STAR SOLAR	115	115		0.03		1	397.5 - AAC - SIN
583	MESA	DIVIDE #1	115	115	T SSP	14.71		1	715.5 - AAC - SIN
584	MESA	DIVIDE #2	115	115		14.72		1	715.5 - AAC - SIN
585	MESA	SANTA MARIA	115	115	T SSP SWP	4.36		1	715.5 - AAC - SIN
586	MESA	SISQUOC	115	115	T SSP SWP	17.6		1	715.5 - AAC - SIN
587	METCALF	SALINAS #1	115	115	T	1.94		1	2/0 - CU - SINGLE
588	METCALF	SALINAS #2 (12KV)	115	115		6.8		1	2/0 - CU - SINGLE
589	METCALF	COYOTE PUMPING PLANT	115	115	SWP SSP	7.86		1	397.5 - AAC - SIN
590	METCALF	EDENVALE #1	115	115	T SSP	5.73		1	715.5 - AAC - SIN
591	METCALF	EDENVALE #2	115	115	T	5.6		1	715.5 - AAC - SIN
592	METCALF	EL PATIO #1	115	115	T SSP	14.39		1	477 - ACSS - SING
593	METCALF	EL PATIO #2	115	115		14.4		1	477 - ACSS - SING
594	METCALF	EVERGREEN #1	115	115	T	10.63		1	715.5 - AAC - SIN
595	METCALF	GREEN VALLEY	115	115	T SSP OTHERS S	25.28		1	715.5 - AAC - SIN
596	METCALF	MORGAN HILL	115	115	SSP	9.72		1	715.5 - AAC - SIN
597	METCALF	HICKS 1 & 2	115	115	T SSP	6.62		1	1 - UNKNOWN - UNK
598	MIDSET TAP		115	115	SWP	0.72		1	715.5 - AAC - SIN
599	MIDSUN	MIDWAY	115	115	SWP SSP OTHERS	18.86		1	715.5 - AAC - SIN
600	MIDWAY	RENFRO-TUPMAN	115	115	T SSP OTHERS	22.6		1	1113 - AAC - SING
601	MIDWAY	TUPMAN-RIO BRAVO-RENFRO	115	115	T SSP OTHERS S	26.59		1	266.8 - AAC - SIN
602	MIDWAY	SHAFTER	115	115	T SSP SWP	13.63		1	715.5 - AAC - SIN
603	MIDWAY	TAFT	115	115	T SSP OTHERS	19.33		1	715.5 - AAC - SIN
604	MIDWAY	TEMBLOR	115	115	T SSP OTHERS S	14.53		1	336.4 - AAC - SIN
605	MIDWAY	SANTA MARIA	115	115	T OTHERS SWP	46.72		1
606	MILLBRAE	SAN MATEO #1	115	115	T SSP	4.71		1	477 - ACSS - SING
607	MILLER #1 TAP		115	115	T SSP SWP	21.26		1	1113 - AAC - SING
608	MILLER #2 TAP		115	115	SWP SSP OTHERS	12.32		1	4/0 - AAC - SINGL
609	MILPITAS	SWIFT	115	115	T SSP	8.86		1	477 - ACSS - SING
610	MISSION POWER TAP		115	115	SWP SSP	1.94		1	397.5 - ACSR - SI
611	MISSOURI FLAT	GOLD HILL #1	115	115	T SSP	19.73		1	715.5 - AAC - SIN
612	MISSOURI FLAT	GOLD HILL #2	115	115	T	19.69		1	715.5 - AAC - SIN
613	MOFFETT FIELD TAP		115	115	SWP	0.16		1	4/0 - AAC - SINGL
614	MONTA VISTA	WOLFE	115	115	T SSP	2.72		1	477 - ACSS - SING
615	MONTA VISTA	WOLFE	115	115	N/A	1.12		1	CU
616	MONTAGUE	TRIMBLE	115	115	SSP	2.07		1	795 - ACSS - SING
617	MONTICELLO PH TAP		115	115	SWP SSP	0.62		1	4/0 - AAC - SINGL
618	MORAGA	CLAREMONT #1	115	115	T OTHERS	5.28		1	715.5 - AAC - SIN
619	MORAGA	CLAREMONT #2	115	115	T OTHERS	5.3		1	715.5 - AAC - SIN
620	MORAGA	OAKLAND #1	115	115	T SSP	5.04		1	3/0 - CU - SINGLE
621	MORAGA	OAKLAND #2	115	115		5.04		1	3/0 - CU - SINGLE
622	MORAGA	OAKLAND #3	115	115	T SSP SWP	5.05		1	715.5 - AAC - SIN
623	MORAGA	OAKLAND #4	115	115	SWP	5.05		1	715.5 - AAC - SIN
624	MORAGA	OAKLAND J	115	115	SWP	17.67		1	715.5 - AAC - SIN
625	MORAGA	SAN LEANDRO #1	115	115	T SSP	11.14		1	715.5 - AAC - SIN
626	MORAGA	SAN LEANDRO #2	115	115	SWP	11.01		1	715.5 - AAC - SIN
627	MORAGA	SAN LEANDRO #3	115	115	T SSP	11		1	715.5 - AAC - SIN
628	MORAGA	LAKEWOOD	115	115	T SSP	15.11		1	954 - ACSR - SING
629	MORGAN HILL	LLAGAS	115	115	T SWP	10.84		1	715.5 - AAC - SIN
630	MORRO BAY	SAN LUIS OBISPO #1	115	115	T	16.01		1	715.5 - AAC - SIN
631	MORRO BAY	SAN LUIS OBISPO #2	115	115	T	16.02		1	715.5 - AAC - SIN
632	MOSS LANDING	DEL MONTE #1	115	115	T SSP	23.35		1	715.5 - AAC - SIN
633	MOSS LANDING	DEL MONTE #2	115	115	T SSP	23.38		1	715.5 - AAC - SIN
634	MOSS LANDING	GREEN VALLEY #1	115	115	T	14.32		1	477 - ACSS - SING
635	MOSS LANDING	GREEN VALLEY #2	115	115	SWP	14.46		1	477 - ACSS - SING
636	MOSS LANDING	SALINAS #1	115	115	T	12		1	477 - ACSS - SING
637	MOSS LANDING	SALINAS #2	115	115	SSP	12.11		1	477 - ACSS - SING
638	MOSS LANDING	CRAZY HORSE CANYON #1	115	115	T	10.62		1	477 - ACSS - SING
639	MOSS LANDING	CRAZY HORSE CANYON #2	115	115		10.61		1	477 - ACSS - SING
640	MTN VIEW	MONTA VISTA	115	115		4.8		1	715.5 - AAC - SIN
641	NEWARK	AMES #1	115	115	T SSP	8.3		1	715.5 - AAC - SIN
642	NEWARK	AMES #2	115	115		8.28		1	715.5 - AAC - SIN
643	NEWARK	AMES #3	115	115	T SWP	8.28		1	715.5 - AAC - SIN
644	NEWARK	APPLIED MATERIALS	115	115	T SSP OTHERS S	11.37		1	477 - ACSS - SING
645	NEWARK	DIXON LANDING	115	115	SSP	4.69		1	477 - ACSS - SING
646	NEWARK	FREMONT #1	115	115	T SSP	3.71		1	477 - ACSS - SING
647	NEWARK	FREMONT #2	115	115	SSP	3.75		1	477 - ACSS - SING
648	NEWARK	JARVIS #1	115	115	T SSP	14.25		1	715.5 - AAC - SIN
649	NEWARK	JARVIS #2	115	115	T SSP	14.48		1	715.5 - AAC - SIN
650	NEWARK	KIFER	115	115	T SSP	10.61		1	715.5 - AAC - SIN
651	NEWARK	LAWRENCE	115	115	T OTHERS	10.25		1	477 - ACSS - SING
652	NEWARK	LAWRENCE LAB	115	115	T	12.21		1	3/0 - CU - SINGLE
653	NEWARK	MILPITAS #1	115	115	T SSP	8.48		1	477 - ACSS - SING
654	NEWARK	MILPITAS #2	115	115	SWP SSP	10.3		1	1113 - AAC - SING
655	NEWARK	NUMMI	115	115	T SSP SWP	4.94		1	4/0 - CU - SINGLE
656	NEWARK	NORTHERN RECEIVING STATION	115	115	T SSP	8.76		1	715.5 - AAC - SIN
657	NEWARK	NORTHERN RECEIVING STATION	115	115	T SSP	8.67		1	715.5 - AAC - SIN
658	NEWARK	TRIMBLE	115	115	T SSP	12.36		1	715.5 - AAC - SIN
659	NEWARK	AMES DISTRIBUTION	115	115	SWP SSP	8.25		1	715.5 - AAC - SIN
660	NEWARK	APPLIED MATERIALS	115	115	N/A	0.74		1	2500 KCMIL - CU
661	NORTECH	NORTHERN RECEIVING STATION	115	115	SSP	2.21		1	795 - ACSS - SING
662	NORTH TOWER	MARTINEZ JCT #1 (21KV)	115	115	T	2.61		1	1 - UNKNOWN - UNK
663	NORTHERN RECEIVING STATION	SCOTT #1	115	115	T SSP	2.08		1	477 - ACCR - SING
664	NORTHERN RECEIVING STATION	SCOTT #2	115	115	SSP	1.98		1	477 - ACSS - SING
665	NOTRE DAME	BUTTE	115	115	SWP SSP	2.02		1	715.5 - AAC - SIN
666	OAKHURST TAP		115	115	SWP SSP OTHERS	18.16		1	4/0 - ACSR - SING
667	OAKLAND C	MARITIME	115	115	SWP SSP	2.36		1	4/0 - ACSR - SING
668	OAKLAND C	TURBINES	115	115	SWP SSP	0.19		1	715.5 - AAC - SIN
669	OAKLAND J	GRANT	115	115	T SSP	14.81		1	715.5 - AAC - PAR
670	OCEANO	CALLENDER SW STA	115	115	SWP	4.22		1	715.5 - AAC - SIN
671	OLEUM	G #1	115	115	T SSP	11.29		1	715.5 - AAC - SIN
672	OLEUM	G #2	115	115	OTHERS	11.3		1	715.5 - AAC - SIN
673	OLEUM	MARTINEZ	115	115	T SSP SWP	10.5		1	715.5 - AAC - SIN
674	OLEUM	NORTH TOWER-CHRISTIE	115	115	T SSP OTHERS S	8.33		1	715.5 - AAC - SIN
675	OLEUM	UNOCAL #1	115	115		0.01		1	250 - CU - SINGLE
676	OLEUM	UNOCAL #2	115	115	SWP	0.05		1	715.5 - AAC - SIN
677	OLIVE SW STA	SMYRNA	115	115	T SSP	22.09		1	1113 - AAC - SING
678	OWENS BROCKWAY TAP		115	115	SWP SSP	1.09		1	4/0 - AAC - SINGL
679	OWENS ILLINOIS TAP		115	115	SWP	0.68		1	4/0 - AAC - SINGL
680	OXFORD TAP		115	115	SWP	3.87		1	4/0 - AAC - SINGL
681	P	X #2	115	115	T SSP	0.28		1
682	P	X #1	115	115	N/A	4.01		1	1000 KCMIL - CU
683	P	X #2 (UNDERGROUND)	115	115	N/A	3.95		1	1000 KCMIL - CU
684	PALERMO	BOGUE	115	115	T SSP	35.74		1	1113 - AAC - SING
685	PALERMO	NICOLAUS	115	115	T SSP OTHERS S	41.18		1	1113 - AAC - SING
686	PALERMO	PEASE	115	115	T	26.53		1	715.5 - AAC - SIN
687	PALERMO	WYANDOTTE	115	115	T SSP SWP	5.3		1	715.5 - AAC - SIN
688	PANOCHE	CAL PEAK-STARWOOD	115	115	SWP	0.1		1	715.5 - AAC - BUN
689	PANOCHE	MENDOTA	115	115	SWP SSP	10.08		1	477 - ACSS - SING
690	PANOCHE	ORO LOMA	115	115	T SSP SWP	18.96		1	477 - ACSS - SING
691	PANOCHE	EXCELSIOR SW STA #1	115	115	T SSP	28.5		1	715.5 - AAC - SIN
692	PANOCHE	EXCELSIOR SW STA #2	115	115	SSP	28.5		1	715.5 - AAC - SIN
693	PARADISE	TABLE MTN	115	115	T SSP OTHERS S	33.73		1	715.5 - AAC - SIN
694	PARADISE	BUTTE	115	115	SSP OTHERS	13.58		1	715.5 - AAC - SIN
695	PARAMOUNT FARMS TAP		115	115	SWP SSP	0.57		1	4/0 - AAC - SINGL
696	PEASE	RIO OSO	115	115	T SSP SWP	27.61		1	336.4 - ACSR - SI
697	PENNGROVE SUB TAP		115	115	SWP	0.81		1	4/0 - AAC - SINGL
698	PEORIA TAP		115	115	SWP	0.85		1	397.5 - ACSR - SI
699	PIERCY	METCALF	115	115	T	4.72		1	477 - ACSS - SING
700	PITTSBURG	CLAYTON #1	115	115	T SSP	16.82		1	715.5 - AAC - PAR
701	PITTSBURG	CLAYTON #3	115	115	T SSP	8.41		1	715.5 - AAC - BUN
702	PITTSBURG	CLAYTON #4	115	115	T SSP	8.32		1	715.5 - AAC - BUN
703	PITTSBURG	COLUMBIA STEEL	115	115	T SSP	9.23		1	715.5 - AAC - SIN
704	PITTSBURG	LOS MEDANOS #1	115	115	SSP	0.54		1	2300 - AAC - BUND
705	PITTSBURG	LOS MEDANOS #2	115	115	SSP	0.54		1	2300 - AAC - BUND
706	PITTSBURG	KIRKER-COLUMBIA STEEL	115	115	SSP	9.26		1	715.5 - AAC - SIN
707	PITTSBURG	MARTINEZ #1	115	115	T SSP	17.22		1	477 - ACSS - SING
708	PITTSBURG	MARTINEZ #2	115	115		15.83		1	477 - ACSS - SING
709	PITTSBURG	LOS MEDANOS #1	115	115	N/A	0.88		1	3000 KCMIL - CU
710	PITTSBURG	LOS MEDANOS #2	115	115	N/A	0.89		1	3000 KCMIL - CU
711	PLACER	GOLD HILL #1	115	115	T SSP	20.67		1	2300 - AAC - SING
712	PLACER	GOLD HILL #2	115	115	SSP	20.67		1	2300 - AAC - SING
713	POINT PINOLE TAP		115	115	SWP SSP	1.3		1	715.5 - AAC - SIN
714	POST OFFICE TAP		115	115	SWP SSP	0.75		1	4/0 - AAC - SINGL
715	PSE MCKITTRICK TAP		115	115	SWP	5.21		1	715.5 - AAC - SIN
716	QUEBEC TAP		115	115	SWP	4.35		1	4/0 - AAC - SINGL
717	RACETRACK TAP		115	115	SWP SSP	3.55		1	397.5 - AAC - SIN
718	RAINBOW TAP		115	115	SSP	2.59		1	715.5 - AAC - SIN
719	RANCHERS COTTON TAP		115	115	SWP SSP	2.1		1	397.5 - AAC - SIN
720	RAVENSWOOD	AMES #1	115	115	T	7.07		1	477 - ACSS - SING
721	RAVENSWOOD	AMES #2	115	115		7.09		1	477 - ACSS - SING
722	RAVENSWOOD	BAIR #1	115	115	T	7.43		1	715.5 - AAC - SIN
723	RAVENSWOOD	BAIR #2	115	115	T SSP	11.29		1	715.5 - AAC - SIN
724	RAVENSWOOD	COOLEY LANDING #1	115	115	T	1.62		1	715.5 - AAC - SIN
725	RAVENSWOOD	COOLEY LANDING #2	115	115		1.62		1	715.5 - AAC - SIN
726	RAVENSWOOD	PALO ALTO #1	115	115	T SSP SWP	4.28		1	715.5 - AAC - SIN
727	RAVENSWOOD	PALO ALTO #2	115	115	SWP SSP	4.26		1	715.5 - AAC - SIN
728	RAVENSWOOD	SAN MATEO	115	115	T	12.04		1	715.5 - AAC - SIN
729	RINCON #1 TAP		115	115	T SSP	0.57		1	397.5 - AAC - SIN
730	RINCON #2 TAP		115	115	SSP	0.55		1	397.5 - AAC - SIN
731	RIO BRAVO	KERN OIL	115	115	SWP SSP	7.28		1	266.8 - AAC - SIN
732	RIO BRAVO (FRESNO) TAP		115	115	SWP OTHERS	0.32		1	4/0 - AAC - SINGL
733	RIO BRAVO (ROCKLIN) TAP		115	115	SWP	0.4		1	4/0 - AAC - SINGL
734	RIO BRAVO TOMATO TAP		115	115	SWP SSP OTHERS	0.43		1	1113 - AAC - SING
735	RIO OSO	LINCOLN	115	115	SWP SSP OTHERS	11.02		1	1113 - AAC - SING
736	RIO OSO	NICOLAUS	115	115	T	5.39		1	1113 - AAC - SING
737	RIO OSO	WEST SACRAMENTO	115	115	T SSP OTHERS S	43.56		1	336.4 - ACSR - SI
738	RIO OSO	WOODLAND #1	115	115	T SSP OTHERS S	45.25		1	715.5 - AAC - SIN
739	RIO OSO	WOODLAND #2	115	115	T SSP SWP	53.37		1	715.5 - AAC - SIN
740	RIPON TAP		115	115	SWP	4.64		1	397.5 - AAC - SIN
741	RIVERBANK JCT SW STA	MANTECA	115	115	SSP	17.65		1	4/0 - ACSR - SING
742	SAFEWAY TAP		115	115	SWP SSP	0.68		1	477 - ACSS - SING
743	SALT SPRINGS	TIGER CREEK	115	115	T SSP	16.48		1	4/0 - CU - SINGLE
744	SAN BENITO	HOLLISTER	115	115	SSP	8.31		1	477 - ACSS - SING
745	SAN FRANCISCO #2		115	115		3.15		1	1 - UNKNOWN - UNK
746	SAN JOAQUIN COGEN TAP		115	115	SWP	0.04		1	715.5 - AAC - SIN
747	SAN JOSE A	SAN JOSE B	115	115	SSP	1.15		1	1113 - AAC - SING
748	SAN JOSE B	STONE-EVERGREEN	115	115	SWP SSP	8.56		1	1113 - AAC - SING
749	SAN LEANDRO	OAKLND J #1	115	115	T SSP	6.7		1	715.5 - AAC - SIN
750	SAN LUIS #3 TAP		115	115	T SSP SWP	16.11		1	397.5 - ACSR - SI
751	SAN LUIS #5 TAP		115	115	SWP SSP	1.88		1	397.5 - ACSR - SI
752	SAN LUIS OBISPO	OCEANO	115	115	T SSP OTHERS S	19.9		1	715.5 - AAC - SIN
753	SAN LUIS OBISPO	SANTA MARIA	115	115	SWP SSP	25.96		1	336.4 - AAC - SIN
754	SAN MATEO	BAY MEADOWS #1	115	115	T	4.3		1	4/0 - CU - SINGLE
755	SAN MATEO	BAY MEADOWS #2	115	115	T	4.26		1	4/0 - CU - SINGLE
756	SAN MATEO	BELMONT	115	115	T SSP	7.2		1	715.5 - AAC - SIN
757	SAN MATEO	MARTIN #3	115	115	T SSP SWP	11.55		1	477 - ACSS - SING
758	SAN MATEO	MARTIN #6	115	115	SSP	11.68		1	477 - ACSS - SING
759	SAN MATEO	MARTIN #4	115	115	SWP SSP	11.64		1	477 - ACSS - SING
760	SAN MATEO	MARTIN #4	115	115	N/A	0.21		1	3000 KCMIL - ALUM
761	SAN MATEO	MARTIN #3	115	115	N/A	0.21		1	3000 KCMIL - ALUM
762	SAN MATEO	MARTIN #6	115	115	N/A	0.23		1	3000 KCMIL - ALUM
763	SAN PABLO #1 TAP		115	115	SSP	0.44		1	715.5 - AAC - SIN
764	SAN PABLO #2 TAP		115	115	T SSP	0.45		1	715.5 - AAC - SIN
765	SANDBAR TAP		115	115	OTHERS	0.09		1	397.5 - ACSR - SI
766	SANGER	MALAGA	115	115	SWP SSP	8.82		1	715.5 - AAC - SIN
767	SANGER	CALIFORNIA AVE	115	115	SWP SSP	9.33		1	1113 - AAC - SING
768	SANGER	REEDLEY	115	115	SWP SSP	20.42		1	1113 - AAC - SING
769	SANGER COGEN TAP		115	115	SWP SSP	0.83		1	715.5 - AAC - SIN
770	SANTA MARIA	SISQUOC	115	115	SWP SSP	10.57		1	715.5 - AAC - SIN
771	SANTA MARIA COGEN TAP		115	115	SWP	0.24		1	397.5 - AAC - SIN
772	SANTA PAULA	MILLBRAE	115	115	SSP	0.09		1	397.5 - AAC - SIN
773	SANTA ROSA	CORONA	115	115	SWP SSP	14.39		1	477 - ACSS - SING
774	SANTA YNEZ TAP		115	115	SWP SSP	4.06		1	397.5 - AAC - SIN
775	SARGENT SW STA	HOLLISTER	115	115	SWP OTHERS	1.54		1	1 - UNKNOWN - UNK
776	SCHULTE SW STA	LAMMERS	115	115	T SSP	0.69		1	954 - ACSS - SING
777	SCHULTE SW STA	KASSON-MANTECA	115	115	T SSP SWP	16.56		1	477 - ACSS - SING
778	SEMITROPIC	CHARCA	115	115	SWP SSP	6.91		1	397.5 - AAC - SIN
779	SEMITROPIC	MIDWAY #1	115	115	T SSP SWP	14.1		1	1113 - AAC - SING
780	SEMITROPIC	MIDWAY #2	115	115	T SSP OTHERS S	20.11		1	715.5 - AAC - SIN
781	SERRAMONTE TAP		115	115	T SSP	2.55		1	397.5 - AAC - SIN
782	SF AIRPORT	SAN MATEO	115	115	T SSP	6.09		1	477 - ACSS - SING
783	SHAFTER	RIO BRAVO	115	115	SWP SSP	8.31		1	715.5 - AAC - SIN
784	SHARON PRISON TAP		115	115	SWP SSP	2.57		1	4/0 - AAC - SINGL
785	SHREDDER TAP		115	115	T SSP SWP	1.38		1	2/0 - CU - SINGLE
786	SIERRA #1		115	115	T	5.47		1	4/0 - CU - SINGLE
787	SIERRA #2		115	115		4.86		1	4/0 - CU - SINGLE
788	SIERRA (PSE) TAP		115	115	SWP SSP	1.81		1	715.5 - AAC - SIN
789	SIERRA PACIFIC IND TAP		115	115	SWP	0.06		1	4/0 - AAC - SINGL
790	SILVERADO	FULTON JCT	115	115	T SWP	26.16		1	4/0 - CU - SINGLE
791	SISQUOC	GAREY	115	115	SWP SSP	5.02		1	397.5 - AAC - SIN
792	SISQUOC	SANTA YNEZ SW STA	115	115	SWP SSP OTHERS	22.12		1	715.5 - AAC - SIN
793	SKAGGS ISLAND #1 TAP		115	115	T	0.59		1	4/0 - AAC - SINGL
794	SKAGGS ISLAND #2 TAP		115	115	T	0.6		1	4/0 - AAC - SINGL
795	SLY CREEK TAP		115	115	SWP SSP OTHERS	5.34		1	4/0 - ACSR - SING
796	SMYRNA	SEMITROPIC-MIDWAY	115	115	T SSP OTHERS S	44.65		1	266.8 - AAC - SIN
797	SOBRANTE	G #1	115	115	T SSP SWP	5.34		1	715.5 - AAC - SIN
798	SOBRANTE	G #2	115	115	SSP	5.39		1	715.5 - AAC - SIN
799	SOBRANTE	GRIZZLY-CLAREMONT #1	115	115	T SSP SWP	19.58		1	715.5 - AAC - SIN
800	SOBRANTE	MORAGA	115	115	T SSP SWP	5.68		1	1113 - AAC - SING
801	SOBRANTE	GRIZZLY-CLAREMONT #2	115	115	T SSP SWP	19.3		1	715.5 - AAC - SIN
802	SOBRANTE	R #1	115	115	T SSP	5.54		1	715.5 - AAC - SIN
803	SOBRANTE	R #2	115	115		5.53		1	715.5 - AAC - SIN
804	SOBRANTE	STANDARD OIL SW STA #2	115	115	SSP	18.89		1	715.5 - AAC - SIN
805	SOBRANTE	STANDARD OIL SW STA #1	115	115	T SSP OTHERS	18.89		1	715.5 - AAC - SIN
806	SOBRANTE	R #1	115	115	N/A	4.16		1	3000 KCMIL - ALUM
807	SOBRANTE	R #2	115	115	N/A	4.11		1
808	SONOMA	PUEBLO	115	115	SWP SSP	18.48		1	715.5 - AAC - SIN
809	SPRING GAP TAP		115	115	T OTHERS SWP	1.64		1	397.5 - ACSR - SI
810	STANISLAUS	MANTECA #2	115	115	T SSP SWP	53.95		1	715.5 - AAC - SIN
811	STANISLAUS	MELONES SW STA-MANTECA #1	115	115	T SSP SWP	61.15		1	715.5 - AAC - SIN
812	STANISLAUS	MELONES SW STA-RIVERBANK JC	115	115	T SSP	43.8		1	715.5 - AAC - SIN
813	STANISLAUS	NEWARK #1 (12KV)	115	115	T SSP	15.05		1	2/0 - CU - SINGLE
814	STANISLAUS	NEWARK #2 (12KV)	115	115	T OTHERS	18.17		1	2/0 - CU - SINGLE
815	STELLING	MONTA VISTA	115	115	T SSP	1.61		1	477 - ACSS - SING
816	STELLING	WOLFE	115	115	T SSP	1.46		1	477 - ACSS - SING
817	STELLING	MONTA VISTA	115	115	N/A	1.14		1	CU
818	STOCKTON A	LOCKEFORD-BELLOTA #1	115	115	T SSP OTHERS S	34.77		1	715.5 - AAC - SIN
819	STOCKTON A	LOCKEFORD-BELLOTA #2	115	115	T SSP SWP	34.49		1	715.5 - AAC - SIN
820	STONE	EVERGREEN-METCALF	115	115	SWP SSP	12.86		1	715.5 - AAC - SIN
821	STONY POINT TAP		115	115	SWP SSP	3.08		1	397.5 - AAC - SIN
822	SURF TAP		115	115	SWP SSP	11.38		1	397.5 - AAC - SIN
823	SWIFT	METCALF	115	115	T	8.93		1	477 - ACSS - SING
824	SYCAMORE CREEK	NOTRE DAME-TABLE MTN	115	115	SWP SSP	20.33		1	715.5 - AAC - SIN
825	TABLE MTN	BUTTE #1	115	115	T SSP SWP	19.54		1	715.5 - AAC - SIN
826	TABLE MTN	BUTTE #2	115	115	T SSP	15.82		1	715.5 - AAC - SIN
827	TAFT	CHALK CLIFF	115	115	SWP SSP OTHERS	7.18		1	715.5 - AAC - SIN
828	TEICHERT TAP		115	115	SWP SSP OTHERS	2.11		1	4/0 - AAC - SINGL
829	TEMBLOR	KERNRIDGE	115	115	SWP SSP	4.78		1	715.5 - AAC - SIN
830	TEMBLOR	SAN LUIS OBISPO	115	115	T SSP SWP	57.79		1	715.5 - AAC - SIN
831	TESLA	SCHULTE SW STA #2	115	115	T SSP	7.34		1	715.5 - AAC - SIN
832	TESLA	SCHULTE SW STA #1	115	115	T SSP OTHERS S	7.39		1	715.5 - AAC - SIN
833	TESLA	SALADO #1	115	115	T SSP OTHERS S	32.07		1	715.5 - AAC - SIN
834	TESLA	SALADO-MANTECA	115	115	T SSP OTHERS S	53.96		1	715.5 - AAC - SIN
835	TESLA	STOCKTON COGEN JCT	115	115	T SSP SWP	44.47		1	715.5 - AAC - SIN
836	TESLA	TRACY	115	115	T SSP SWP	25.23		1	1113 - AAC - SING
837	THERMAL ENERGY TAP		115	115	SWP SSP	0.74		1	715.5 - AAC - SIN
838	TRIMBLE	SAN JOSE B	115	115	SSP	2.53		1	715.5 - AAC - SIN
839	TRIMBLE	SAN JOSE B	115	115	N/A	1.11		1
840	TRINITY	COTTONWOOD	115	115	T SSP OTHERS S	45.97		1	336.4 - ACAR - SI
841	TULLOCH TAP		115	115	SWP OTHERS	0.31		1	397.5 - AAC - SIN
842	TUPMAN-NORCO TAP		115	115	SWP SSP	6.67		1	715.5 - AAC - SIN
843	UC DAVIS #1 TAP		115	115	SWP SSP	1.64		1	715.5 - AAC - SIN
844	UC DAVIS #2 TAP		115	115	SWP SSP	1.61		1	715.5 - AAC - SIN
845	UKIAH	HOPLAND-CLOVERDALE	115	115	SWP SSP OTHERS	31.17		1	715.5 - AAC - SIN
846	ULTRAPOWER (OGLE) TAP		115	115	SWP SSP OTHERS	2.45		1	1113 - AAC - SING
847	UNION OIL TAP		115	115	SWP SSP	0.5		1	4/0 - AAC - SINGL
848	UNITED COGEN INC TAP		115	115	SWP SSP	0.68		1	397.5 - AAC - SIN
849	UNIVERSITY COGEN TAP		115	115	SWP	0.22		1	715.5 - AAC - SIN
850	VACA	SUISUN	115	115	T SSP SWP	23.06		1	715.5 - AAC - SIN
851	VACA	SUISUN-JAMESON	115	115	T SSP SWP	25.46		1	715.5 - AAC - SIN
852	VACA	VACAVILLE-CORDELIA	115	115	T SWP	22.04		1	715.5 - AAC - SIN
853	VACA	VACAVILLE-JAMESON-NORTH TOW	115	115	T SSP OTHERS S	36.18		1	715.5 - AAC - SIN
854	VALLEY CHILDRENS HOSPITAL T		115	115		0.03		1	4/0 - AAC - SINGL
855	VALLEY VIEW #1 TAP		115	115	SSP	0.96		1	715.5 - AAC - SIN
856	VALLEY VIEW #2 TAP		115	115	SSP	0.97		1	715.5 - AAC - SIN
857	VEDDER TAP		115	115	SWP SSP OTHERS	11.09		1	3/0 - AAC - SINGL
858	VIERRA	TRACY-KASSON	115	115	T SSP SWP	10.49		1	715.5 - AAC - SIN
859	WASCO PRISON TAP		115	115	SWP	0.54		1	4/0 - AAC - SINGL
860	WAUKENA SW STA	CORCORAN	115	115		2.37		1	1113 - AAC - SING
861	WEST FRESNO	CALIFORNIA AVE	115	115	T SWP	4.9		1	715.5 - AAC - SIN
862	WEST SACRAMENTO	BRIGHTON	115	115	T SSP OTHERS	13.97		1	477 - ACSS - SING
863	WEST SACRAMENTO	DAVIS	115	115	SWP SSP OTHERS	12.14		1	715.5 - AAC - SIN
864	WESTLANDS #1 RA PUMPING PLA		115	115	SWP SSP	1.05		1	4/0 - AAC - SINGL
865	WESTLANDS #18 RA TAP		115	115	SWP	3.52		1	4/0 - AAC - SINGL
866	WESTPARK	MAGUNDEN	115	115	T SSP SWP	12.29		1	715.5 - AAC - SIN
867	WHEELER RIDGE	ADOBE SW STA	115	115	SWP SSP	1.34		1	715.5 - AAC - SIN
868	WHISMAN	MONTA VISTA	115	115	T	5.97		1	715.5 - AAC - SIN
869	WHISMAN	MTN VIEW	115	115	T SWP	3.54		1	715.5 - AAC - SIN
870	WILSON	DAIRYLAND (12KV)	115	115	SWP	11.37		1	266.8 - AAC - SIN
871	WILSON	ATWATER #2	115	115	T SSP	15.41		1	715.5 - AAC - SIN
872	WILSON	LE GRAND	115	115	T SSP OTHERS S	14.04		1	715.5 - AAC - SIN
873	WILSON	MERCED #1	115	115	T SSP SWP	5.58		1	715.5 - AAC - SIN
874	WILSON	MERCED #2	115	115	T SSP SWP	6.2		1	266.8 - AAC - SIN
875	WILSON	ORO LOMA	115	115	T SSP SWP	43.56		1	715.5 - AAC - SIN
876	WITCO (REFINERY) TAP		115	115	SWP	0.03		1	4/0 - AAC - SINGL
877	WOODLAND	DAVIS	115	115	SWP SSP	11.71		1	715.5 - AAC - SIN
878	WOODLAND BIOMASS TAP		115	115	SWP	0.87		1	4/0 - AAC - SINGL
879	WOODLEAF	PALERMO	115	115	T SSP OTHERS S	19.62		1	715.5 - AAC - SIN
880	WOODWARD	SHEPHERD	115	115	SWP SSP	4.84		1	2300 - AAC - SING
881	X	Y #1	115	115	N/A	0.57		1	1250 KCMIL - CU
882	ZAMORA TAP		115	115	SWP SSP	1.92		1	397.5 - AAC - SIN
883	ZANKER #1 TAP		115	115	SWP SSP	0.6		1	715.5 - AAC - SIN
884	ZANKER #2 TAP		115	115	SWP SSP	0.72		1	4/0 - AAC - SINGL
885	AERA ENERGY TAP		70	60	SWP SSP	0.35		1	397.5 - ALUM - SI
886	ANTELOPE TAP		70	70	SWP SSP	4.33		1	4/0 - AAC - SINGL
887	ARBURUA TAP		70	70	SWP	3.57		1	2 - ACSR - SINGLE
888	ARCO	CARNERAS	70	70	SWP SSP	17.97		1	715.5 - AAC - SIN
889	ARCO	CHOLAME	70	70	SWP SSP	26.74		1	397.5 - AAC - SIN
890	ARCO	POLONIO PASS PP	70	70	SWP SSP	21.27		1	715.5 - AAC - SIN
891	ARCO	TULARE LAKE	70	70	SWP SSP	16.11		1	3/0 - AAC - SINGL
892	ARCO	TWISSELMAN	70	70	SWP SSP	6.52		1	715.5 - AAC - SIN
893	ARMSTRONG TAP		70	70	SWP	0.44		1	4/0 - AAC - SINGL
894	ATASCADERO	CAYUCOS	70	70	SWP SSP OTHERS	11.8		1	3/0 - AAC - SINGL
895	ATASCADERO	SAN LUIS OBISPO	70	70	T SSP OTHERS	15.47		1	715.5 - AAC - SIN
896	AUBERRY TAP		70	70	SWP SSP	2.27		1	1/0 - ACSR - SING
897	AVENAL TAP		70	70	SWP SSP OTHERS	5.4		1	397.5 - AAC - SIN
898	BADGER HILL TAP		70	70	SWP	1.56		1	1/0 - ACSR - SING
899	BERRENDA A TAP		70	70	SWP	2.25		1	4/0 - AAC - SINGL
900	BERRENDA C TAP		70	70	SWP	1.87		1	4/0 - AAC - SINGL
901	BIOLA	GLASS-MADERA	70	70	SWP SSP OTHERS	18.84		1	715.5 - AAC - SIN
902	BONITA TAP		70	70	SWP SSP	3.04		1	2 - CU - SINGLE
903	BORDEN	COPPERMINE	70	70	SWP SSP OTHERS	19.95		1	4/0 - CU - SINGLE
904	BORDEN	GLASS	70	70	SWP SSP	6.62		1	715.5 - AAC - SIN
905	BORDEN	MADERA #2	70	70	SWP SSP OTHERS	5.81		1	715.5 - AAC - SIN
906	BORDEN	MADERA #1	70	70	SWP SSP	4.91		1	715.5 - AAC - SIN
907	BORDEN	GLASS; XLPE; 70 KV	70	70	N/A	0.39		1	1750 KCMIL - ALUM
908	BOSWELL TAP		70	70	SWP	1.39		1	4/0 - ACSR - SING
909	BRICEBURG JCT-MARIPOSA TAP		70	70	SWP SSP	7.78		1	715.5 - AAC - SIN
910	CADET TAP		70	70	SWP	0.12		1	397.5 - AAC - SIN
911	CALIFORNIA AVE	KEARNEY	70	70	SWP	3.2		1	715.5 - AAC - SIN
912	CAMDEN	KINGSBURG	70	70	SWP SSP	14.91		1	266.8 - AAC - SIN
913	CANANDAIGUA WINERY TAP		70	70	SWP	0.29		1	4/0 - AAC - SINGL
914	CARNATION TAP		70	70	SWP SSP	0.61		1	4/0 - AAC - SINGL
915	CARNERAS	TAFT	70	70	SWP SSP OTHERS	34.92		1	3/0 - AAC - SINGL
916	CARUTHERS	LEMOORE NAS-CAMDEN	70	70	SWP SSP	25.17		1	3/0 - AAC - SINGL
917	CASTAIC TAP		70	70	SWP	0.02		1	2 - ACSR - SINGLE
918	CAWELO B TAP		70	70	SWP	0.4		1	4/0 - AAC - SINGL
919	CAYUCOS	CAMBRIA	70	70	SWP SSP OTHERS	17.73		1	307.1 - AAC - SIN
920	CELERON TAP		70	70	SWP	0.04		1	4/0 - AAC - SINGL
921	CHEVRON (LOST HILLS) TAP		70	70	SWP	14.75		1	397.5 - AAC - SIN
922	CHEVRON PIPELINE KETTLEMAN		70	70	SWP	1.17		1	4/0 - AAC - SINGL
923	COALINGA #1	COALINGA #2	70	70	SWP SSP OTHERS	8.61		1	1113 - AAC - SING
924	COALINGA #1	SAN MIGUEL	70	70	T SSP SWP	38.01		1	266.8 - ACSR - SI
925	COALINGA COGEN TAP		70	70	SWP SSP	4.91		1	715.5 - AAC - SIN
926	COPPERMINE	TIVY VALLEY	70	70	SWP SSP OTHERS	24.01		1	715.5 - AAC - SIN
927	COPUS	OLD RIVER	70	70	SWP SSP	19.61		1	715.5 - AAC - SIN
928	CORCORAN	ANGIOLA	70	70	SWP SSP	8.96		1	4/0 - CU - SINGLE
929	CORCORAN	GUERNSEY	70	70	SWP SSP	13.57		1	1113 - AAC - SING
930	CRESCENT SW STA	SCULPIN PV	70		SSP	0.04		1	1113 - AAC - SING
931	CRESCENT SW STA	SCHINDLER	70	70	SWP SSP	10.8		1	1113 - AAC - SING
932	CRESCENT SW STA	STROUD	70	70	SWP SSP	3.61		1	1113 - AAC - SING
933	DERRICK TAP		70	70	SWP	0.85		1	397.5 - AAC - SIN
934	DINOSAUR POINT TAP		70	70	SWP SSP OTHERS	2		1	2/0 - CU - SINGLE
935	DINUBA	OROSI	70	70	SWP SSP	9.83		1	715.5 - AAC - SIN
936	DINUBA ENERGY TAP		70	70	SWP	3.16		1	397.5 - AAC - SIN
937	DIVIDE	VANDENBERG #1	70	70	SWP OTHERS	6.64		1	266.8 - AAC - SIN
938	DIVIDE	VANDENBERG #2	70	70	SWP OTHERS	6.57		1	715.5 - AAC - SIN
939	DIVIDE	ZACA-LOMPOC (12KV)	70	70	SWP	10.55		1	397.5 - AAC - SIN
940	DUNLAP TAP		70	70	SWP SSP	16.21		1	715.5 - AAC - SIN
941	EISEN TAP		70	70	SWP	1.86		1	1/0 - ACSR - SING
942	EL PECO TAP		70	70	SWP OTHERS	3.02		1	397.5 - AAC - SIN
943	EMIDIO TAP		70	70	SWP	3.07		1	1/0 - ACSR - SING
944	EXCHEQUER	MARIPOSA	70	70	T SSP SWP	19.3		1	715.5 - AAC - SIN
945	EXCHEQUER	YOSEMITE	70	70	T SSP OTHERS S	34.91		1	3/0 - ACSR - SING
946	FIVE POINTS SW	WHITNEY POINT PV	70	70	SSP	0.06		1	715.5 - AAC - SIN
947	FIVE POINTS SW STA	HURON-GATES	70	70	T SSP SWP	19.78		1	715.5 - AAC - SIN
948	FRESNO COGEN (AGRICO) TAP		70	70	SWP	3.17		1	715.5 - AAC - SIN
949	FRIANT	COPPERMINE	70	70	SWP	8.3		1	715.5 - AAC - SIN
950	FRUITVALE TAP		70	70	T SWP	0.12		1	4/0 - CU - SINGLE
951	GARDNER TAP		70	70	SWP	3.77		1	4/0 - AAC - SINGL
952	GATES	JAYNE SW STA	70	70	SWP SSP	0.68		1	715.5 - AAC - SIN
953	GATES	COALINGA #2	70	70	SWP SSP	17.26		1	715.5 - AAC - SIN
954	GATES	HURON	70	70	T SSP SWP	4.5		1	715.5 - AAC - SIN
955	GATES	TULARE LAKE	70	70	SWP SSP OTHERS	18.34		1	715.5 - AAC - SIN
956	GIFFEN TAP		70	70	SWP SSP	4.95		1	1113 - AAC - SING
957	GRAPEVINE TAP		70	70	SWP	0.14		1	1/0 - ACSR - SING
958	GUERNSEY	HENRIETTA	70	70	SWP SSP	18.44		1	266.8 - AAC - SIN
959	GWF	HENRIETTA	70	70	SWP OTHERS	0.12		1	477 - ACSS - SING
960	GWF HANFORD COGEN TAP		70	70	SWP OTHERS	0.32		1	397.5 - AAC - SIN
961	HAAS	WOODCHUCK	70	70	SWP SSP	6.79		1	4/0 - ACSR - SING
962	HARDWICK TAP		70	70	SWP	2.74		1	266.8 - AAC - SIN
963	HELM	KERMAN	70	70	SWP SSP	13.25		1	715.5 - AAC - SIN
964	HELM	CRESCENT SW STA	70	70	SWP SSP	4.92		1	715.5 - AAC - SIN
965	HELM	STROUD	70	70	SWP	7.43		1	715.5 - AAC - SIN
966	HENRIETTA	LEMOORE	70	70	SWP SSP	9.37		1	715.5 - AAC - SIN
967	HENRIETTA	LEMOORE NAS	70	70	SWP SSP	1.69		1	715.5 - AAC - SIN
968	HENRIETTA	KENT SW STA	70	70	SWP SSP	1.47		1	715.5 - AAC - SIN
969	HERDLYN	TRACY	70	70	SWP	2.06		1	715.5 - AAC - SIN
970	JAYNE SW STA	COALINGA	70	70	SWP SSP	11.81		1	715.5 - AAC - SIN
971	KEARNEY	BIOLA	70	70	SWP SSP	19.13		1	4/0 - CU - SINGLE
972	KEARNEY	BOWLES	70	70	SWP SSP	9.29		1	4/0 - AAC - SINGL
973	KEARNEY	CARUTHERS	70	70	SWP	12.05		1	715.5 - AAC - SIN
974	KEARNEY	KERMAN	70	70	SWP SSP	10.98		1	715.5 - AAC - SIN
975	KEARNEY ALTERNATE TIE		70	70	T SWP	0.3		1	1113 - AAC - SING
976	KEARNEY TIE		70	70	T SWP	0.15		1	1113 - AAC - SING
977	KELLEY TAP		70	70	SWP	2.79		1	1/0 - ACSR - SING
978	KENT SW STA	TULARE LAKE	70	70	T SSP SWP	15.93		1	715.5 - AAC - SIN
979	KERN	FRUITVALE	70	70	T SWP	0.16		1	397.5 - AAC - SIN
980	KERN	KERN OIL-FAMOSO	70	70	T SSP SWP	24.69		1	715.5 - AAC - SIN
981	KERN	MAGUNDEN	70	70	T SSP SWP	20.61		1	715.5 - AAC - SIN
982	KERN	OLD RIVER #1	70	70	T SSP OTHERS S	11.94		1	795 - ACSS - SING
983	KERN	OLD RIVER #2	70	70	SWP SSP	23.07		1	1/0 - CU - SINGLE
984	KERN CANYON	MAGUNDEN-WEEDPATCH	70	70	T SSP SWP	20.65		1	397.5 - AAC - SIN
985	KETTLEMAN HILLS TAP		70	70	SWP SSP	1.02		1	715.5 - AAC - SIN
986	KINGSBURG	LEMOORE	70	70	T SSP OTHERS S	27.49		1	3/0 - CU - SINGLE
987	LAS PERILLAS TAP		70	70	SWP	0.39		1	1/0 - ACSR - SING
988	LEPRINO TAP		70	70	SWP	0.47		1	4/0 - AAC - SINGL
989	LIGHTNER TAP		70	70	SWP	3.06		1	1 - UNKNOWN - UNK
990	LIVINGSTON	LIVINGSTON JCT	70	70	SWP SSP	23.36		1	715.5 - AAC - SIN
991	LOS BANOS	MERCY SPRINGS SW STA	70	70	T SSP SWP	14.73		1	715.5 - AAC - SIN
992	LOS BANOS	LIVINGSTON JCT-CANAL	70	70	SWP SSP	14.29		1	715.5 - AAC - SIN
993	LOS BANOS	O'NEILL PGP	70	70	T SSP OTHERS S	3.88		1	715.5 - AAC - SIN
994	LOS BANOS	PACHECO	70	70	T SSP OTHERS S	20.78		1	715.5 - AAC - SIN
995	LOST HILLS TAP		70	70	SWP SSP	2.89		1	1/0 - ACSR - SING
996	MARICOPA	COPUS	70	70	SWP SSP	7.86		1	715.5 - AAC - SIN
997	MCFARLAND TAP		70	70	SWP	5.99		1	1/0 - CU - SINGLE
998	MCSWAIN TAP		70	70	SWP	1.37		1	4/0 - AAC - SINGL
999	MENDOTA	SAN JOAQUIN-HELM	70	70	SWP SSP	26.96		1	715.5 - AAC - SIN
1000	MENDOTA BIOMASS TAP		70	70	SWP SSP	3.84		1	397.5 - AAC - SIN
1001	MERCED	MERCED FALLS	70	70	T SSP OTHERS S	20.93		1	715.5 - AAC - SIN
1002	MERCED #1		70	70	T SSP SWP	39.88		1	2 - UNKNOWN - SIN
1003	MERCED FALLS	EXCHEQUER	70	70	T SSP	6.29		1	3/0 - CU - SINGLE
1004	MERCY SPRINGS SW STA	CANAL-ORO LOMA	70	70	SWP SSP	23.32		1	715.5 - AAC - SIN
1005	MOCO TAP		70	70	SWP	1.64		1	397.5 - AAC - SIN
1006	MUSTANG TAP		70	70	SWP	0.71		1	4/0 - AAC - SINGL
1007	OIL CITY TAP		70	70	SWP	0.05		1	4/0 - AAC - SINGL
1008	ORO LOMA	CANAL #1	70	70	T SSP SWP	24.56		1	397.5 - AAC - SIN
1009	ORO LOMA	MENDOTA	70	70	SWP SSP	29.58		1	266.8 - AAC - SIN
1010	PASO ROBLES	TEMPLETON	70	70	SWP SSP OTHERS	4.9		1	1113 - AAC - SING
1011	PENN ZIER TAP		70	70	SWP	4.99		1	715.5 - AAC - SIN
1012	PENTLAND TAP		70	70	SWP	0.55		1	4/0 - AAC - SINGL
1013	REEDLEY	DINUBA #1	70	70	SWP SSP	7.7		1	715.5 - AAC - SIN
1014	REEDLEY	OROSI	70	70	SWP SSP	10.89		1	715.5 - AAC - SIN
1015	RESERVE OIL TAP		70	70	SWP	0.58		1	1/0 - ACSR - SING
1016	RIO BRAVO HYDRO		70	70	SWP	0.24		1	4/0 - AAC - SINGL
1017	RIVER ROCK TAP		70	70	SWP	1.21		1	4/0 - AAC - SINGL
1018	ROSE TAP		70	70	SWP	0.31		1	4/0 - AAC - SINGL
1019	SAN BERNARD	TEJON	70	70	SWP SSP	6.96		1	715.5 - AAC - SIN
1020	SAN LUIS OBISPO	CAYUCOS	70	70	SWP SSP OTHERS	23.39		1	715.5 - AAC - SIN
1021	SAN LUIS OBISPO	SANTA MARIA *	70	70	SWP SSP	13.33		1	4/0 - AAC - SINGL
1022	SAN MIGUEL	PASO ROBLES	70	70	SWP	9.92		1	4/0 - AAC - SINGL
1023	SANGER	CALIFORNIA AVE #1	70	70	SWP SSP	9.23		1	266.8 - AAC - SIN
1024	SCHINDLER	COALINGA #2	70	70	SWP SSP	17.26		1	715.5 - AAC - SIN
1025	SCHINDLER	FIVE POINTS SW STA	70	70	SWP SSP	1.7		1	4/0 - CU - SINGLE
1026	SEMITROPIC	WASCO	70	70	T SSP SWP	6.32		1	1113 - AAC - SING
1027	SOLAR TANNEHILL TAP		70	70	SWP	2.65		1	715.5 - AAC - SIN
1028	STONE CORRAL TAP		70	70	SWP SSP	7.56		1	3/0 - AAC - SINGL
1029	SYCAMORE TAP		70	70	SWP SSP	2.04		1	4/0 - AAC - SINGL
1030	TAFT	CUYAMA #1	70	70	SWP SSP	19.25		1	715.5 - AAC - SIN
1031	TAFT	CUYAMA #2	70	70	SWP SSP	18.75		1	2 - ACSR - SINGLE
1032	TAFT	ELK HILLS	70	70	SWP SSP	12.39		1	4 - CU - SINGLE 4
1033	TAFT	MARICOPA	70	70	T SSP OTHERS S	5.98		1	3/0 - CU - SINGLE
1034	TECUYA TAP		70	70	SWP SSP	1.91		1	1/0 - ACSR - SING
1035	TEJON	LEBEC	70	70	SWP SSP	13		1	1/0 - ACSR - SING
1036	TEMPLETON	ATASCADERO	70	70	SWP SSP	8.82		1	1113 - AAC - SING
1037	TEXACO (LOST HILLS) TAP		70	70	SWP	0.01		1	397.5 - AAC - SIN
1038	TEXACO BASIC SCHOOL TAP		70	70	SWP	0.75		1	4/0 - AAC - SINGL
1039	TEXACO BUENA VISTA HILLS TA		70	70	SWP	0.1		1	4/0 - AAC - SINGL
1040	TIVY VALLEY	REEDLEY	70	70	SWP	12.3		1	397.5 - AAC - SIN
1041	TORNADO TAP		70	70	SWP	0.06		1	1/0 - ACSR - SING
1042	TULE	SPRINGVILLE	70	70	SWP SSP OTHERS	15.24		1	1/0 - CU - SINGLE
1043	WASCO	FAMOSO	70	70	SWP SSP	7.13		1	715.5 - AAC - SIN
1044	WEEDPATCH	SAN BERNARD	70	70	SWP SSP	9.29		1	715.5 - AAC - SIN
1045	WEEDPATCH	WELLFIELD	70	70	SWP SSP	5.82		1	4/0 - AAC - SINGL
1046	WESIX TAP		70	70	SWP	2.51		1	2 - ACSR - SINGLE
1047	WESTLANDS TAP		70	70	SWP	1.07		1	1/0 - ACSR - SING
1048	WHEELER RIDGE	LAKEVIEW	70	70	SWP SSP	7.51		1	715.5 - AAC - SIN
1049	WHEELER RIDGE	SAN BERNARD	70	70	SWP SSP	5.88		1	397.5 - ACSR - SI
1050	WHEELER RIDGE	TEJON	70	70	T SWP	5.01		1	715.5 - AAC - SIN
1051	WHEELER RIDGE	WEEDPATCH	70	70	SWP SSP	22.43		1	3/0 - CU - SINGLE
1052	WISHON	COPPERMINE	70	70	T SSP SWP	19.99		1	336.4 - AAC - SIN
1053	WISHON	SAN JOAQUIN #3	70	70	SWP SSP OTHERS	7.68		1	1 - CU - SINGLE
1054	WRIGHT TAP		70	70	SWP OTHERS	1.18		1	4/0 - AAC - SINGL
1055	YANKE (NORTH FORK) TAP		70	70	SWP	0.44		1	397.5 - AAC - SIN
1056	ALMADEN	LOS GATOS	60	60	SWP SSP	6.38		1	336.4 - AAC - SIN
1057	ALMENDRA JCT	NICOLAUS	60	60	SWP SSP	24.9		1	2/0 - CU - SINGLE
1058	AMFOR TAP		60	60	SWP	1.08		1	1/0 - ACSR - SING
1059	ARBUCKLE TAP		60	60	SWP SSP	0.82		1	715.5 - AAC - SIN
1060	ARCATA	HUMBOLDT	60	60	SWP SSP	7.28		1	715.5 - AAC - SIN
1061	AUBURN TAP		60	60	SWP SSP	0.75		1	2/0 - CU - SINGLE
1062	BAIR	COOLEY LANDING #1	60	60	T SSP SWP	5.55		1	4/0 - CU - SINGLE
1063	BAIR	COOLEY LANDING #2	60	60	SWP	5.6		1	715.5 - AAC - SIN
1064	BASALT #1 TAP		60	60	T SWP	1.18		1	477 - ACSS - SING
1065	BEALE AFB (WAPA) #1 TAP		60	60	SSP	0.11		1	2/0 - CU - SINGLE
1066	BEALE AFB (WAPA) #2 TAP		60	60	SWP SSP	0.14		1	2/0 - CU - SINGLE
1067	BELLE HAVEN #1 TAP		60	60	SWP SSP	0.45		1	477 - ACSS - SING
1068	BELLE HAVEN #2 TAP		60	60	SWP	0.4		1	477 - ACSS - SING
1069	BIXLER TAP		60	60	SWP	0.55		1	4/0 - AAC - SINGL
1070	BLUE CHIP MILLING TAP		60	60	SWP	0.42		1	4/0 - AAC - SINGL
1071	BLUE LAKE TAP		60	60	SWP SSP	3.7		1	4/0 - ACAR - SING
1072	BRIDGEVILLE	GARBERVILLE	60	60	SWP SSP OTHERS	36.16		1	4/0 - ACSR - SING
1073	BRIONES TAP		60	60	SWP SSP	7		1	4/0 - AAC - SINGL
1074	BUENA VISTA BIOMASS POWER T		60	60	SWP SSP	1.02		1	715.5 - AAC - SIN
1075	BURNEY TAP		60	60	SWP SSP	1.09		1	1/0 - ACSR - SING
1076	BURNS	LONE STAR #1	60	60	SWP SSP OTHERS	5.42		1	3/0 - CU - SINGLE
1077	BURNS	LONE STAR #2	60	60	SWP SSP OTHERS	6.34		1	3/0 - CU - SINGLE
1078	BUTTE	CHICO #1	60	60	SWP	0.79		1	397.5 - AAC - SIN
1079	BUTTE	CHICO #2	60	60	SWP	0.74		1	4/0 - AAC - SINGL
1080	BUTTE	ESQUON	60	60	SWP SSP	9.87		1	4/0 - ALUM - SING
1081	CACHE SLOUGH TAP		60	60	SWP SSP	6.85		1	1/0 - ACSR - SING
1082	CALVO TAP		60	60	SWP	0.54		1	2 - ACSR - SINGLE
1083	CAPE HORN TAP		60	60	SWP	0.31		1	2 - ACSR - SINGLE
1084	CARBONA #2 TAP		60	60	SWP	5.64		1	397.5 - AAC - SIN
1085	CARIBOU	PLUMAS JCT	60	60	SWP SSP OTHERS	21.25		1	397.5 - ACSR - SI
1086	CARIBOU	WESTWOOD	60	60	SWP SSP OTHERS	21.06		1	795 - ACSR - SING
1087	CARIBOU #2		60	60	SWP SSP OTHERS	42.12		1	397.5 - ACSR - SI
1088	CASCADE	BENTON-DESCHUTES	60	60	SWP SSP OTHERS	15.98		1	715.5 - AAC - SIN
1089	CENTERVILLE	TABLE MTN	60	60	SWP SSP	21.5		1	715.5 - AAC - SIN
1090	CENTERVILLE	TABLE MTN-OROVILLE	60	60	T SSP OTHERS S	26.11		1	350 - AAC - SINGL
1091	CHICO A	DAYTON RD	60		SWP	0.8		1	1 - UNKNOWN - UNK
1092	CHRISTIE	FRANKLIN #1	60	60	SWP SSP OTHERS	5.01		1	715.5 - AAC - SIN
1093	CHRISTIE	FRANKLIN #2	60	60	SWP SSP OTHERS	5.11		1	336.4 - AAC - SIN
1094	CHRISTIE	WILLOW PASS	60	60	T SSP OTHERS S	15.93		1	3/0 - CU - SINGLE
1095	CHUALAR TAP		60	60	SWP	1.43		1	1 - UNKNOWN - UNK
1096	CIC TAP		60	60	SWP	0.13		1	397.5 - AAC - SIN
1097	CISCO GROVE TAP		60	60	SWP	0.34		1	2 - ACSR - SINGLE
1098	CLAY	MARTEL	60	60	SWP SSP OTHERS	21.49		1	715.5 - AAC - SIN
1099	CLEAR LAKE	HOPLAND	60	60	SWP SSP OTHERS	11.54		1	4/0 - AAC - SINGL
1100	CLEAR LAKE	KONOCTI	60	60	SWP SSP OTHERS	10.95		1	715.5 - AAC - SIN
1101	CLOVER CREEK TAP		60	60	SWP	0.02		1
1102	COBURN	BASIC ENERGY	60	60	SWP	3.39		1	1431 - AAC - BUND
1103	COBURN	OIL FIELDS #1	60	60	SWP SSP	29.46		1	715.5 - AAC - SIN
1104	COBURN	OIL FIELDS #2	60	60	SWP SSP	31.05		1	715.5 - AAC - SIN
1105	COGENERATION NATIONAL TAP		60	60	SWP	0.56		1	715.5 - AAC - SIN
1106	COLEMAN	COTTONWOOD	60	60	SWP SSP OTHERS	8.58		1	715.5 - AAC - SIN
1107	COLEMAN	RED BLUFF	60	60	SWP SSP	48.31		1	1/0 - CU - SINGLE
1108	COLEMAN	SOUTH	60	60	SWP SSP	13.39		1	715.5 - AAC - SIN
1109	COLEMAN HATCHERY TAP		60	60	SWP SSP	0.56		1	4/0 - AAC - SINGL
1110	COLGATE	ALLEGHANY	60	60	SWP SSP OTHERS	24.55		1	4 - ACSR - SINGLE
1111	COLGATE	CHALLENGE	60	60	SWP SSP OTHERS	13.04		1	4/0 - ACSR - SING
1112	COLGATE	GRASS VALLEY	60	60	SWP SSP OTHERS	13.17		1	2/0 - CU - SINGLE
1113	COLGATE	PALERMO	60	60	SWP SSP OTHERS	22.65		1	715.5 - AAC - SIN
1114	COLGATE	SMARTVILLE #1	60	60	SWP SSP OTHERS	11.26		1	477 - ACSS - SING
1115	COLGATE	SMARTVILLE #2	60	60	SWP SSP	11.19		1	4/0 - CU - SINGLE
1116	COLGATE PH	COLGATE SW STA	60	60	SSP	0.19		1	1113 - AAC - BUND
1117	COLLINS PINE TAP		60	60	SWP	1		1	2 - ACSR - SINGLE
1118	COLUSA JCT #1		60	60	SWP SSP	16.98		1	715.5 - AAC - SIN
1119	CONTRA COSTA	DU PONT	60	60	T OTHERS SWP	2.65		1	715.5 - AAC - SIN
1120	CONTRA COSTA	PITTSBURG	60	60	T SSP SWP	6.28		1	715.5 - AAC - SIN
1121	CONTRA COSTA	SHELL CHEMICAL#1(21KV)	60	60		9.55		1	4/0 - CU - SINGLE
1122	CONTRA COSTA	BALFOUR	60	60	SWP SSP	11.55		1	397.5 - AAC - SIN
1123	COOLEY LANDING	LOS ALTOS	60	60	T SSP SWP	14.89		1	715.5 - AAC - SIN
1124	COOLEY LANDING	LOS ALTOS (I2KV)	60	60	T SSP SWP	1.41		1	715.5 - AAC - SIN
1125	COOLEY LANDING	STANFORD	60	60	SWP SSP	6.04		1	715.5 - AAC - SIN
1126	COOLEY LANDING	STANFORD	60	60	N/A	1.59		1	2000 KCMIL - ALUM
1127	CORDELIA #1 TAP		60	60	SWP SSP	7.69		1	1 - CU - SINGLE 2
1128	CORDELIA #2 TAP		60	60	SWP SSP OTHERS	6.87		1	2/0 - CU - SINGLE
1129	CORDELIA INTERIM PUMPING PL		60	60	SWP SSP	0.36		1	1/0 - ACSR - SING
1130	CORTINA #1		60	60	SWP SSP	26.29		1	715.5 - AAC - SIN
1131	CORTINA #2		60	60	SWP SSP OTHERS	26.61		1	715.5 - AAC - SIN
1132	CORTINA #3		60	60	SWP SSP	24.8		1	715.5 - AAC - SIN
1133	CORTINA #4		60	60	SWP SSP	45.28		1	715.5 - AAC - SIN
1134	COTTONWOOD	BENTON #1	60	60	T SSP SWP	15.53		1	715.5 - AAC - SIN
1135	COTTONWOOD	BENTON #2	60	60	SWP SSP OTHERS	14.68		1	250 - CU - SINGLE
1136	COTTONWOOD	RED BLUFF	60	60	SWP SSP OTHERS	16.74		1	300 - AAC - SINGL
1137	COTTONWOOD #1		60	60	T SSP SWP	48.16		1	4/0 - AAC - SINGL
1138	COTTONWOOD #2		60	60	T SSP SWP	23.63		1	715.5 - AAC - SIN
1139	CROW CREEK SW STA	FRONTIER SOLAR PV	60	60	SSP	0.02		1	715.5 - SINGLE
1140	CROW CREEK SW STA	NEWMAN	60	60	SWP SSP	11.14		1	4/0 - CU - SINGLE
1141	CROWS LANDING TAP		60	60	SWP	5.28		1	4/0 - CU - SINGLE
1142	CRUSHER TAP		60	60	SWP SSP	1.95		1	1/0 - ACSR - SING
1143	CRYSTAL SPRINGS TAP		60	60	SWP SSP	0.28		1	4/0 - AAC - SINGL
1144	DEAN FOODS TAP		60	60	SWP	0.51		1	397.5 - AAC - SIN
1145	DEER CREEK	DRUM	60	60	SWP SSP OTHERS	6.24		1	2/0 - CU - SINGLE
1146	DEL MAR	ATLANTIC #1	60	60	SWP SSP	2.78		1	477 - ACSS - SING
1147	DEL MAR	ATLANTIC #2	60	60	SWP SSP	4.45		1	715.5 - AAC - SIN
1148	DEL MAR	ATLANTIC #1	60	60	N/A	1.18		1	3000 KCMIL - CU
1149	DEL MONTE	MONTEREY	60	60	SWP SSP	2.53		1	715.5 - AAC - SIN
1150	DEL MONTE	VIEJO	60	60	SWP SSP	7.92		1	715.5 - AAC - SIN
1151	DEL MONTE	FORT ORD #1	60	60	SWP SSP	6.13		1	715.5 - AAC - SIN
1152	DEL MONTE	FORT ORD #2	60	60	SWP SSP	5.6		1	715.5 - AAC - SIN
1153	DELTA	MTN GATE JCT	60	60	T OTHERS SWP	15.14		1	518 - ACSR - SING
1154	DESABLA	CENTERVILLE	60	60	T SSP OTHERS S	5.86		1	350 - AAC - SINGL
1155	DISTRICT 1001 TAP		60	60	SWP	1.47		1	4 - CU - SINGLE
1156	DISTRICT 1500 TAP		60	60	SWP SSP	3.61		1	6 - CU - SINGLE 2
1157	DIXON	VACA #1	60	60	T SSP SWP	18.35		1	715.5 - AAC - SIN
1158	DIXON	VACA #2	60	60	SWP SSP	26.77		1	715.5 - AAC - SIN
1159	DRUM	GRASS VALLEY-WEIMAR	60	60	SWP SSP	31.17		1	397.5 - ACSR - SI
1160	DRUM	SPAULDING	60	60	SWP SSP	9.36		1	4/0 - CU - SINGLE
1161	DU PONT TAP		60	60	SWP	0.52		1	715.5 - AAC - SIN
1162	EAST DUBLIN (BART) TAP		60	60	SWP	0.04		1	715.5 - AAC - SIN
1163	EEL RIVER TAP		60	60	T SSP SWP	2.31		1	4/0 - ACSR - SING
1164	ELK	GUALALA	60	60	SWP SSP OTHERS	29.01		1	1/0 - CU - SINGLE
1165	ELK CREEK TAP		60	60	SWP SSP	20.44		1	2 - ACSR - SINGLE
1166	ENCINAL TAP		60	60	SWP SSP	1.43		1	4 - CU - SINGLE
1167	ESSEX JCT	ARCATA-FAIRHAVEN	60	60	T SSP OTHERS S	16.08		1	715.5 - AAC - SIN
1168	ESSEX JCT	ORICK	60	60	SWP SSP OTHERS	31.29		1	2/0 - CU - SINGLE
1169	EUREKA	STA A	60	60	SWP	0.22		1	715.5 - AAC - SIN
1170	EVERGREEN	ALMADEN	60	60	SWP	4.96		1	715.5 - AAC - SIN
1171	EVERGREEN	MABURY	60	60	SWP	5.48		1	4/0 - CU - SINGLE
1172	FAIRHAVEN	HUMBOLDT	60	60	SWP SSP	15.56		1	715.5 - AAC - SIN
1173	FAIRHAVEN #1		60	60	SWP	0.41		1	715.5 - AAC - SIN
1174	FAIRHAVEN POWER CO TAP		60	60	SWP SSP	0.55		1	397.5 - AAC - SIN
1175	FITCH MTN #1 TAP		60	60	SWP	0.87		1	477 - ACSS - SING
1176	FITCH MTN #2 TAP		60	60	SWP	0.07		1	2/0 - CU - SINGLE
1177	FORKS OF THE BUTTE TAP		60	60	SWP	0.2		1	350 - AAC - SINGL
1178	FORT BRAGG	ELK	60	60	SWP SSP OTHERS	24.02		1	397.5 - AAC - SIN
1179	FORT ROSS	GUALALA	60	60	SWP SSP OTHERS	29.76		1	715.5 - AAC - SIN
1180	FORT SEWARD TAP		60	60	SWP SSP	7.7		1	4/0 - ACSR - SING
1181	FRENCH MEADOWS	MIDDLE FORK	60	60	SWP SSP OTHERS	13.19		1	4/0 - ACSR - SING
1182	FRESH EXPRESS TAP		60	60	SWP	0.56		1	2/0 - CU - SINGLE
1183	FRUITLAND TAP		60	60	SWP SSP	4.26		1	4/0 - ACSR - SING
1184	FULTON	WINDSOR	60	60	SWP SSP	6.59		1	477 - ACSS - SING
1185	FULTON	CALISTOGA	60	60	SWP SSP OTHERS	64.6		1	4/0 - AAC - SINGL
1186	FULTON	HOPLAND	60	60	SWP SSP	41.09		1	715.5 - AAC - SIN
1187	FULTON	MOLINO-COTATI	60	60	SWP SSP	20.52		1	715.5 - AAC - SIN
1188	FULTON	MOLINO-COTATI	60	60	SWP SSP	0.35		1	715.5 - AAC - SIN
1189	GARBERVILLE	LAYTONVILLE	60	60	SWP SSP OTHERS	39.99		1	715.5 - AAC - SIN
1190	GARCIA TAP		60	60	SWP SSP	3.04		1	1/0 - ACSR - SING
1191	GLENN #1		60	60	SWP SSP	33.37		1	715.5 - AAC - SIN
1192	GLENN #2		60	60	SWP SSP	34.69		1	715.5 - AAC - SIN
1193	GLENN #3		60	60	SWP SSP	28.51		1	715.5 - AAC - SIN
1194	GLENN #4		60	60	SWP SSP	12.54		1	715.5 - AAC - SIN
1195	GLENN #5		60	60	SWP SSP	7.41		1	715.5 - AAC - SIN
1196	GOLD HILL #1		60	60	SWP SSP OTHERS	27.85		1	715.5 - AAC - SIN
1197	GONZALES #1 TAP		60	60	SWP	0.2		1	2/0 - CU - SINGLE
1198	GONZALES #2 TAP		60	60	SWP SSP	0.3		1	2/0 - CU - SINGLE
1199	GRANITE ROCK TAP		60	60	SWP	2.39		1	4/0 - AAC - SINGL
1200	GREEN VALLEY	WATSONVILLE	60	60	SWP SSP	4.74		1	397.5 - AAC - SIN
1201	GREENLEAF #2 TAP		60	60	SWP	0.62		1	715.5 - AAC - SIN
1202	GRONEMEYER TAP		60	60	SWP	0.83		1	1/0 - ACSR - SING
1203	GUSTINE #1 TAP		60	60	SWP SSP	7.56		1	4/0 - AAC - SINGL
1204	GUSTINE #2 TAP		60	60	SWP	4.44		1	715.5 - AAC - SIN
1205	GWF #4 TAP		60	60	T SWP	0.25		1	397.5 - AAC - SIN
1206	HALSEY	PLACER	60	60	SWP SSP	4.94		1	397.5 - AAC - SIN
1207	HAMILTON BRANCH	CHESTER	60	60	SWP SSP OTHERS	12.27		1	4/0 - ACSR - SING
1208	HAMMER	COUNTRY CLUB	60	60	SWP SSP	8.82		1	715.5 - AAC - SIN
1209	HARRINGTON TAP		60	60	SWP	0.53		1	1/0 - ACSR - SING
1210	HARTLEY	CLEARLAKE	60	60	SWP SSP	6.66		1	4/0 - AAC - SINGL
1211	HAT CREEK #1	PIT #1	60	60	T SSP OTHERS S	6.08		1	1/0 - ACSR - SING
1212	HAT CREEK #1	WESTWOOD	60	60	SWP SSP OTHERS	55.87		1	4/0 - CU - SINGLE
1213	HEADGATE TAP		60	60	SWP SSP	0.97		1	4/0 - AAC - SINGL
1214	HEALDSBURG #1 TAP		60	60	SWP SSP	0.25		1	4/0 - AAC - SINGL
1215	HEALDSBURG #2 TAP		60	60	SWP SSP	0.16		1	471 - AAC - SINGL
1216	HERDLYN	BALFOUR	60	60	SWP SSP	20.5		1	1/0 - CU - SINGLE
1217	HILLSDALE JCT	HALF MOON BAY	60	60	SWP SSP OTHERS	6.82		1	397.5 - AAC - SIN
1218	HUMBOLDT	EUREKA	60	60	SWP SSP	4.7		1	715.5 - AAC - SIN
1219	HUMBOLDT	MAPLE CREEK	60	60	SWP SSP OTHERS	14.13		1	4/0 - ACSR - SING
1220	HUMBOLDT #1		60	60	T SSP SWP	11.05		1	715.5 - AAC - SIN
1221	HUMBOLDT BAY	EUREKA	60	60	SWP SSP	5.61		1	715.5 - AAC - SIN
1222	HUMBOLDT BAY	HUMBOLDT #1	60	60	SWP SSP	8.34		1	715.5 - AAC - SIN
1223	HUMBOLDT BAY	HUMBOLDT #2	60	60	SWP SSP	6.45		1	1113 - AAC - SING
1224	HUMBOLDT BAY	RIO DELL JCT	60	60	SWP SSP OTHERS	18.4		1	1113 - AAC - SING
1225	IGNACIO	STAFFORD	60		SWP SSP	6.13		1	715.5 - AAC - SIN
1226	IGNACIO	BOLINAS #1	60	60	SWP SSP OTHERS	15.06		1	715.5 - AAC - SIN
1227	IGNACIO	ALTO	60	60	SWP SSP	17.79		1	715.5 - AAC - SIN
1228	IGNACIO	ALTO-SAUSALITO #1	60	60	T SSP SWP	17.83		1	4/0 - ACSR - SING
1229	IGNACIO	ALTO-SAUSALITO #2	60	60	SWP SSP	17.83		1	4/0 - ACSR - SING
1230	IGNACIO	BOLINAS #2	60	60	SWP SSP OTHERS	28.22		1	715.5 - AAC - SIN
1231	INDUSTRIAL TAP		60	60	SWP	0.97		1	715.5 - AAC - SIN
1232	IONE TAP		60	60	SWP SSP	4.09		1	4/0 - AAC - SINGL
1233	IUKA TAP		60	60	SWP	0.49		1	4 - CU - SINGLE
1234	JANES CREEK TAP		60	60	SWP	1.78		1	4/0 - AAC - SINGL
1235	JEFFERSON	HILLSDALE JCT	60	60	T SSP SWP	14.72		1	715.5 - AAC - SIN
1236	JEFFERSON	LAS PULGAS	60	60	SWP SSP	6		1	715.5 - AAC - SIN
1237	JEFFERSON	STANFORD	60	60	SWP SSP	7.64		1	715.5 - AAC - SIN
1238	JEFFERSON	STANFORD (UNDERGROUND)	60	60	N/A	1.52		1
1239	JEFFERSON	LAS PULGAS	60	60	N/A	0.18		1	1750 KCMIL - ALUM
1240	JEFFERSON #1		60	60	T SWP	9.05		1	715.5 - AAC - SIN
1241	JENNINGS TAP		60	60	SWP	0.14		1	336.4 - AAC - SIN
1242	JOLON TAP		60	60	SWP SSP	15.87		1	4/0 - AAC - SINGL
1243	KASSON	CARBONA	60	60	SWP SSP	7.32		1	715.5 - AAC - SIN
1244	KASSON	BANTA #1	60	60	SWP	1.05		1	715.5 - AAC - SIN
1245	KASSON	LOUISE	60	60	SWP SSP	8.79		1	715.5 - AAC - SIN
1246	KASSON #1		60	60	SWP SSP	0.19		1	715.5 - AAC - SIN
1247	KESWICK	CASCADE	60	60	SWP SSP	9.35		1	4/0 - AAC - SINGL
1248	KESWICK	TRINITY	60	60	SWP SSP OTHERS	30.42		1	336.4 - ACSR - SI
1249	KILARC	CEDAR CREEK	60	60	SWP SSP	13.33		1	1/0 - ACSR - SING
1250	KILARC	DESCHUTES	60	60	SWP SSP	27.28		1	2 - ACSR - SINGLE
1251	KILARC	VOLTA TIE	60	60	T	1.94		1	1/0 - ACSR - SING
1252	KING CITY	COBURN #1	60	60	SWP SSP OTHERS	21.91		1	715.5 - AAC - SIN
1253	KING CITY	COBURN #2	60	60	SWP SSP OTHERS	15.79		1	715.5 - AAC - SIN
1254	KONOCTI	MIDDLETOWN	60	60	SWP SSP OTHERS	19.87		1	715.5 - AAC - SIN
1255	KONOCTI	EAGLE ROCK	60	60	SWP SSP OTHERS	9.66		1	715.5 - AAC - SIN
1256	LAGUNA TAP		60	60	SWP SSP	1.68		1	4/0 - AAC - SINGL
1257	LAGUNITAS TAP		60	60	SWP	0.6		1
1258	LAKEVILLE	PETALUMA C	60	60	SWP SSP	5.36		1	250 - CU - SINGLE
1259	LAKEVILLE #1		60	60	SWP SSP OTHERS	11.16		1	397.5 - AAC - SIN
1260	LAKEVILLE #2		60	60	T SSP SWP	21.62		1	1/0 - CU - SINGLE
1261	LAS POSITAS	VASCO	60	60	SWP SSP	1.5		1	715.5 - AAC - SIN
1262	LAURELES	OTTER	60	60	SWP SSP OTHERS	15.56		1	4/0 - ACSR - SING
1263	LAYTONVILLE	COVELO	60	60	SWP SSP OTHERS	16.09		1	715.5 - AAC - SIN
1264	LAYTONVILLE	WILLITS	60	60	SWP SSP OTHERS	23.14		1	715.5 - AAC - SIN
1265	LEE TAP		60	60	SWP	5.85		1	4/0 - AAC - SINGL
1266	LIMESTONE TAP		60	60	SWP	1.73		1	2 - ACSR - SINGLE
1267	LIVERMORE	LAS POSITAS	60	60	SWP SSP OTHERS	3.63		1	715.5 - AAC - SIN
1268	LOCKEFORD	INDUSTRIAL	60	60	SWP	6.03		1	715.5 - AAC - SIN
1269	LOCKEFORD	LODI #2	60	60	SWP SSP	9.41		1	715.5 - AAC - SIN
1270	LOCKEFORD	LODI #3	60	60	SWP SSP	15.42		1	715.5 - AAC - SIN
1271	LOCKEFORD #1		60	60	SWP SSP OTHERS	12.85		1	715.5 - AAC - SIN
1272	LODI	INDUSTRIAL	60	60	SWP SSP	0.97		1	715.5 - AAC - SIN
1273	LONE STAR TAP		60	60	SWP	1.18		1
1274	LOS COCHES TAP		60	60	SWP	1.33		1	4/0 - AAC - SINGL
1275	LOUISIANA PACIFIC (OROVILLE		60	60	SWP	0.16		1	1/0 - ACSR - SING
1276	LP FLAKEBOARD TAP		60	60	SWP	0.51		1	397.5 - AAC - SIN
1277	LYOTH TAP		60	60	SWP	1.34		1	4/0 - AAC - SINGL
1278	MANTECA	LOUISE	60	60	SWP SSP	12.53		1	715.5 - AAC - SIN
1279	MANTECA #1		60	60	SWP SSP	34.52		1	1/0 - CU - SINGLE
1280	MAPLE CREEK	HOOPA	60	60	SWP SSP OTHERS	29.13		1	1/0 - ACSR - SING
1281	MARSH TAP		60	60	SWP	3.97		1	1/0 - ACSR - SING
1282	MARTIN	SNEATH LANE	60	60	T SSP OTHERS S	7.19		1	715.5 - AAC - SIN
1283	MCDONALD TAP		60	60	SWP SSP OTHERS	5.88		1	1/0 - ACSR - SING
1284	MENDOCINO	HARTLEY	60	60	SWP SSP OTHERS	23.17		1	4/0 - ACSR - SING
1285	MENDOCINO	PHILO JCT-HOPLAND	60	60	SWP SSP	23.55		1	3/0 - CU - SINGLE
1286	MENDOCINO	WILLITS	60	60	SWP SSP	14.52		1	2/0 - CU - SINGLE
1287	MENDOCINO	WILLITS-FORT BRAGG	60	60	SWP SSP OTHERS	43.77		1	715.5 - ALUM - SI
1288	MENDOCINO #1		60	60	SWP SSP	7.48		1	3/0 - CU - SINGLE
1289	MENLO TAP		60	60	SWP	0.36		1	715.5 - AAC - BUN
1290	MIDDLE FORK #1		60	60	SWP SSP OTHERS	9.43		1	4/0 - ACSR - SING
1291	MIDDLE RIVER TAP		60	60	SWP SSP	7.02		1	3 - CU - SINGLE 3
1292	MILLBRAE	SNEATH LANE	60	60	T SSP SWP	6.49		1	715.5 - AAC - SIN
1293	MONTA VISTA	BURNS	60	60	SWP SSP OTHERS	18.06		1	3/0 - CU - SINGLE
1294	MONTA VISTA	LOS ALTOS	60	60	SWP SSP	7.13		1	715.5 - AAC - SIN
1295	MONTA VISTA	LOS GATOS	60	60	SWP SSP	10.88		1	715.5 - AAC - SIN
1296	MONTA VISTA	PERMANENTE	60	60	T SSP SWP	1.19		1	397.5 - AAC - SIN
1297	MONTE RIO	FORT ROSS	60	60	SWP SSP OTHERS	14.3		1	715.5 - AAC - SIN
1298	MONTE RIO	FULTON	60	60	SWP SSP OTHERS	22.56		1	715.5 - AAC - SIN
1299	MTN GATE JCT	CASCADE	60	60	SWP OTHERS	6.57		1	2/0 - CU - SINGLE
1300	MTN GATE TAP		60	60	SWP	0.7		1	1/0 - ACSR - SING
1301	MTN QUARRIES TAP		60	60	SWP SSP	2.63		1	397.5 - AAC - SIN
1302	MULE CREEK TAP		60	60		0.01		1	4/0 - AAC - SINGL
1303	NARROWS #1 TAP		60	60	SWP OTHERS	2.65		1	715.5 - AAC - SIN
1304	NARROWS #2 TAP		60	60	SWP SSP OTHERS	3.1		1	715.5 - AAC - SIN
1305	NAVY LAB TAP		60	60	SWP	0.19		1	2 - CU - SINGLE
1306	NEW HOGAN TAP		60	60	SWP	2.21		1	1/0 - ACSR - SING
1307	NEWARK	DECOTO	60	60	T SSP SWP	6.28		1	715.5 - AAC - SIN
1308	NEWARK	LIVERMORE	60	60	T OTHERS SWP	19.05		1	4/0 - CU - SINGLE
1309	NEWARK	VALLECITOS	60	60	T SSP SWP	12.39		1	715.5 - AAC - SIN
1310	NEWARK-SIERRA PAPERBOARD TA		60	60	SWP	0.29		1	715.5 - AAC - SIN
1311	NICOLAUS	CATLETT JCT	60	60	T SSP SWP	20.16		1	715.5 - AAC - SIN
1312	NICOLAUS	CATLETT JCT	60	60	T SSP SWP	18.63		1	715.5 - AAC - SIN
1313	NICOLAUS	CATLETT JCT (12KV)	60	60	T SSP SWP	18.63		1	715.5 - AAC - SIN
1314	NICOLAUS	MARYSVILLE	60	60	SWP SSP OTHERS	18.74		1	4/0 - CU - SINGLE
1315	NICOLAUS	PLAINFIELD	60	60	T SSP SWP	30.63		1	715.5 - AAC - SIN
1316	NICOLAUS	WILKINS SLOUGH	60	60	T SSP OTHERS S	42.72		1	4 - CU - SINGLE 3
1317	OAK PARK TAP		60	60	SWP SSP	0.87		1	4 - CU - SINGLE
1318	OILFIELDS	SARGENT CANYON	60	60	SWP	2.02		1	715.5 - AAC - SIN
1319	OILFIELDS	SALINAS RIVER	60	60	SWP	1.46		1	715.5 - AAC - SIN
1320	ORO FINO TAP		60	60	SWP	1.3		1	2 - ACSR - SINGLE
1321	OXBOW TAP		60	60	SWP	0.15		1	4/0 - ACSR - SING
1322	PACIFIC ETHANOL TAP		60	60	SWP	0.68		1	715.5 - AAC - SIN
1323	PACIFIC LUMBER (SCOTIA) TA		60	60	SWP OTHERS	0.52		1	4/0 - AAC - SINGL
1324	PACIFIC OROVILLE POWER TAP		60	60	SWP	0.78		1	4/0 - AAC - SINGL
1325	PALERMO	OROVILLE #1	60	60	SWP	6.97		1	715.5 - AAC - SIN
1326	PALERMO	OROVILLE #2	60	60	SWP SSP	10.13		1	715.5 - AAC - SIN
1327	PARDEE #1 TAP		60	60	SWP	4.33		1	2/0 - CU - SINGLE
1328	PARDEE #2 TAP		60	60	SWP	0.09		1	2/0 - CU - SINGLE
1329	PARKS TAP		60	60	SWP	0.45		1	1/0 - ACSR - SING
1330	PEACHTON	PEASE	60	60	SWP SSP	16.34		1	715.5 - AAC - SIN
1331	PEASE	HARTER	60	60	SWP SSP	15.88		1	715.5 - AAC - SIN
1332	PEASE	MARYSVILLE-HARTER	60	60	SWP SSP	10.29		1	715.5 - AAC - SIN
1333	PERMANENTE #1 TAP		60	60	SWP	0.31		1	397.5 - AAC - SIN
1334	PERMANENTE #2 TAP		60	60	SWP SSP	0.51		1	397.5 - AAC - SIN
1335	PHILO JCT	ELK	60	60	SWP SSP OTHERS	37.25		1	397.5 - ACSR - SI
1336	PINE GROVE TAP		60	60	SWP	2.67		1	397.5 - ACSR - SI
1337	PIT #1	HAT CREEK #2-BURNEY	60	60	SWP SSP	12.96		1	3/0 - CU - SINGLE
1338	PIT #1	MCARTHUR	60	60	SWP SSP	7.3		1	1/0 - ACSR - SING
1339	PITTSBURG #1 TAP (NO FLY)		60	60	SSP	1.15		1	4/0 - CU - SINGLE
1340	PITTSBURG #2 TAP		60	60	SWP	1.19		1	3/0 - CU - SINGLE
1341	PLACER	DEL MAR	60	60	SWP SSP	10.81		1	715.5 - AAC - SIN
1342	PLUMAS-SIERRA TAP		60	60	SWP	0.75		1	397.5 - ACSR - SI
1343	PORT COSTA BRICK TAP		60	60	SWP SSP OTHERS	1.9		1	3/0 - CU - SINGLE
1344	POTTER VALLEY	MENDOCINO	60	60	SWP SSP	10.94		1	3/0 - CU - SINGLE
1345	POTTER VALLEY	WILLITS	60	60	SWP SSP OTHERS	13.16		1	1/0 - ACSR - SING
1346	RADUM	LIVERMORE	60	60	SWP SSP	4.66		1	715.5 - AAC - SIN
1347	RADUM	VALLECITOS	60	60	T SSP OTHERS S	10.62		1	715.5 - AAC - SIN
1348	RED BANK TAP		60	60	SWP SSP	0.68		1	1/0 - ACSR - SING
1349	RIO DELL JCT	BRIDGEVILLE	60	60	SWP SSP OTHERS	21.25		1	1/0 - CU - SINGLE
1350	RIO DELL TAP		60	60	SWP SSP OTHERS	5.36		1	1/0 - CU - SINGLE
1351	ROBERTSON TAP		60	60	SWP SSP	0.82		1	1/0 - ACSR - SING
1352	ROLLINS TAP		60	60	SWP SSP	0.73		1	4/0 - ACSR - SING
1353	ROUGH & READY TAP		60	60	SWP SSP	0.95		1	4/0 - AAC - SINGL
1354	SALADO	CROW CREEK SW STA	60	60	SWP SSP	3.77		1	715.5 - ACSR - SI
1355	SALADO	NEWMAN #2	60	60	SWP SSP	21.56		1	715.5 - AAC - SIN
1356	SALINAS	FORT ORD #1	60	60	T SSP OTHERS S	10.22		1	715.5 - AAC - SIN
1357	SALINAS	FIRESTONE #1	60	60	SWP SSP	6.18		1	715.5 - AAC - SIN
1358	SALINAS	FIRESTONE #2	60	60	SWP SSP	17.21		1	715.5 - AAC - SIN
1359	SALINAS	LAGUNITAS	60	60	SWP SSP	5.81		1	4/0 - CU - SINGLE
1360	SALINAS	LAURELES	60	60	SWP SSP	27.46		1	266.8 - AAC - SIN
1361	SALINAS	FORT ORD #2	60	60	T SSP SWP	10.12		1	715.5 - AAC - SIN
1362	SALMON CREEK TAP		60	60	SWP SSP OTHERS	10.51		1	397.5 - AAC - SIN
1363	SAN ANDREAS (CCSF) TAP		60	60	SWP	0.39		1	397.5 - AAC - SIN
1364	SAN ARDO TAP		60	60	SWP SSP	0.34		1	715.5 - AAC - SIN
1365	SAN BRUNO TAP		60	60	SWP	1.13		1	1/0 - ACSR - SING
1366	SAN MATEO	BAIR	60	60	T SSP	13.99		1	397.5 - AAC - PAR
1367	SAN MATEO	HILLSDALE JCT	60	60	SWP SSP OTHERS	6.89		1	397.5 - AAC - SIN
1368	SAN RAMON	RADUM	60	60	SWP	7.06		1	715.5 - AAC - SIN
1369	SEBASTIANI TAP		60	60	SWP	0.01		1	4/0 - AAC - SINGL
1370	SENTER #1 TAP		60	60	SWP	0.23		1	336.4 - AAC - SIN
1371	SEQUOIA TAP		60	60	SWP	0.4		1	4/0 - AAC - SINGL
1372	SIERRA PAC IND (QUINCY) TAP		60	60	SWP	0.17		1
1373	SIERRA PINES LIMITED		60	60	SWP	0.4		1	4/0 - AAC - SINGL
1374	SIMPSON-KORBEL TAP		60	60	SWP	0.39		1	4/0 - AAC - SINGL
1375	SLAC TAP		60	60	SWP	1.41		1	397.5 - AAC - SIN
1376	SMARTVILLE	CAMP FAR WEST	60	60	SWP SSP	17.81		1	715.5 - AAC - SIN
1377	SMARTVILLE	CAMP FAR WEST (12KV)	60	60	SWP SSP	7.15		1	715.5 - AAC - SIN
1378	SMARTVILLE	MARYSVILLE	60	60	SWP SSP	20.11		1	715.5 - AAC - SIN
1379	SMARTVILLE	NICOLAUS #1	60	60	SWP SSP OTHERS	29.6		1	715.5 - AAC - SIN
1380	SMARTVILLE	NICOLAUS #2	60	60	SWP SSP OTHERS	30.16		1	715.5 - AAC - SIN
1381	SMARTVILLE TAP		60	60	SWP	0.09		1	715.5 - AAC - SIN
1382	SNEATH LANE	HALF MOON BAY	60	60	SWP SSP OTHERS	15.41		1	715.5 - AAC - SIN
1383	SNEATH LANE	PACIFICA	60	60	SWP SSP OTHERS	3.26		1	715.5 - AAC - SIN
1384	SOLEDAD #1		60	60	SWP SSP	15.5		1	397.5 - AAC - SIN
1385	SOLEDAD #2		60	60	SWP SSP OTHERS	18.86		1	4/0 - AAC - SINGL
1386	SOLEDAD #3		60	60	SWP SSP	1.63		1	397.5 - AAC - SIN
1387	SOLEDAD #4		60	60	SWP SSP	6.08		1	397.5 - AAC - SIN
1388	SPAULDING	SUMMIT	60	60	T SSP OTHERS S	19.65		1	4/0 - CU - SINGLE
1389	SPAULDING #3	SPAULDING #1	60	60	SWP	1.09		1	1/0 - CU - SINGLE
1390	STAGG	COUNTRY CLUB #1	60	60	SSP	2.43		1	715.5 - AAC - SIN
1391	STAGG	COUNTRY CLUB #2	60	60	SWP SSP	2.46		1	715.5 - AAC - SIN
1392	STAGG	HAMMER	60	60	SWP SSP	4.25		1	715.5 - AAC - SIN
1393	STANDARD #1 & #2 (12KV)		60	60	T	4.16		1	1 - UNKNOWN - UNK
1394	STANISLAUS RECOVERY TAP		60	60	SWP	0.11		1	397.5 - AAC - SIN
1395	STAUFFER TAP		60	60	SWP SSP	0.58		1	1/0 - ACSR - SING
1396	STOCKTON	NEWARK	60	60	T SSP SWP	14.59		1	3/0 - CU - SINGLE
1397	STOCKTON A	WEBER #1	60	60	SWP SSP	13.2		1	715.5 - AAC - SIN
1398	STOCKTON A	WEBER #2	60	60	SWP	9.87		1	715.5 - AAC - SIN
1399	STOCKTON A	WEBER #3	60	60	SWP SSP	9.81		1	715.5 - AAC - SIN
1400	STOCKTON A #1		60	60	T SSP SWP	5.58		1	715.5 - AAC - SIN
1401	SUMIDEN WIRE PRODUCTS TAP		60	60	SWP	0.19		1	397.5 - AAC - SIN
1402	SUNOL TAP		60	60	SWP OTHERS	0.08		1	4/0 - AAC - SINGL
1403	SUTTER HOME	SUTTER HOME SW STA	60	60	SSP	0.03		1	715.5 - AAC - SIN
1404	SUTTER HOME SW STA	LOCKEFORD-LODI	60	60	SWP SSP	29.74		1	715.5 - AAC - SIN
1405	SUTTER HOME SW STA	STAGG	60	60	SWP SSP	17.13		1	715.5 - AAC - SIN
1406	TABLE MTN	PEACHTON	60	60	SWP SSP	14.84		1	715.5 - AAC - SIN
1407	TERMINOUS TAP		60	60	SWP	3.01		1	2/0 - ACSR - SING
1408	TEXACO TAP		60	60	SWP SSP	0.72		1	397.5 - AAC - SIN
1409	TOCALOMA TAP		60	60	SWP OTHERS	1.03		1	2 - ACSR - SINGLE
1410	TRAVIS TAP		60	60	SWP SSP	2.88		1	715.5 - AAC - SIN
1411	TRINIDAD TAP		60	60	SWP	1.34		1	1 - CU - SINGLE
1412	TRINITY	MAPLE CREEK	60	60	T SSP OTHERS S	55.45		1	4/0 - ACSR - SING
1413	TULUCAY	NAPA #1	60	60	T SSP SWP	9.72		1	715.5 - AAC - SIN
1414	TULUCAY	NAPA #2	60	60	SWP SSP	3.93		1	715.5 - AAC - SIN
1415	ULTRA POWER TAP		60	60	SWP	1.17		1	4/0 - AAC - SINGL
1416	UNION CHEMICAL TAP		60	60	SWP	1.04		1	715.5 - AAC - SIN
1417	URICH TAP		60	60	SWP	0.21		1	4/0 - AAC - SINGL
1418	US WINDPOWER TAP		60	60	SWP	1.52		1	4/0 - AAC - SINGL
1419	VACA	PLAINFIELD	60	60	SWP SSP	29.83		1	715.5 - AAC - SIN
1420	VALLEY SPRINGS	CALAVERAS CEMENT	60	60	SWP SSP	7.91		1	715.5 - AAC - SIN
1421	VALLEY SPRINGS	MARTELL #1	60	60	SWP SSP	12.75		1	1113 - AAC - SING
1422	VALLEY SPRINGS	CLAY	60	60	SWP SSP OTHERS	17.3		1	715.5 - AAC - SIN
1423	VALLEY SPRINGS #1		60	60	SWP SSP OTHERS	27.27		1	1113 - AAC - SING
1424	VALLEY SPRINGS #2		60	60	SWP SSP OTHERS	25.65		1	1113 - AAC - SING
1425	VASCO	HERDLYN	60	60	SWP OTHERS	10.97		1	715.5 - AAC - SIN
1426	VICTOR TAP		60	60	SSP	0.06		1	4/0 - AAC - SINGL
1427	VIEJO	MONTEREY	60	60	SWP SSP	2.28		1	715.5 - AAC - SIN
1428	VOLTA	DESCHUTES	60	60	SWP SSP	20.86		1	2/0 - CU - SINGLE
1429	VOLTA	SOUTH	60	60	SWP SSP	4.86		1	1 - CU - SINGLE 2
1430	WADHAM TAP		60	60	SWP	1.68		1	4/0 - AAC - SINGL
1431	WASHOE TAP		60	60	SWP SSP	1.04		1	4/0 - AAC - SINGL
1432	WATERSHED TAP		60	60	SWP SSP	0.28		1	4/0 - AAC - SINGL
1433	WATSONVILLE	SALINAS	60	60	SWP SSP OTHERS	28.39		1	3/0 - CU - SINGLE
1434	WEBER	FRENCH CAMP #1	60	60	SWP SSP	6.07		1	715.5 - AAC - SIN
1435	WEBER	FRENCH CAMP #2	60	60	T SSP SWP	10.89		1	715.5 - AAC - SIN
1436	WEBER	MORMON JCT	60	60	SWP SSP	17.67		1	715.5 - AAC - SIN
1437	WEIMAR	HALSEY	60	60	SWP SSP	6.28		1	397.5 - AAC - SIN
1438	WEIMAR #1		60	60	SWP SSP OTHERS	13.98		1	80 - ACSR - SINGL
1439	WEST POINT	VALLEY SPRINGS	60	60	SWP SSP OTHERS	21.66		1	715.5 - AAC - SIN
1440	WEST SAC COM TOWERS		60		T SSP	0.02		1
1441	WESTINGHOUSE TAP		60	60	T SWP	7.97		1	4/0 - CU - SINGLE
1442	WILLOW PASS	CONTRA COSTA	60	60	T SSP SWP	10.82		1	715.5 - AAC - SIN
1443	WIND FARMS		60	60	SWP	3.75		1	715.5 - AAC - SIN
1444	WINDSOR	FITCH MOUNTAIN	60	60	SWP SSP OTHERS	21.24		1	4/0 - ACSR - SING
1445	WINTU TAP		60	60	SWP	1.86		1	1/0 - ACSR - SING
1446	WOHLER TAP		60	60	SWP	1.44		1	2 - ACSR - SINGLE
1447	WOODBRIDGE TAP		60	60	SWP	0.53		1	4/0 - AAC - SINGL
1448	YUBA CITY COGEN TAP		60	60	SWP	0.8		1	477 - ACSS - SING
1449	ZOND WIND TAP		60	60	SWP	1.19		1
1450	A	Y #1 (UNDERGROUND IDLE)			N/A	0.35		1	1250 KCMIL - CU
1451	Summary of Lines
1452	listed individually above
1453	Towers & Poles		500			1,328				29,217,173	461,063,372	490,280,545	1,594,870	9,529,274		11,124,144
1454			230			5,335				77,883,619	1,757,640,266	1,835,523,885	6,408,707	38,291,725		44,700,432
1455			115			6,114				92,589,376	1,052,639,078	1,145,228,454	7,344,486	43,882,962		51,227,448
1456			70			1,544				14,828,234	225,301,498	240,129,732	1,854,741	11,081,991		12,936,732
1457			60			3,905				34,646,232	528,067,383	562,713,615	4,690,909	28,027,963		32,718,872
1458	Other Undground
1459	Transmission Lines		230			86				2,790,742	238,509,403	241,300,145	139,269	839,038		978,307
1460			115			84				122,163	516,524,425	516,646,588	136,226	820,704		956,930
1461			70
1462			60			5					21,150,299	21,150,299	8,733	52,614		61,347
1463	Transmission Roads										103,255,426	103,255,426
36	TOTAL					36,802.57		1,450		252,077,539	4,904,151,150	5,156,228,689	22,177,941	132,526,271		154,704,212

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

TRANSMISSION LINES ADDED DURING YEAR

Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines.
Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m).
If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.

LINE DESIGNATION

SUPPORTING STRUCTURE

CIRCUITS PER STRUCTURE

CONDUCTORS

LINE COST

Line No.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

(o)

(p)

(q)

Semitropic Sub

Midway Substation

14.2

Various

AAC

T1 8.5 FT

115

100

4,773,741

1,267,713

100

6,041,654

Headgate Metering station

Glenn #3

111.1

SWP, LDSP

146

4/0

AAC

T1 8.5 FT

4,327,626

47,491,469

61,411,844

100

113,231,039

TOTAL

125.3

163

4,327,726

52,265,210

62,679,557

200

119,272,693

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

SUBSTATIONS
Report below the information called for concerning substations of the respondent as of the end of the year. Substations which serve only one industrial or street railway customer should not be listed below. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f). Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
		Character of Substation		VOLTAGE (In MVa)						Conversion Apparatus and Special Equipment
Line No.	SubstationNameAndLocation Name and Location of Substation (a)	SubstationCharacterDescription Transmission or Distribution (b)	SubstationCharacterAttendedOrUnattended Attended or Unattended (b-1)	PrimaryVoltageLevel Primary Voltage (In MVa) (c)	SecondaryVoltageLevel Secondary Voltage (In MVa) (d)	TertiaryVoltageLevel Tertiary Voltage (In MVa) (e)	SubstationInServiceCapacity Capacity of Substation (In Service) (In MVa) (f)	NumberOfTransformersInService Number of Transformers In Service (g)	Number of Spare Transformers (h)	ConversionApparatusAndSpecialEquipmentType Type of Equipment (i)	NumberOfConversionApparatusAndSpecialEquipmentUnits Number of Units (j)	CapacityOfConversionApparatusAndSpecialEquipment Total Capacity (In MVa) (k)
1	ARCO SUB, Lost Hills	Transmission	Unattended	230	70	13.2	360	6	1	2.00000
2	ATLANTIC SUB, Roseville	Transmission	Unattended	230	60	13.2	334	4	1	2.00000
3	ATLANTIC SUB, Roseville	Transmission	Unattended	230	115	13.2	840	2		2.00000
4	BAIR SUB, Redwood City	Transmission	Unattended	115	60	13.2	80	3		1.00000
5	BELLOTA SUB, Bellota	Transmission	Unattended	230	115	13.2	400	2		Sync Cond	1	40
6	BORDEN SUB, Madera	Transmission	Unattended	230	70	13.2	400	2		2.00000
7	BRIDGEVILLE SUB, Bridgeville	Transmission	Unattended	115	60	13.2	90	3	1	1.00000
8	BRIGHTON SUB, Sacramento	Transmission	Unattended	230	115	13.2	840	2		2.00000
9	BUTTE SUB, Chico	Transmission	Unattended	115	60	13.2	90	3	1	1.00000
10	CASCADE SUB, Pine Grove	Transmission	Unattended	115	60	13.2	76	3		1.00000
11	CHRISTIE SUB, Hercules	Transmission	Unattended	115	60	13.2	190	4	1	2.00000
12	COBURN SUB, King City	Transmission	Unattended	230	60	13.2	214	6	1	2.00000
13	CONTRA COSTA SUBSTATION, Antioch	Transmission	Unattended	115	60	13.2	120	6	2	2.00000
14	CONTRA COSTA SUBSTATION, Antioch	Transmission	Unattended	230	115	13.2	180	3	1	1.00000
15	COOLEY LANDING SUB, Palo Alto	Transmission	Unattended	115	60	13.8	290	4	1	2.00000
16	CORCORAN SUB, Corcoran	Transmission	Unattended	115	70	13.2	90	3	1	1.00000
17	CORTINA SUB, Williams	Transmission	Unattended	115	60	13.2	200	1		1.00000
18	CORTINA SUB, Williams	Transmission	Unattended	230	115	13.2	588	4	2	2.00000
19	COTTONWOOD SUB, Cottonwood	Transmission	Unattended	230	60	13.2	400	2		2.00000
20	COTTONWOOD SUB, Cottonwood	Transmission	Unattended	230	115	13.2	240	6	1	2.00000
21	DEL MONTE SUB, Monterey	Transmission	Unattended	115	60	13.2	400	2		2.00000
22	DIVIDE SUB, Orcutt	Transmission	Unattended	115	70	13.2	170	6	1	2.00000
23	EAGLE ROCK SUB, Geysers	Transmission	Unattended	115	60		68	3	1	1.00000
24	EAST NICOLAUS SUB, E. Nicolaus	Transmission	Unattended	115	60		400	2		2.00000
25	EASTSHORE SUB, Hayward	Transmission	Unattended	230	115		840	2		2.00000
26	EVERGREEN SUB, San Jose	Transmission	Unattended	115	60	13.2	80	3	1	1.00000
27	FULTON SUB, Fulton	Transmission	Unattended	115	60	13.2	600	2		2.00000
28	FULTON SUB, Fulton	Transmission	Unattended	230	115	13.2	823	4	1	2.00000
29	GATES SUB, Huron	Transmission	Unattended	115	70	13.2	117	3	1	1.00000
30	GATES SUB, Huron	Transmission	Unattended	230	115	13.2	120	3		1.00000
31	GATES SUB, Huron	Transmission	Unattended	500	230	13.2	1122	3	1	2.00000
32	GLENN SUB, Orland	Transmission	Unattended	230	60	13.2	255	4	1	2.00000
33	GOLD HILL SUB, Folsom	Transmission	Unattended	115	60	13.2	80	3		1.00000
34	GOLD HILL SUB, Folsom	Transmission	Unattended	230	115	13.2	840	2		2.00000
35	GREEN VALLEY SUB, Watsonville	Transmission	Unattended	115	60		38	3		1.00000
36	HELM SUB, San Joaquin	Transmission	Unattended	230	70	13.2	134	3		1.00000
37	HENRIETTA SUB, Lamoore	Transmission	Unattended	230	70	13.2	286	2		2.00000
38	HENRIETTA SUB, Lamoore	Transmission	Unattended	230	115	2.4	180	3	1	1.00000
39	HERDLYN SUB, Tracy	Transmission	Unattended	70	60	2.4	50	3	1	1.00000
40	HERNDON SUB, Herndon	Transmission	Unattended	230	115	13.2	1260	3		Sync Cond	2	80
41	HOPLAND SUB, Hopland	Transmission	Unattended	115	60	13.2	40	1		1.00000
42	HUMBOLDT SUB SUB, Eureka	Transmission	Unattended	115	60	13.2	400	2		SVC	1	50
43	IGNACIO SUB, Ignacio	Transmission	Unattended	115	60	13.2	400	2		2.00000
44	IGNACIO SUB, Ignacio	Transmission	Unattended	230	115	13.2	823	4	1	2.00000
45	JEFFERSON SUB, Redwood City	Transmission	Unattended	230	60	13.2	400	2		2.00000
46	KASSON SUB, Tracy	Transmission	Unattended	115	60	13.2	76	3		1.00000
47	KERN PP SUB, Bakersfield	Transmission	Unattended	115	70	13.2	400	2		2.00000
48	KERN PP SUB, Bakersfield	Transmission	Unattended	230	115	13.2	1260	3		3.00000
49	KINGSBURG SUB, Kingsburg	Transmission	Unattended	115	70	13.8	90	3	1	1.00000
50	LAKEVILLE SUB, Petaluma	Transmission	Unattended	230	60	13.2	400	2		2.00000
51	LAKEVILLE SUB, Petaluma	Transmission	Unattended	230	115	13.2	840	2		2.00000
52	LAS POSITAS SUB, Livermore	Transmission	Unattended	230	60	13.2	90	3		1.00000
53	LOCKEFORD SUB, Lockeford	Transmission	Unattended	230	60	13.2	400	2		2.00000
54	LOS BANOS SUB, Los Banos	Transmission	Unattended	230	70	13.2	334	4		2.00000
55	LOS BANOS SUB, Los Banos	Transmission	Unattended	500	230	13.8	840	3	1	1.00000
56	LOS ESTEROS SUB,	Transmission	Unattended	230	115	12	840	2		2.00000
57	MANTECA SUB, Manteca	Transmission	Unattended	115	60	13.2	100	1	1	2.00000
58	MCCALL SUB, Selma	Transmission	Unattended	230	115	13.2	1243	5	1	Sync Cond	2	80
59	MENDOCINO SUB, Redwood Valley	Transmission	Unattended	115	60	13.2	280	4	1	2.00000
60	MENDOTA SUB, Mendota	Transmission	Unattended	115	70	12	90	3	1	1.00000
61	MERCED SUB, Merced	Transmission	Unattended	115	70	6.6	50	3		1.00000
62	MESA SUB, Nipomo	Transmission	Unattended	230	115	13.2	840	2		2.00000
63	METCALF SUB, San Jose	Transmission	Unattended	500	230	13.8	3366	9	2	3.00000
64	METCALF SUB, San Jose	Transmission	Unattended	230	115	13.2	1630	10	1	4.00000
65	MIDWAY SUB, Buttonwillow	Transmission	Unattended	230	115	13.2	1260	3		3.00000
66	MIDWAY SUB, Buttonwillow	Transmission	Unattended	500	230	13.8	3364	9	2	3.00000
67	MILLBRAE SUB, Millbrae	Transmission	Unattended	115	60	13.8	90	3		1.00000
68	MONTA VISTA SUB, Cupertino	Transmission	Unattended	115	60	13.2	200	1		1.00000
69	MONTA VISTA SUB, Cupertino	Transmission	Unattended	230	60		134	3	1	1.00000
70	MONTA VISTA SUB, Cupertino	Transmission	Unattended	230	115	13.2	1260	3		1.00000
71	MORAGA SUB, Orinda	Transmission	Unattended	230	115	13.2	1243	5	1	3.00000
72	MORRO BAY PP SWYD, Morro Bay	Transmission	Unattended	230	115	13.2	269	3	1	1.00000
73	MOSS LANDING PP SUB, Moss Landing	Transmission	Unattended	230	115	13.2	1680	4		2.00000
74	MOSS LANDING PP SUB, Moss Landing	Transmission	Unattended	500	230	13.8	1122	3	1	1.00000
75	NEW KEARNEY SUB, FRESNO	Transmission	Unattended	230	70	13.2	200	4	1	1.00000
76	NEWARK SUB, Fremont	Transmission	Unattended	115	60	13.2	80	3		1.00000
77	NEWARK SUB, Fremont	Transmission	Unattended	230	115	13.2	1646	8	1	SVC	1	220
78	ORO LOMA SUB, Dos Palos	Transmission	Unattended	115	70	13.2	60	3		1.00000
79	PALERMO SUB, Palermo	Transmission	Unattended	230	60		168	3	1	1.00000
80	PALERMO SUB, Palermo	Transmission	Unattended	230	115	13.2	420	1		1.00000
81	PANOCHE SUB, Mendota	Transmission	Unattended	230	115	13.2	840	2		2.00000
82	PEASE SUB, Tierra Buena	Transmission	Unattended	115	60	13.2	80	3	1	1.00000
83	PITTSBURG PP SUB,	Transmission	Unattended	230	115	13.2	840	2		2.00000
84	PLACER SUB, Auburn	Transmission	Unattended	115	60		95	3		1.00000
85	RAVENSWOOD SUB, Menlo Park	Transmission	Unattended	230	115	13.2	823	4	1	2.00000
86	REEDLEY SUB, Reedley	Transmission	Unattended	115	70	13.2	190	4	1	2.00000
87	RIO OSO SUB, Rio Oso	Transmission	Unattended	230	115	13.2	254	6		2.00000
88	ROUND MOUNTAIN SUB, Rd Mtn	Transmission	Unattended	500	230	13.8	1122	3	1	1.00000
89	SALADO SUB, Patterson	Transmission	Unattended	115	60	13.2	200	2		2.00000
90	SALINAS SUB, Salinas	Transmission	Unattended	115	60	13.2	400	2		2.00000
91	SAN FRAN A (POTRERO PP) SUB, San Francisco	Transmission	Unattended	230	115	13.2	420	1		1.00000
92	SAN FRAN H (MARTIN) SUB, Daly City	Transmission	Unattended	115	60		100	1		1.00000
93	SAN FRAN H (MARTIN) SUB, Daly City	Transmission	Unattended	230	115		823	4	1	2.00000
94	SAN LUIS OBISPO SUB, SLO	Transmission	Unattended	115	70	13.2	200	1		1.00000
95	SAN MATEO SUB, San Mateo	Transmission	Unattended	115	60		200	2		2.00000
96	SAN MATEO SUB, San Mateo	Transmission	Unattended	230	115		1260	3		Sync Cond	2	88
97	SAN RAMON SUB, San Ramon	Transmission	Unattended	230	60	13.2	90	3	1	1.00000
98	SANGER SUB, Fresno	Transmission	Unattended	115	70	6.6	30	3	1	1.00000
99	SCHINDLER SUB, Five Points	Transmission	Unattended	115	70	13.2	90	3	1	1.00000
100	SEMITROPIC SUB, Wasco	Transmission	Unattended	115	70	13.8	90	3	1	1.00000
101	SOBRANTE SUB, Orinda	Transmission	Unattended	230	115		823	4	1	2.00000
102	SOLEDAD SUB, Soledad	Transmission	Unattended	115	60		75	6		2.00000
103	STAGG SUB, Stockton	Transmission	Unattended	230	60	13.2	600	2		2.00000
104	TABLE MOUNTAIN SUB, Oroville	Transmission	Unattended	230	115		1008	5	1	3.00000
105	TABLE MOUNTAIN SUB, Oroville	Transmission	Unattended	500	230	13.8	1122	3	1	1.00000
106	TAFT SUB, Taft	Transmission	Unattended	115	70	13.2	162	4		2.00000
107	TEMPLETON SUB, TEMPLETON	Transmission	Unattended	230	70	13.2	175	1		1.00000
108	TESLA SUB, Tracy	Transmission	Unattended	230	115	13.2	806	6	1	2.00000
109	TESLA SUB, Tracy	Transmission	Unattended	500	230	13.2	3366	9	2	3.00000
110	TRINITY SUB, Weaverville	Transmission	Unattended	115	60	13.2	90	3	1	1.00000
111	TULUCAY SUB, Napa	Transmission	Unattended	230	60	13.2	400	2		2.00000
112	VACA DIXON SUB, Vacaville	Transmission	Unattended	115	60	13.2	290	4	1	2.00000
113	VACA DIXON SUB, Vacaville	Transmission	Unattended	230	115	13.2	1094	8		3.00000
114	VACA DIXON SUB, Vacaville	Transmission	Unattended	500	230	13.8	2244	6	1	2.00000
115	VALLEY SPRINGS SUB, Valley Springs	Transmission	Unattended	230	60	13.2	334	4	1	2.00000
116	WEBER SUB, Stockton	Transmission	Unattended	230	60	13.2	600	2		2.00000
117	WHEELER RIDGE SUB, Bakersfield	Transmission	Unattended	115	70	13.2	60	3	1	1.00000
118	WHEELER RIDGE SUB, Bakersfield	Transmission	Unattended	230	70	13.2	400	2		2.00000
119	WILSON SUB, Merced	Transmission	Unattended	230	115	13.2	689	4	1	2.00000
120	7th STANDARD SUB, Bakersfield	Distribution	Unattended	115	21		45	1		1.00000
121	AIRWAYS SUB, Fresno, Ca.	Distribution	Unattended	115	12	7.2	90	2		2.00000
122	ALHAMBRA SUB, Martinez	Distribution	Unattended	115	12	7.2	27	2		2.00000
123	ALLEGHANY SUB, Alleghany	Distribution	Unattended	60	12	7.2	13	1		1.00000
124	ALMADEN SUB, San Jose	Distribution	Unattended	60	12	7.2	60	2		2.00000
125	ALPAUGH SUB, Tulare	Distribution	Unattended	115	12		41	2		2.00000
126	ALTO SUB, Mill Valley	Distribution	Unattended	60	12	2.4	49	4	1	2.00000
127	AMES DISTRIBUTION SUB, Mountain View	Distribution	Unattended	115	12	7.2	30	1		1.00000
128	ANDERSON SUB, Anderson	Distribution	Unattended	60	12	2.4	19	3	1	1.00000
129	ANGIOLA SUB, Kings	Distribution	Unattended	70	12	7.2	16	1		1.00000
130	ANITA SUB, Chico	Distribution	Unattended	60	12	2.4	38	2		2.00000
131	ANTELOPE SUB, Blackwell Corner	Distribution	Unattended	70	12	2.4	16	1		1.00000
132	ANTLER SUB, Lakehead	Distribution	Unattended	60	12	2.4	11	3	1	1.00000
133	APPLE HILL SUB, Camino	Distribution	Unattended	115	12	7.2	16	1		1.00000
134	APPLE HILL SUB, Camino	Distribution	Unattended	115	21	7.2	16	1		1.00000
135	ARBUCKLE SUB, ARBUCKLE	Distribution	Unattended	60	12	7.2	27	4	1	2.00000
136	ARCATA SUB, Arcata	Distribution	Unattended	60	12	2.4	60	2		2.00000
137	ARVIN SUB, Arvin	Distribution	Unattended	70	12	2.4	13	3	1	1.00000
138	ASHLAN AVENUE SUB, Fresno	Distribution	Unattended	230	12	7.2	210	3		3.00000
139	ATASCADERO SUB, Atascadero	Distribution	Unattended	115	12	7.2	30	1		1.00000
140	ATWATER SUB, Atwater	Distribution	Unattended	115	12	7.2	90	2		2.00000
141	AUBERRY SUB, Auberry	Distribution	Unattended	70	12	7.2	25	2		2.00000
142	AVENA SUB, Escalon	Distribution	Unattended	115	12		16	3	1	1.00000
143	AVENAL SUB, Avenal	Distribution	Unattended	70	12		16	1		1.00000
144	BAHIA SUB, Benicia	Distribution	Unattended	230	12	7.2	112	2		2.00000
145	BAIR SUB, Redwood City	Transmission	Unattended	115	12	7.2	45	1		1.00000
146	BAKERSFIELD SUB, Bakersfield	Distribution	Unattended	230	21	7.2	225	3		3.00000
147	BANGOR SUB, Bangor	Distribution	Unattended	60	12	7.2	13	1		1.00000
148	BARTON SUB, Fresno	Distribution	Unattended	115	12	7.2	120	3		3.00000
149	BASALT SUB, Napa	Distribution	Unattended	60	12	2.4	39	4		2.00000
150	BAY MEADOWS SUB, San Mateo	Distribution	Unattended	115	21	7.2	90	2		2.00000
151	BAY MEADOWS SUB, San Mateo	Distribution	Unattended	115	12	7.2	75	2		2.00000
152	BAYWOOD SUB, Morro Bay	Distribution	Unattended	70	12	2.4	16	1		1.00000
153	BEAR VALLEY SUB, Bear Valley	Distribution	Unattended	70	21	7.2	13	1		1.00000
154	BELL SUB, Auburn	Distribution	Unattended	115	12	7.2	57	2		2.00000
155	BELLE HAVEN SUB, Menlo Park	Distribution	Unattended	60	12	2.4	57	3		3.00000
156	BELLE HAVEN SUB, Menlo Park	Distribution	Unattended	60	4	2.4	16	6	1	2.00000
157	BELLEVUE SUB, Santa Rosa	Distribution	Unattended	115	12	7.2	70	3		3.00000
158	BELMONT SUB, Belmont	Distribution	Unattended	115	12	7.2	135	3		3.00000
159	BERRENDA A SUB,	Distribution	Unattended	70	4	2.4	16	2		2.00000
160	BIG BASIN SUB, Santa Cruz	Distribution	Unattended	60	12		11	3	1	1.00000
161	BIG MEADOWS SUB, Greenville	Distribution	Unattended	60	44	2.4	15	3		1.00000
162	BIOLA SUB, Biola	Distribution	Unattended	70	12	2.4	20	3		1.00000
163	BLACKWELL SUB, Blackwell Corner	Distribution	Unattended	70	12	2.4	13	1		1.00000
164	BLUE LAKE SUB, Blue Lake	Distribution	Unattended	60	12	2.4	13	3	1	1.00000
165	BOGUE SUB, Yuba City	Distribution	Unattended	115	12	7.2	90	2		2.00000
166	BOLINAS SUB, Boninas	Distribution	Unattended	60	12	7.2	13	1		1.00000
167	BONITA SUB, Madera	Distribution	Unattended	70	12	7.2	16	1		1.00000
168	BORDEN SUB, Madera	Transmission	Unattended	230	12	7.2	30	1		1.00000
169	BOWLES SUB, Bowles	Distribution	Unattended	70	12	7.2	30	1		1.00000
170	BRENTWOOD SUB, Brentwood	Distribution	Unattended	230	21	7.2	225	3		3.00000
171	BRITTON SUB, Sunnyvale	Distribution	Unattended	115	12		120	3		3.00000
172	BRUNSWICK SUB, Grass Valley	Distribution	Unattended	115	12	7.2	90	3		3.00000
173	BUELLTON SUB, Buellton /93427	Distribution	Unattended	115	12	7.2	21	2		2.00000
174	BUENA VISTA SUB, Salinas	Distribution	Unattended	60	12	7.2	76	3		3.00000
175	BULLARD SUB, Fresno	Distribution	Unattended	115	12	7.2	90	2		2.00000
176	BULLARD SUB, Fresno	Distribution	Unattended	115	21	7.2	45	1		1.00000
177	BURLINGAME SUB, Burlingame	Distribution	Unattended	115	21	7.2	30	1		1.00000
178	BUTTE SUB, Chico	Transmission	Unattended	115	12	7.2	46	2		2.00000
179	CABRILLO SUB, LOMPOC	Distribution	Unattended	115	12	7.2	11	1		1.00000
180	CADET SUB, Maricopa	Distribution	Unattended	70	12		20	3		1.00000
181	CAL WATER SUB,	Distribution	Unattended	115	12	7.2	30	1		1.00000
182	CALAVERAS CEMENT SUB, San Andreas	Distribution	Unattended	60	12	7.2	15	3		1.00000
183	CALFLAX SUB, Huron	Distribution	Unattended	70	12	2.4	19	3		1.00000
184	CALIFORNIA AVE SUB, Fresno	Distribution	Unattended	115	12	7.2	135	3		3.00000
185	CALISTOGA SUB, Calistoga	Distribution	Unattended	60	12	7.2	21	3	1	1.00000
186	CALPELLA SUB, Calpella	Distribution	Unattended	115	12	7.2	16	1		1.00000
187	CAMDEN SUB, Riverdale	Distribution	Unattended	70	12	2.4	41	2		2.00000
188	CAMP EVERS SUB, Santa Cruz	Distribution	Unattended	115	21	7.2	90	2		2.00000
189	CAMPHORA SUB, Monterey	Distribution	Unattended	60	12	7.2	11	1		1.00000
190	CAMPHORA SUB, Monterey	Distribution	Unattended	60	4		6	3	1	1.00000
191	CANAL SUB, Los Banos	Distribution	Unattended	70	12	7.2	60	2		2.00000
192	CANTUA SUB, Cantua Creek	Distribution	Unattended	115	12		24	1		1.00000
193	CAPAY SUB, Orland	Distribution	Unattended	60	12	2.4	11	6		1.00000
194	CARBONA SUB, Tracy	Distribution	Unattended	60	12	7.2	37	3		2.00000
195	CARNATION SUB, Bakersfield	Distribution	Unattended	70	21	7.2	16	1		1.00000
196	CARNERAS SUB, Blackwells Corner	Distribution	Unattended	70	12	7.2	16	1		1.00000
197	CAROLANDS SUB, Hillsborough	Distribution	Unattended	60	4		14	2		2.00000
198	CARQUINEZ SUB, Vallejo	Distribution	Unattended	115	12	2.4	25	2		2.00000
199	CARUTHERS SUB, Fresno	Distribution	Unattended	70	12	2.4	50	4		2.00000
200	CASSIDY SUB, Madera	Distribution	Unattended	70	12	2.4	45	1		1.00000
201	CASTRO VALLEY SUB, Castro Valley	Distribution	Unattended	230	12		90	2		2.00000
202	CASTROVILLE SUB, Castroville	Distribution	Unattended	115	21	7.2	30	3	1	1.00000
203	CATLETT SUB, Pleasant Grove	Distribution	Unattended	60	12		39	4	1	2.00000
204	CAWELO B SUB, Famosa	Distribution	Unattended	70	4		11	1		1.00000
205	CAYETANO SUB, Danville	Distribution	Unattended	230	21	7.2	45	1		1.00000
206	CAYUCOS SUB, Cayucos	Distribution	Unattended	70	12	7.2	25	2		2.00000
207	CHANNEL SUB, Stockton	Distribution	Unattended	60	12		13	1		1.00000
208	CHARCA SUB, Wasco	Distribution	Unattended	115	12	7.2	41	2		2.00000
209	CHEROKEE SUB, Stockton	Distribution	Unattended	60	12	7.2	16	1		1.00000
210	CHICO A SUB, Chico	Distribution	Unattended	60	12	7.2	21	3	1	1.00000
211	CHICO B SUB, Chico	Distribution	Unattended	115	12	7.2	32	2		2.00000
212	CHOLAME SUB, Cholame/93431	Distribution	Unattended	70	12	2.4	13	1		1.00000
213	CHOLAME SUB, Cholame/93431	Distribution	Unattended	70	21	2.4	13	1		1.00000
214	CHOWCHILLA SUB, Chowchilla	Distribution	Unattended	115	12	7.2	61	2		2.00000
215	CLARK ROAD SUB, Paradise	Distribution	Unattended	60	12	2.4	11	3	1	1.00000
216	CLARKSVILLE SUB, Clarksville	Distribution	Unattended	115	21	7.2	135	3		3.00000
217	CLAY SUB, Ione	Distribution	Unattended	60	12	2.4	29	2		2.00000
218	CLAYTON SUB, Concord	Distribution	Unattended	115	21	7.2	135	3		3.00000
219	CLAYTON SUB, Concord	Distribution	Unattended	115	12	7.2	16	1		1.00000
220	CLEAR LAKE SUB, Finley	Distribution	Unattended	60	12	2.4	20	6	1	2.00000
221	CLOVERDALE SUB, Cloverdale	Distribution	Unattended	115	12	7.2	19	3	1	1.00000
222	CLOVIS SUB, Clovis	Distribution	Unattended	115	12	7.2	90	2		2.00000
223	CLOVIS SUB, Clovis	Distribution	Unattended	115	21	7.2	45	1		1.00000
224	COALINGA #1 SUB, Coalinga	Distribution	Unattended	70	12	7.2	27	2		2.00000
225	COALINGA #2 SUB, Coalinga	Distribution	Unattended	70	12	2.4	21	3		1.00000
226	COARSEGOLD SUB, Coursegold	Distribution	Unattended	115	21	7.2	61	2		2.00000
227	COLUMBUS SUB, Bakersfield	Distribution	Unattended	115	12	7.2	59	3		3.00000
228	COLUSA JUNCT SUB, Colusa	Distribution	Unattended	60	12	7.2	12	1		1.00000
229	COLUSA SUB, Colusa	Distribution	Unattended	60	12		21	6	1	2.00000
230	CONTRA COSTA SUBSTATION, Antioch	Transmission	Unattended	230	21	7.2	225	3		3.00000
231	CONTRA COSTA SUBSTATION, Antioch	Transmission	Unattended	115	21	6.6	42	3	1	1.00000
232	COPPERMINE SUB, Clovis	Distribution	Unattended	70	12	2.4	20	3	1	1.00000
233	COPUS SUB, Bakersfield	Distribution	Unattended	70	12		28	4		2.00000
234	CORCORAN SUB, Corcoran	Transmission	Unattended	115	12	7.2	46	2		2.00000
235	CORDELIA SUB, Cordelia	Distribution	Unattended	115	12	7.2	45	1		1.00000
236	CORDELIA SUB, Cordelia	Distribution	Unattended	60	12	2.4	13	3	2	1.00000
237	CORNING SUB, Corning	Distribution	Unattended	60	12	2.4	58	10	3	2.00000
238	CORONA SUB,	Distribution	Unattended	115	12	7.2	30	1		1.00000
239	CORRAL SUB, Bellota	Distribution	Unattended	60	12	7.2	43	2		2.00000
240	CORTINA SUB, Williams	Transmission	Unattended	115	12	7.2	7	1		1.00000
241	COTATI SUB, Cotati	Distribution	Unattended	60	12		29	6	1	2.00000
242	COTTLE SUB, Oakdale	Distribution	Unattended	230	17		130	3		3.00000
243	COTTONWOOD SUB, Cottonwood	Transmission	Unattended	115	12	7.2	75	2		2.00000
244	COUNTRY CLUB SUB, Stockton	Distribution	Unattended	60	12		35	3		3.00000
245	COUNTRY CLUB SUB, Stockton	Distribution	Unattended	60	4		7	1		1.00000
246	CRESSEY SUB, Merced	Distribution	Unattended	115	21		30	1		1.00000
247	CURTIS SUB, Sonora	Distribution	Unattended	115	18		90	2		2.00000
248	CUYAMA SUB, Cuyama	Distribution	Unattended	70	12		19	3	1	1.00000
249	CUYAMA SUB, Cuyama	Distribution	Unattended	70	21	7.2	16	3		1.00000
250	CYMRIC SUB, McKitrick	Distribution	Unattended	115	12	7.2	16	1		1.00000
251	DAIRYLAND SUB, Chowchilla	Distribution	Unattended	115	12	7.2	60	2		2.00000
252	DALY CITY SUB, Daly City	Distribution	Unattended	115	12	7.2	135	3		3.00000
253	DAVIS SUB, Davis	Distribution	Unattended	115	12	7.2	135	3		3.00000
254	DEEPWATER SUB, W. Sactramento	Distribution	Unattended	115	12	7.2	90	2		2.00000
255	DEL MAR SUB, Rocklin	Distribution	Unattended	60	21	7.2	75	2		2.00000
256	DEL MAR SUB, Rocklin	Distribution	Unattended	60	12	7.2	16	1		1.00000
257	DEL MONTE SUB, Monterey	Transmission	Unattended	115	21	7.2	75	2		2.00000
258	DERRICK SUB, Kettleman	Distribution	Unattended	70	12	2.4	14	1		1.00000
259	DESCHUTES SUB, Palo Cedro	Distribution	Unattended	60	12	7.2	43	2		2.00000
260	DIAMOND SPRINGS SUB, Placerville	Distribution	Unattended	115	12	7.2	61	2		2.00000
261	DINUBA SUB, Dinuba	Distribution	Unattended	70	12	7.2	60	2		2.00000
262	DIVIDE SUB, Orcutt	Transmission	Unattended	70	12	2.4	11	3	1	1.00000
263	DIVIDE SUB, Orcutt	Transmission	Unattended	115	12	7.2	30	1		1.00000
264	DIXON LANDING SUB,	Distribution	Unattended	115	21	7.2	135	3		3.00000
265	DIXON SUB, Dixon	Distribution	Unattended	60	12		75	2		2.00000
266	DOLAN ROAD SUB, Moss Landing	Distribution	Unattended	115	12		11	1		1.00000
267	DOS PALOS SUB, Dos Palos	Distribution	Unattended	70	12	7.2	13	1		1.00000
268	DUMBARTON SUB, Fremont	Distribution	Unattended	115	12		105	3		3.00000
269	DUNBAR SUB, Glen Ellen	Distribution	Unattended	60	12		32	6	1	2.00000
270	EAST GRAND SUB, So San Fran.	Distribution	Unattended	115	12	7.2	180	4		4.00000
271	EAST MARYSVILLE SUB, Marysville,	Distribution	Unattended	115	12	7.2	25	2	1	2.00000
272	EAST NICOLAUS SUB, E. Nicolaus	Transmission	Unattended	115	12		16	1		1.00000
273	EAST STOCKTON SUB, Stockton	Distribution	Unattended	60	12	7.2	16	1		1.00000
274	EAST STOCKTON SUB, Stockton	Distribution	Unattended	60	4		8	1		1.00000
275	EDENVALE SUB, San Jose	Distribution	Unattended	115	21	7.2	135	3		3.00000
276	EDENVALE SUB, San Jose	Distribution	Unattended	115	12	7.2	45	1		1.00000
277	EDES SUB, Oakland	Distribution	Unattended	115	12	7.2	90	2		2.00000
278	EEL RIVER SUB, Ferndale	Distribution	Unattended	60	12	7.2	25	4		2.00000
279	EIGHT MILE SUB, Stockton	Distribution	Unattended	230	21	7.2	90	2		2.00000
280	EL CAPITAN SUB, Snelling	Distribution	Unattended	115	12		63	2		2.00000
281	EL CAPITAN SUB, Snelling	Distribution	Unattended	115	21		45	1		1.00000
282	EL CERRITO G SUB, El Cerrito	Distribution	Unattended	115	12		127	3		3.00000
283	EL NIDO SUB, Merced	Distribution	Unattended	115	12	7.2	32	2		2.00000
284	EL PATIO SUB, Campbell	Distribution	Unattended	115	12	7.2	180	4		4.00000
285	EL PECO SUB, Madera	Distribution	Unattended	70	12		23	2		2.00000
286	ELECTRA SUB,	Distribution	Unattended	60	12		11	1		1.00000
287	ELK HILLS SUB, Valley Acres	Distribution	Unattended	70	12		13	1		1.00000
288	ELK SUB, Elk	Distribution	Unattended	60	12	2.4	11	3	1	1.00000
289	EUREKA A SUB, Eureka	Distribution	Unattended	60	12	7.2	13	1		1.00000
290	EUREKA E SUB, Eureka	Distribution	Unattended	60	12		21	3	1	1.00000
291	EVERGREEN SUB, San Jose	Transmission	Unattended	115	21	7.2	90	2	1	2.00000
292	FAIRHAVEN SUB, Fairhaven	Distribution	Unattended	60	12	7.2	13	1		1.00000
293	FAIRVIEW SUB, Martinez	Distribution	Unattended	115	21	12	50	3		1.00000
294	FAIRWAY SUB, Santa Maria	Distribution	Unattended	115	12	7.2	60	2		2.00000
295	FAMOSO SUB, Famosa	Distribution	Unattended	115	12		30	1		1.00000
296	FELLOWS SUB, Fellows	Distribution	Unattended	115	21		60	2		2.00000
297	FIGARDEN SUB, Fresno	Distribution	Unattended	230	21	7.2	225	3		3.00000
298	FIREBAUGH SUB, Firebaugh	Distribution	Unattended	70	12	7.2	30	1		1.00000
299	FITCH MOUNTAIN SUB, Healdsburg	Distribution	Unattended	60	12	7.2	22	2		2.00000
300	FLINT SUB, Auburn	Distribution	Unattended	115	12	7.2	25	3		1.00000
301	FMC SUB, San Jose	Distribution	Unattended	115	12	7.2	50	2		2.00000
302	FOOTHILL SUB, SLO	Distribution	Unattended	115	12	2.4	11	1		1.00000
303	FORESTHILL SUB, Foresthill,	Distribution	Unattended	60	12	7.2	21	3	1	1.00000
304	FORT BRAGG A SUB, Fort Bragg	Distribution	Unattended	60	12		60	2		2.00000
305	FORT ORD SUB, Fort Ord	Distribution	Unattended	60	21	7.2	45	1		1.00000
306	FORT ORD SUB, Fort Ord	Distribution	Unattended	60	12	2.4	19	3	1	1.00000
307	FRANKLIN SUB, Hercules	Distribution	Unattended	60	12	7.2	60	2		2.00000
308	FREMONT SUB, Fremont	Distribution	Unattended	115	12	7.2	105	3		3.00000
309	FRENCH CAMP SUB, Stockton	Distribution	Unattended	60	12		32	2		2.00000
310	FROGTOWN SUB, Angels Camp	Distribution	Unattended	115	17		25	4		2.00000
311	FRUITVALE SUB, Bakersfield	Distribution	Unattended	70	12	2.4	49	4	1	2.00000
312	FULTON SUB, Fulton	Transmission	Unattended	230	12	7.2	60	2		2.00000
313	GABILAN SUB, Salinas	Distribution	Unattended	115	12	7.2	16	1		1.00000
314	GALLO SUB, Livingston	Distribution	Unattended	115	12		25	1		1.00000
315	GANSNER SUB, Quincy	Distribution	Unattended	60	12	7.2	13	1		1.00000
316	GANSO SUB, Buttonwillow	Distribution	Unattended	115	12	7.2	16	1		1.00000
317	GARBERVILLE SUB, Garberville	Distribution	Unattended	60	12	7.2	21	3	1	SVC	1	15
318	GATES SUB, Huron	Transmission	Unattended	230	12	7.2	45	1		1.00000
319	GATES SUB, Huron	Transmission	Unattended	115	12		19	3		1.00000
320	GEYSERVILLE SUB, Geyserville	Distribution	Unattended	60	12	2.4	22	4		2.00000
321	GIFFEN SUB, San Joaquin	Distribution	Unattended	70	12	2.4	19	3		1.00000
322	GIRVAN SUB, Redding	Distribution	Unattended	60	12	7.2	16	1		1.00000
323	GLENN SUB, Orland	Transmission	Unattended	60	12		30	1		1.00000
324	GLENWOOD SUB, Menlo Park	Distribution	Unattended	60	12	7.2	32	2		2.00000
325	GLENWOOD SUB, Menlo Park	Distribution	Unattended	60	4		7	1		1.00000
326	GOLDTREE SUB, SLO	Distribution	Unattended	115	12	7.2	16	1		1.00000
327	GONZALES SUB, Gonzales	Distribution	Unattended	60	12		22	2		2.00000
328	GOOSE LAKE SUB, Wasco	Distribution	Unattended	115	12	7.2	27	2		2.00000
329	GRAND ISLAND SUB, Ryde	Distribution	Unattended	115	21	7.2	81	3		3.00000
330	GRANT SUB, San Lorenzo	Distribution	Unattended	115	12	7.2	90	2		2.00000
331	GRASS VALLEY SUB, Grass Valley	Distribution	Unattended	60	12		19	3	1	1.00000
332	GREEN VALLEY SUB, Watsonville	Transmission	Unattended	115	21	7.2	60	2		2.00000
333	GREENBRAE SUB, Larkspur	Distribution	Unattended	60	12	7.2	32	2		2.00000
334	GUALALA SUB, Gualala	Distribution	Unattended	60	12	2.4	12	7	1	2.00000
335	GUERNSEY SUB, Hanford	Distribution	Unattended	70	12		60	2		2.00000
336	GUSTINE SUB, Gustine	Distribution	Unattended	60	12	7.2	21	3		3.00000
337	HALF MOON BAY SUB, Half Moon Bay	Distribution	Unattended	60	12	2.4	50	5		3.00000
338	HAMMER SUB, Stockton	Distribution	Unattended	60	12	7.2	90	3		3.00000
339	HAMMONDS SUB, Fresno	Distribution	Unattended	115	12		16	1		1.00000
340	HARDING SUB, Stockton	Distribution	Unattended	60	4		13	2		2.00000
341	HARDWICK SUB, Layton	Distribution	Unattended	70	12	7.2	12	1		1.00000
342	HARRIS SUB, Eureka	Distribution	Unattended	60	12	7.2	29	2		2.00000
343	HARTER SUB, Yuba City	Distribution	Unattended	60	12	7.2	60	2		2.00000
344	HARTLEY SUB, Lakeport	Distribution	Unattended	60	12	7.2	19	2		2.00000
345	HATTON SUB, Carmel Valley	Distribution	Unattended	60	12	2.4	16	3		1.00000
346	HENRIETTA SUB, Lemoore	Transmission	Unattended	70	12	2.4	46	2		2.00000
347	HERDLYN SUB, Tracy	Transmission	Unattended	60	12	2.4	13	1		1.00000
348	HICKS SUB, San Jose	Distribution	Unattended	230	21	7.2	150	2		2.00000
349	HICKS SUB, San Jose	Distribution	Unattended	230	12	7.2	90	2		2.00000
350	HIGGINS SUB, Higgins Corner	Distribution	Unattended	115	12	7.2	77	3		3.00000
351	HIGHLANDS SUB, Clear Lake	Distribution	Unattended	115	12	7.2	60	2		2.00000
352	HIGHWAY SUB, Petaluma	Distribution	Unattended	115	12	7.2	90	2		2.00000
353	HOLLISTER SUB, Hollister	Distribution	Unattended	115	21	7.2	70	2		2.00000
354	HOLLISTER SUB, Hollister	Distribution	Unattended	60	21		25	1		1.00000
355	HONCUT SUB, Honcut	Distribution	Unattended	115	12	7.2	16	1		1.00000
356	HOPLAND SUB, Hopland	Transmission	Unattended	60	12	2.4	13	3	1	1.00000
357	HORSESHOE SUB, Granite Bay	Distribution	Unattended	115	12	7.2	90	2		2.00000
358	HOWLAND ROAD SUB, Manteca	Distribution	Unattended	115	12	7.2	16	1		1.00000
359	HUMBOLDT BAY PP SUB, Eureka	Distribution	Unattended	60	13.8		133	6		2.00000
360	HUMBOLDT BAY PP SUB, Eureka	Distribution	Unattended	115	13.8		77	3		2.00000
361	HUMBOLDT BAY PP SUB, Eureka	Distribution	Unattended	60	12	7.2	11	1		1.00000
362	HUMBOLDT BAY PP SUB, Eureka	Distribution	Unattended	60	2		4	1		1.00000
363	HUMBOLDT BAY PP SUB, Eureka	Distribution	Unattended	115	2		4	1		1.00000
364	HURON SUB, Huron	Distribution	Unattended	70	12	2.4	20	3		1.00000
365	IGNACIO SUB, Ignacio	Transmission	Unattended	115	12		46	2		2.00000
366	IMHOFF SUB, Martinez	Distribution	Unattended	115	12	7.2	16	1		1.00000
367	IONE SUB, Ione	Distribution	Unattended	60	12	7.2	13	1		1.00000
368	JACINTO SUB, Willows	Distribution	Unattended	60	12	7.2	16	1		1.00000
369	JACOBS CORNER SUB, Lemoore	Distribution	Unattended	70	12	2.4	29	2		2.00000
370	JAMESON SUB, CORDELIA	Distribution	Unattended	115	12	7.2	90	2		2.00000
371	JANES CREEK SUB, Arcata	Distribution	Unattended	60	12	7.2	39	2		2.00000
372	JARVIS SUB, Union City	Distribution	Unattended	115	12	7.2	105	3		3.00000
373	JESSUP SUB, Anderson	Distribution	Unattended	115	12		22	1		1.00000
374	JOLON SUB, King City	Distribution	Unattended	60	12		27	2		2.00000
375	KELSO SUB, Tracy	Distribution	Unattended	230	12		30	1		1.00000
376	KERMAN SUB, Kerman	Distribution	Unattended	70	12	7.2	60	2		2.00000
377	KERN OIL SUB, Bakersfield	Distribution	Unattended	115	12	7.2	135	3		3.00000
378	KERN PP DIST SUB, Bakersfield	Distribution	Unattended	115	21	7.2	90	2		2.00000
379	KESWICK SUB, Keswick	Distribution	Unattended	60	12	2.4	11	3	1	1.00000
380	KETTLEMAN HILLS SUB, Kettleman	Distribution	Unattended	70	12	2.4	11	3		1.00000
381	KING CITY SUB, King City	Distribution	Unattended	60	12		47	3		3.00000
382	KINGSBURG SUB, Kingsburg	Transmission	Unattended	115	12	7.2	90	2		2.00000
383	KIRKER SUB, Pittsburg	Distribution	Unattended	115	21	7.2	135	3		3.00000
384	KONOCTI SUB, Clear Lake	Distribution	Unattended	60	12	2.4	23	2		2.00000
385	LAKEVIEW SUB, Bakersfield	Distribution	Unattended	70	12	2.4	49	4		2.00000
386	LAKEVILLE SUB, Petaluma	Transmission	Unattended	115	12	7.2	75	2		2.00000
387	LAKEWOOD SUB, Walnut Creek	Distribution	Unattended	115	21	7.2	215	4		4.00000
388	LAKEWOOD SUB, Walnut Creek	Distribution	Unattended	115	12	7.2	25	3	1	1.00000
389	LAMMERS SUB, TRACY	Distribution	Unattended	115	12	7.2	90	2		2.00000
390	LAMONT SUB, Bakersfield	Distribution	Unattended	115	12		75	2		2.00000
391	LAS GALLINAS A SUB, Las Gallinas	Distribution	Unattended	115	12	7.2	76	3		3.00000
392	LAS PALMAS SUB, Fresno	Distribution	Unattended	115	12	7.2	30	1		1.00000
393	LAS POSITAS SUB, Livermore	Transmission	Unattended	230	21	7.2	165	3		3.00000
394	LAS PULGAS SUB, Redwood City	Distribution	Unattended	60	4	2.4	14	2		2.00000
395	LAWRENCE SUB, Sunnyvale	Distribution	Unattended	115	12	7.2	145	5	1	3.00000
396	LE GRAND SUB, Le Grand	Distribution	Unattended	115	12	7.2	45	1		1.00000
397	LEMOORE SUB, Armonia	Distribution	Unattended	70	12	2.4	75	2		2.00000
398	LERDO SUB, Bakersfield	Distribution	Unattended	115	12	7.2	90	2		2.00000
399	LINCOLN SUB, Lincoln	Distribution	Unattended	115	12	7.2	91	3		3.00000
400	LINDEN SUB, Linden	Distribution	Unattended	60	12	2.4	19	3		1.00000
401	LIVE OAK SUB, Live Oak	Distribution	Unattended	60	12		27	2		2.00000
402	LIVERMORE SUB, Livermore	Distribution	Unattended	60	12	2.4	25	6		2.00000
403	LIVINGSTON SUB, Livingston	Distribution	Unattended	115	12	7.2	45	1		1.00000
404	LIVINGSTON SUB, Livingston	Distribution	Unattended	70	12		11	3		1.00000
405	LLAGAS SUB, Gilroy	Distribution	Unattended	115	21	12	100	3		3.00000
406	LOCKEFORD SUB, Lockeford	Transmission	Unattended	115	21	7.2	30	1	1	1.00000
407	LOCKHEED #1 SUB, Sunnyvale	Distribution	Unattended	115	12	7.2	90	2		2.00000
408	LOCKHEED #2 SUB, Sunnyvale	Distribution	Unattended	115	12		46	2		2.00000
409	LODI SUB, Lodi	Distribution	Unattended	60	12	2.4	21	3	1	1.00000
410	LODI SUB, Lodi	Distribution	Unattended	60	4		5	3	1	1.00000
411	LOGAN CREEK SUB, Willows	Distribution	Unattended	230	21		45	1		1.00000
412	LONETREE SUB, Antioch	Distribution	Unattended	230	21	7.2	45	1		1.00000
413	LOS ALTOS SUB, Los Altos	Distribution	Unattended	60	12		51	3		3.00000
414	LOS COCHES SUB, Greenfield	Distribution	Unattended	60	12		13	3	1	1.00000
415	LOS GATOS SUB, Los Gatos	Distribution	Unattended	60	12	7.2	32	2		2.00000
416	LOS MOLINOS SUB, Los Molinos	Distribution	Unattended	60	12	7.2	13	3	1	1.00000
417	LOS OSITOS SUB, Monterey	Distribution	Unattended	60	21	7.2	43	2		2.00000
418	LOYOLA SUB, Loyola	Distribution	Unattended	60	12	7.2	21	3	1	1.00000
419	LOYOLA SUB, Loyola	Distribution	Unattended	60	4	2.4	5	3	1	1.00000
420	LUCERNE SUB, Lucerne	Distribution	Unattended	115	12	7.2	29	2		2.00000
421	MABURY SUB, San Jose	Distribution	Unattended	60	12	2.4	19	3		1.00000
422	MABURY SUB, San Jose	Distribution	Unattended	60	12	7.2	45	1		1.00000
423	MADERA SUB, Madera	Distribution	Unattended	70	12		71	7		3.00000
424	MADISON SUB, Madison	Distribution	Unattended	60	12	7.2	30	1		1.00000
425	MADISON SUB, Madison	Distribution	Unattended	115	12		21	2		2.00000
426	MAGUNDEN SUB, Bakersfield	Distribution	Unattended	115	12	7.2	45	1		1.00000
427	MAGUNDEN SUB, Bakersfield	Distribution	Unattended	115	21	7.2	45	1		1.00000
428	MALAGA SUB, Fresno	Distribution	Unattended	115	12	7.2	105	3		3.00000
429	MANCHESTER SUB, Fresno	Distribution	Unattended	115	12	7.2	135	3		3.00000
430	MANTECA SUB, Manteca	Transmission	Unattended	115	17		135	8	1	4.00000
431	MARICOPA SUB, Maricopa	Distribution	Unattended	70	12	2.4	11	3		1.00000
432	MARIPOSA SUB, Mariposa	Distribution	Unattended	70	21		32	2		2.00000
433	MARTELL SUB, Martell	Distribution	Unattended	60	12	2.4	13	3	1	1.00000
434	MARYSVILLE SUB, Marysville	Distribution	Unattended	60	12		49	4	1	2.00000
435	MAXWELL SUB, Maxwell	Distribution	Unattended	60	12		43	4	1	2.00000
436	MCARTHUR SUB, McArthur	Distribution	Unattended	60	12	2.4	11	3	1	1.00000
437	MCCALL SUB, Selma	Transmission	Unattended	115	12	7.2	90	2		2.00000
438	MCDONALD-MCDONALDISLAND SUB, Stockton	Distribution	Unattended	60	4	2.4	21	2		2.00000
439	MCFARLAND SUB, McFarland	Distribution	Unattended	70	12	7.2	32	2		2.00000
440	MCKEE SUB, San Jose	Distribution	Unattended	115	12	7.2	105	3		3.00000
441	MCKITTRICK SUB, MCKITTRICK	Distribution	Unattended	70	12		13	4	1	1.00000
442	MCMULLIN SUB, Fresno	Distribution	Unattended	230	12	7.2	45	1		1.00000
443	MEADOW LANE SUB, Concord	Distribution	Unattended	115	21	7.2	170	3		3.00000
444	MENDOCINO SUB, Redwood Valley	Transmission	Unattended	60	12	2.4	5	3	1	1.00000
445	MENDOTA SUB, Mendota	Transmission	Unattended	115	12	7.2	30	1		1.00000
446	MENLO SUB, Menlo Park	Distribution	Unattended	60	12	7.2	32	2		2.00000
447	MENLO SUB, Menlo Park	Distribution	Unattended	60	4		18	2		2.00000
448	MERCED SUB, Merced	Transmission	Unattended	115	12	7.2	45	1		1.00000
449	MERCED SUB, Merced	Transmission	Unattended	115	21	7.2	45	1		1.00000
450	MERIDIAN SUB, Meridian	Distribution	Unattended	60	12		21	3	1	1.00000
451	MESA SUB, Nipomo	Transmission	Unattended	230	12		45	1		1.00000
452	METTLER SUB, Stockton	Distribution	Unattended	60	12		11	1		1.00000
453	MIDDLETOWN SUB, Middletown	Distribution	Unattended	60	12	7.2	34	4	1	2.00000
454	MIDWAY SUB, Buttonwillow	Transmission	Unattended	115	12	7.2	23	2		2.00000
455	MILLBRAE SUB, Millbrae	Transmission	Unattended	115	12		60	2		2.00000
456	MILLBRAE SUB, Millbrae	Transmission	Unattended	60	4		6	3	1	1.00000
457	MILPITAS SUB, Milpitas	Distribution	Unattended	115	21	7.2	90	2		2.00000
458	MILPITAS SUB, Milpitas	Distribution	Unattended	115	12	7.2	75	2		2.00000
459	MIRABEL SUB, Forestville	Distribution	Unattended	60	12		11	1		1.00000
460	MI-WUK SUB, Sugarpine	Distribution	Unattended	115	17		14	3	1	1.00000
461	MOLINO SUB, Sebastopol	Distribution	Unattended	60	12	7.2	43	2		2.00000
462	MONROE SUB, Santa Rosa	Distribution	Unattended	115	21	7.2	90	2		2.00000
463	MONROE SUB, Santa Rosa	Distribution	Unattended	115	12	7.2	45	1		1.00000
464	MONTAGUE SUB, San Jose	Distribution	Unattended	115	21	7.2	135	3		3.00000
465	MONTE RIO SUB, Monte Rio	Distribution	Unattended	60	12	7.2	29	2		2.00000
466	MONTEREY SUB, Monterey	Distribution	Unattended	60	4		11	3	1	1.00000
467	MORAGA SUB, Orinda	Transmission	Unattended	115	12		45	1		1.00000
468	MORGAN HILL SUB, Morgan Hill	Distribution	Unattended	115	21	7.2	120	3		3.00000
469	MORMON SUB, Stockton	Distribution	Unattended	60	12	7.2	30	1		1.00000
470	MORRO BAY PP SWYD, Morro Bay	Transmission	Unattended	115	12	7.2	16	1		1.00000
471	MOSHER SUB, Stockton	Distribution	Unattended	60	21	7.2	105	3		3.00000
472	MOUNTAIN VIEW SUB, Mt. View	Distribution	Unattended	115	12	7.2	115	3		2.00000
473	MT. EDEN SUB, Hayward	Distribution	Unattended	115	12	7.2	135	3		2.00000
474	MT. QUARRIES SUB, Cool	Distribution	Unattended	60	12	7.2	16	1		1.00000
475	NAPA SUB, Napa	Distribution	Unattended	60	12		79	5		3.00000
476	NARROWS SUB,	Distribution	Unattended	60	21	7.2	30	1		1.00000
477	NEWARK DIST SUB, Fremont	Distribution	Unattended	230	21	7.2	150	2		2.00000
478	NEWARK SUB, Fremont	Transmission	Unattended	115	12	7.2	90	2		2.00000
479	NEWBURG SUB, Fortuna	Distribution	Unattended	60	12	2.4	20	4	1	2.00000
480	NEWHALL SUB, Firebaugh	Distribution	Unattended	115	12	7.2	29	2		2.00000
481	NEWMAN SUB, Newman	Distribution	Unattended	60	12	7.2	41	4		2.00000
482	NORCO SUB, Bakersfield	Distribution	Unattended	115	12	7.2	16	1		1.00000
483	NORD SUB, Chico	Distribution	Unattended	115	12	7.2	32	2		2.00000
484	NORTECH SUB, San Jose	Distribution	Unattended	115	21	7.2	90	2		2.00000
485	NORTH DUBLIN SUB, Pleasanton	Distribution	Unattended	230	21	12	45	1		1.00000
486	NORTH TOWER SUB, Vallejo	Distribution	Unattended	115	12	7.2	90	2		2.00000
487	NOTRE DAME SUB, Chico	Distribution	Unattended	115	12	7.2	45	1		1.00000
488	NOVATO SUB, Novato	Distribution	Unattended	60	12	7.2	23	2		2.00000
489	OAKHURST SUB, Oakhurst	Distribution	Unattended	115	12	2.4	43	3		2.00000
490	OAKLAND C (OAKLAND PP) SUB, Oakland	Distribution	Unattended	115	12	7.2	195	4		4.00000
491	OAKLAND D SUB, Oakland	Distribution	Unattended	115	12	7.2	175	4		4.00000
492	OAKLAND J SUB, Oakland	Distribution	Unattended	115	12	7.2	120	3		3.00000
493	OAKLAND K (CLAREMONT) SUB, Oakland	Distribution	Unattended	115	12	6.6	38	3	1	1.00000
494	OAKLAND L SUB, Oakland	Distribution	Unattended	115	12	7.2	135	3		3.00000
495	OAKLAND X SUB, Oakland	Distribution	Unattended	115	12	7.2	90	3		3.00000
496	OCEANO SUB, Oceano	Distribution	Unattended	115	12	7.2	75	2		2.00000
497	OILFIELDS SUB, San Ardo	Distribution	Unattended	60	12		42	6	1	2.00000
498	OLD KEARNEY SUB, Fresno	Distribution	Unattended	70	12	13.2	31	4		2.00000
499	OLD RIVER SUB, Knob Hill	Distribution	Unattended	70	12	2.4	16	1		1.00000
500	OLD RIVER SUB, Knob Hill	Distribution	Unattended	70	12	7.2	45	1		1.00000
501	OLETA SUB, Plymouth	Distribution	Unattended	60	12	2.4	18	4		2.00000
502	OLIVEHURST SUB, Olivehurst	Distribution	Unattended	115	12	7.2	60	2		2.00000
503	OREGON TRAIL SUB, Redding	Distribution	Unattended	115	12	7.2	16	1		1.00000
504	OREGON TRAIL SUB, Redding	Distribution	Unattended	60	12	2.4	6	3		1.00000
505	ORLAND B SUB, Orland	Distribution	Unattended	60	12	2.4	25	7		2.00000
506	ORO FINO SUB, Magalia	Distribution	Unattended	60	12	2.4	11	1		1.00000
507	ORO LOMA SUB, Dos Palos	Transmission	Unattended	70	12	2.4	22	3		1.00000
508	ORO LOMA SUB, Dos Palos	Transmission	Unattended	115	12		45	1		1.00000
509	OROSI SUB, Orosi	Distribution	Unattended	70	12	7.2	41	2		2.00000
510	OROVILLE SUB, Oroville	Distribution	Unattended	60	12	7.2	25	2		2.00000
511	OROVILLE SUB, Oroville	Distribution	Unattended	60	4	2.4	5	3	1	1.00000
512	ORTIGA SUB, Los Banos	Distribution	Unattended	70	12	2.4	16	1		1.00000
513	PACIFICA SUB, Pacifica	Distribution	Unattended	60	12		23	2		2.00000
514	PALMER SUB, Sisquat	Distribution	Unattended	115	12	7.2	11	1		1.00000
515	PANAMA SUB, Bakersfield	Distribution	Unattended	70	21	7.2	45	1		1.00000
516	PANOCHE SUB, Mendota	Transmission	Unattended	230	12	7.2	30	1		1.00000
517	PANORAMA SUB, Anderson	Distribution	Unattended	115	12		30	1		1.00000
518	PARADISE SUB, Paradise	Distribution	Unattended	60	12	7.2	45	1		1.00000
519	PARADISE SUB, Paradise	Distribution	Unattended	115	12		45	1		1.00000
520	PARKWAY SUB, Vallejo	Distribution	Unattended	230	12	7.2	30	1		1.00000
521	PARLIER SUB, Parlier	Distribution	Unattended	115	12	7.2	45	1		1.00000
522	PASO ROBLES SUB, Paso Robles	Distribution	Unattended	70	12	2.4	90	3		3.00000
523	PAUL SWEET SUB, Santa Cruz	Distribution	Unattended	115	21	7.2	135	3		SVC	1	60
524	PEABODY SUB, Fairfield	Distribution	Unattended	230	21	7.2	195	3		3.00000
525	PEACHTON SUB, Gridley	Distribution	Unattended	60	12	2.4	14	6	1	2.00000
526	PEASE SUB, Tierra Buena	Transmission	Unattended	115	12		50	2		2.00000
527	PENNGROVE SUB, Penngrove	Distribution	Unattended	115	12		13	1		1.00000
528	PENRYN SUB, Penryn	Distribution	Unattended	60	12	7.2	61	2		2.00000
529	PEORIA SUB, Jamestown	Distribution	Unattended	115	18		58	4		2.00000
530	PETALUMA C SUB, Petaluma	Distribution	Unattended	60	12		57	5	1	3.00000
531	PIERCY SUB, San Jose	Distribution	Unattended	115	21	7.2	45	1		1.00000
532	PINE GROVE SUB, Pine Grove	Distribution	Unattended	60	12	2.4	22	4		2.00000
533	PINEDALE SUB, FRESNO	Distribution	Unattended	115	21	7.2	135	3		3.00000
534	PLACER SUB, Auburn	Transmission	Unattended	115	12		41	4	1	2.00000
535	PLACERVILLE SUB, Placerville	Distribution	Unattended	115	12	7.2	30	1		1.00000
536	PLACERVILLE SUB, Placerville	Distribution	Unattended	115	21		30	1		1.00000
537	PLAINFIELD SUB, Davis	Distribution	Unattended	60	12	2.4	39	2		2.00000
538	PLEASANT GROVE SUB, Pleasant Grove	Distribution	Unattended	60	21	7.2	135	3		3.00000
539	PLUMAS SUB, Wheatland	Distribution	Unattended	60	21	7.2	45	1		1.00000
540	PLUMAS SUB, Wheatland	Distribution	Unattended	60	12	7.2	13	1		1.00000
541	POINT MORETTI SUB, Davenport	Distribution	Unattended	60	12	2.4	11	1		1.00000
542	POINT PINOLE SUB, Richmond	Distribution	Unattended	115	12	6.6	16	1		1.00000
543	POSO MOUNTAIN SUB, Kern	Distribution	Unattended	115	21		65	2		1.00000
544	PRUNEDALE SUB, Prunedale	Distribution	Unattended	115	12	7.2	32	2		2.00000
545	PUEBLO SUB, Napa	Distribution	Unattended	115	12		45	1		StatCom	2	8
546	PUEBLO SUB, Napa	Distribution	Unattended	115	21		45	1		1.00000
547	PURISIMA SUB, Lompoc	Distribution	Unattended	115	12	7.2	11	1		1.00000
548	PUTAH CREEK SUB, Winters	Distribution	Unattended	115	12		32	2		2.00000
549	RACE TRACK SUB, Jamestown	Distribution	Unattended	115	17		16	1		1.00000
550	RADUM SUB, Pleasanton	Distribution	Unattended	60	12		25	6		2.00000
551	RAINBOW SUB, Sanger	Distribution	Unattended	115	12	7.2	30	1		1.00000
552	RALSTON SUB, Belmont	Distribution	Unattended	60	12		16	4		2.00000
553	RANCHERS COTTON SUB, Fresno	Distribution	Unattended	115	12	7.2	16	1		1.00000
554	RAWSON SUB, Red Bluff	Distribution	Unattended	60	12	2.4	19	3		1.00000
555	RED BLUFF SUB, Red Bluff	Distribution	Unattended	60	12	2.4	50	5		3.00000
556	REDBUD SUB, Clearlake Oaks	Distribution	Unattended	115	12	7.2	23	3		2.00000
557	REDWOOD CITY SUB, Redwood City	Distribution	Unattended	60	12	7.2	70	5		3.00000
558	REDWOOD CITY SUB, Redwood City	Distribution	Unattended	60	4		14	3		1.00000
559	REEDLEY SUB, Reedley	Transmission	Unattended	115	12	7.2	30	1		1.00000
560	REEDLEY SUB, Reedley	Transmission	Unattended	70	12	2.4	30	1		1.00000
561	RENFRO SUB, BAKERSFIELD	Distribution	Unattended	115	12	7.2	90	2		2.00000
562	RESEARCH SUB, San Ramon	Distribution	Unattended	230	21	7.2	45	1		1.00000
563	RESERVATION ROAD SUB, Salinas	Distribution	Unattended	60	12	2.4	11	1		1.00000
564	RICE SUB, Princeton	Distribution	Unattended	60	12	4.16	14	2		2.00000
565	RICHMOND R SUB, Richmond	Distribution	Unattended	115	12	7.2	90	2		2.00000
566	RINCON SUB, Santa Rosa	Distribution	Unattended	115	12		32	2		2.00000
567	RIO BRAVO SUB, Shafter	Distribution	Unattended	115	12	7.2	64	4		2.00000
568	RIO DELL SUB, Rio Dell	Distribution	Unattended	60	12		11	3		1.00000
569	RIPON SUB, Ripon	Distribution	Unattended	115	17		73	2		2.00000
570	RISING RIVER SUB, Cassell,	Distribution	Unattended	60	12	2.4	11	3	1	1.00000
571	RIVER OAKS SUB, San Jose	Distribution	Unattended	115	21	7.2	90	2		2.00000
572	RIVERBANK SUB, Escalon	Distribution	Unattended	115	12		73	4	1	2.00000
573	ROB ROY SUB, Watsonville	Distribution	Unattended	115	21	7.2	23	1		1.00000
574	ROCKLIN SUB, Rocklin	Distribution	Unattended	60	12	7.2	27	4	1	2.00000
575	ROSEDALE SUB, Bakersfield	Distribution	Unattended	115	12	7.2	30	1		1.00000
576	ROSSMOOR SUB, Walnut Creek	Distribution	Unattended	230	12		90	2		2.00000
577	ROUGH & READY ISLAND SUB, Stockton	Distribution	Unattended	60	12	7.2	16	1		1.00000
578	SALINAS SUB, Salinas	Transmission	Unattended	115	12	7.2	90	2		2.00000
579	SALMON CREEK SUB, Bodega Bay	Distribution	Unattended	60	12	2.4	11	3	1	1.00000
580	SAN ARDO SUB, San Ardo	Distribution	Unattended	60	12		11	3	1	1.00000
581	SAN BENITO SUB, San Benito	Distribution	Unattended	115	21	7.2	30	1		1.00000
582	SAN BERNARD SUB, Lamont	Distribution	Unattended	70	12	2.4	19	3		1.00000
583	SAN CARLOS SUB, San Carlos	Distribution	Unattended	60	12	7.2	29	2		2.00000
584	SAN CARLOS SUB, San Carlos	Distribution	Unattended	60	4	2.4	12	3	1	1.00000
585	SAN FRAN A (POTRERO PP) SUB, San Francisco	Transmission	Unattended	115	12	7.2	186	3		3.00000
586	SAN FRAN H (MARTIN) SUB, Daly City	Transmission	Unattended	115	12		180	4		4.00000
587	SAN FRAN P-HUNTERS POINT SUB, San Francisco	Distribution	Unattended	115	12		98	2		2.00000
588	SAN FRAN X (MISSION) SUB, San Francisco	Distribution	Unattended	115	12	7.2	375	5		5.00000
589	SAN FRAN Y (LARKIN) SUB, San Francisco	Distribution	Unattended	115	12	7.2	450	6		6.00000
590	SAN FRAN Z (Embarcadero), San Francisco	Distribution	Unattended	230	34.5	7.2	345	3		3.00000
591	SAN JOAQUIN SUB, San Joaquin	Distribution	Unattended	70	12	7.2	18	2		2.00000
592	SAN JOSE A SUB, San Jose	Distribution	Unattended	115	4	7.2	40	2		3.00000
593	SAN JOSE A SUB, San Jose	Distribution	Unattended	115	12		30	1		1.00000
594	SAN JOSE B SUB, San Jose	Distribution	Unattended	115	12	7.2	180	4		2.00000
595	SAN LEANDRO U SUB, San Leandro	Distribution	Unattended	115	12		160	4		4.00000
596	SAN LUIS OBISPO SUB, SLO	Transmission	Unattended	115	12	7.2	135	3		3.00000
597	SAN MATEO SUB, San Mateo	Transmission	Unattended	115	21		45	1		1.00000
598	SAN MATEO SUB, San Mateo	Transmission	Unattended	60	4		13	3	1	1.00000
599	SAN MIGUEL SUB, San Miguel	Distribution	Unattended	70	12	7.2	16	1		1.00000
600	SAN PABLO SUB, Richmond	Distribution	Unattended	115	12	7.2	45	1		1.00000
601	SAN RAFAEL SUB, San Rafael	Distribution	Unattended	115	12		120	3		3.00000
602	SAN RAMON SUB, San Ramon	Transmission	Unattended	230	21	12	300	4		4.00000
603	SANGER SUB, Fresno	Transmission	Unattended	115	12	7.2	60	2		2.00000
604	SANTA MARIA SUB, Santa Maria	Distribution	Unattended	115	12	7.2	90	2		2.00000
605	SANTA NELLA SUB, Santa Nella	Distribution	Unattended	70	12	2.4	27	2		2.00000
606	SANTA RITA SUB, Dos Palos	Distribution	Unattended	70	12	2.4	12	3		1.00000
607	SANTA ROSA A SUB, Santa Rosa	Distribution	Unattended	115	12	7.2	135	3		3.00000
608	SANTA YNEZ SUB, Santa Maria	Distribution	Unattended	115	12	7.2	41	2		2.00000
609	SARATOGA SUB, Saratoga	Distribution	Unattended	230	12	7.2	157	3		3.00000
610	SAUSALITO SUB, Sausalito	Distribution	Unattended	60	12	2.4	21	3	1	1.00000
611	SAUSALITO SUB, Sausalito	Distribution	Unattended	60	4		5	3	1	1.00000
612	SCHINDLER SUB, Five Points	Transmission	Unattended	115	12	7.2	60	2		2.00000
613	SEMITROPIC SUB, Wasco	Transmission	Unattended	115	12	7.2	30	1		1.00000
614	SERRAMONTE SUB, Daly City	Distribution	Unattended	115	12		13	1		1.00000
615	SHAFTER SUB, Shafter	Distribution	Unattended	115	12	7.2	72	4	1	2.00000
616	SHARON SUB, Chowchilla	Distribution	Unattended	115	12		11	1		1.00000
617	SHEPARD SUB, Clovis	Distribution	Unattended	115	21	7.2	45	1		1.00000
618	SHINGLE SPRINGS SUB, Shingle Springs	Distribution	Unattended	115	21	7.2	61	2		2.00000
619	SHINGLE SPRINGS SUB, Shingle Springs	Distribution	Unattended	115	12	7.2	16	1		1.00000
620	SHREDDER SUB, Redwood City	Distribution	Unattended	115	4	6.6	15	3	1	1.00000
621	SILVERADO SUB, St. Helena	Distribution	Unattended	115	21		60	2		2.00000
622	SISQUOC SUB, Orcutt	Distribution	Unattended	115	12	7.2	32	2		2.00000
623	SMYRNA SUB, Wasco	Distribution	Unattended	115	12	7.2	49	4		2.00000
624	SNEATH LANE SUB, San Bruno	Distribution	Unattended	60	12	2.4	19	6		2.00000
625	SOBRANTE SUB, Orinda	Transmission	Unattended	115	12	7.2	30	1		1.00000
626	SOLEDAD SUB, Soledad	Transmission	Unattended	60	12		11	1		1.00000
627	SONOMA A SUB, Sonoma	Distribution	Unattended	115	12		60	2		2.00000
628	SOUTH BAY #1 & #2 SUB, Tracy	Distribution	Unattended	60	4		25	3		3.00000
629	SPANISH CREEK SUB,	Distribution	Unattended	60	44		19	1		1.00000
630	SPENCE SUB, Salinas	Distribution	Unattended	60	12		13	3	1	2.00000
631	SRI SUB, Menlo Park	Distribution	Unattended	60	12		13	1		1.00000
632	STAFFORD SUB, Novato	Distribution	Unattended	60	12		25	2		2.00000
633	STAGG SUB, Stockton	Transmission	Unattended	230	21	7.2	150	2		2.00000
634	STAGG SUB, Stockton	Transmission	Unattended	60	12	2.4	51	4	1	2.00000
635	STELLING SUB, Cupertino	Distribution	Unattended	115	12	7.2	105	3		2.00000
636	STILLWATER STA SUB, Project City	Distribution	Unattended	60	12	2.4	11	3	1	1.00000
637	STOCKDALE SUB, Bakersfield	Distribution	Unattended	230	21	7.2	225	3		3.00000
638	STOCKDALE SUB, Bakersfield	Distribution	Unattended	115	12	7.2	75	2		2.00000
639	STOCKTON A SUB, Stockton	Distribution	Unattended	115	12		105	3		3.00000
640	STOCKTON A SUB, Stockton	Distribution	Unattended	60	4		22	6		1.00000
641	STONE CORRAL SUB, Woodlake	Distribution	Unattended	70	12	2.4	17	2		2.00000
642	STONE SUB, San Jose	Distribution	Unattended	115	12	7.2	45	1		1.00000
643	STOREY SUB, Madera	Distribution	Unattended	230	12	7.2	90	2		2.00000
644	STROUD SUB, Helm	Distribution	Unattended	70	12	2.4	21	3	1	1.00000
645	SUISUN SUB, Fairfield	Distribution	Unattended	115	12	7.2	120	3		3.00000
646	SUNOL SUB, Sunol	Distribution	Unattended	60	12	7.2	13	1		1.00000
647	SWIFT SUB, San Jose	Distribution	Unattended	115	21	7.2	135	3		3.00000
648	SYCAMORE CREEK SUB, Chico	Distribution	Unattended	115	12		90	3		3.00000
649	TAFT SUB, Taft	Transmission	Unattended	115	12	7.2	27	2		2.00000
650	TAMARACK SUB, Soda Springs	Distribution	Unattended	60	12	7.2	13	1		1.00000
651	TASSAJARA SUB, Danville	Distribution	Unattended	230	21	7.2	225	3		3.00000
652	TEJON SUB, Leboc	Distribution	Unattended	70	12	2.4	49	4		2.00000
653	TEMBLOR SUB, McKittrick	Distribution	Unattended	115	12	2.4	21	3	1	1.00000
654	TEMPLETON SUB, TEMPLETON	Transmission	Unattended	230	21	7.2	90	2		2.00000
655	TEVIS SUB, Oildale	Distribution	Unattended	115	21	7.2	90	2		2.00000
656	TIDEWATER SUB, Martinez	Distribution	Unattended	230	21		150	2		2.00000
657	TIVY VALLEY SUB, Fresno	Distribution	Unattended	70	12	7.2	13	1		1.00000
658	TRACY SUB, Tracy	Distribution	Unattended	115	12	7.2	121	4		4.00000
659	TRES VIAS SUB, Oroville	Distribution	Unattended	60	12	7.2	16	1		1.00000
660	TRIMBLE SUB, San Jose	Distribution	Unattended	115	12	7.2	90	2		2.00000
661	TRIMBLE SUB, San Jose	Distribution	Unattended	115	21	7.2	90	2		2.00000
662	TULARE LAKE SUB, Kettleman	Distribution	Unattended	70	12	2.4	24	4	2	2.00000
663	TULUCAY SUB, Napa	Transmission	Unattended	60	12	7.2	30	1		1.00000
664	TUPMAN SUB, Tupman	Distribution	Unattended	115	12	7.2	61	2		2.00000
665	TWISSELMAN SUB, Blackwell Corners	Distribution	Unattended	70	12	7.2	32	2		2.00000
666	TYLER SUB, Red Bluff	Distribution	Unattended	60	12	2.4	19	6		2.00000
667	UKIAH SUB, Ukiah	Distribution	Unattended	115	12	7.2	29	2		2.00000
668	URICH SUB, Martinez	Distribution	Unattended	60	4		10	3	1	1.00000
669	VACA DIXON SUB, Vacaville	Transmission	Unattended	115	12	7.2	105	3		3.00000
670	VACAVILLE SUB, Vacaville	Distribution	Unattended	115	12	7.2	120	3		3.00000
671	VALLEY HOME SUB, Valley Home	Distribution	Unattended	60	17		6	3	1	1.00000
672	VALLEY HOME SUB, Valley Home	Distribution	Unattended	115	17		30	1		1.00000
673	VALLEY VIEW SUB, El Sobrante	Distribution	Unattended	115	12		29	2		2.00000
674	VASCO SUB, Livermore	Distribution	Unattended	60	12		17	6		2.00000
675	VASONA SUB, Los Gatos	Distribution	Unattended	230	12	7.2	90	2		4.00000
676	VICTOR SUB, Lodi	Distribution	Unattended	60	12	2.4	30	1		1.00000
677	VIEJO SUB, Monterey	Distribution	Unattended	60	21	7.2	60	2		2.00000
678	VIERRA SUB, Lathrop	Distribution	Unattended	115	17	7.2	90	2		2.00000
679	VINEYARD SUB, Pleasanton	Distribution	Unattended	230	21	7.2	150	2	1	2.00000
680	VOLTA #1PH SUB, Shingletown	Distribution	Unattended	60	12	2.4	21	3	1	1.00000
681	WAHTOKE SUB, Reedley	Distribution	Unattended	115	12	7.2	60	2		2.00000
682	WASCO SUB, Wasco	Distribution	Unattended	70	12	2.4	20	3		1.00000
683	WATERLOO SUB, Stockton	Distribution	Unattended	60	12	2.4	11	1		1.00000
684	WATSONVILLE SUB, Watsonville	Distribution	Unattended	60	12	7.2	16	1		1.00000
685	WATSONVILLE SUB, Watsonville	Distribution	Unattended	60	4		8	1		1.00000
686	WEBER SUB, Stockton	Transmission	Unattended	60	12	7.2	50	2		2.00000
687	WEBER SUB, Stockton	Transmission	Unattended	230	12	7.2	90	2		2.00000
688	WEEDPATCH SUB, Weedpatch	Distribution	Unattended	70	12	7.2	30	1		1.00000
689	WELLFIELD SUB, Lamont	Distribution	Unattended	70	12	2.4	24	4		2.00000
690	WEST FRESNO SUB, Fresno	Distribution	Unattended	115	12	7.2	135	3		3.00000
691	WEST LANE SUB, Stockton	Distribution	Unattended	60	12	7.2	30	1		1.00000
692	WEST SACRAMENTO SUB, WEST SACRAMENTO	Distribution	Unattended	115	12	7.2	105	3		3.00000
693	WESTLEY SUB, Westley	Distribution	Unattended	60	12	2.4	29	2		2.00000
694	WESTPARK SUB, Bakersfield	Distribution	Unattended	115	12	7.2	105	3		3.00000
695	WHEATLAND SUB, Wheatland	Distribution	Unattended	60	12	7.2	44	4	1	2.00000
696	WHEELER RIDGE SUB, Bakersfield	Transmission	Unattended	70	12	7.2	30	1		1.00000
697	WHISMAN SUB, Mt. View	Distribution	Unattended	115	12	7.2	105	3		3.00000
698	WILLIAMS SUB, Williams	Distribution	Unattended	60	12	7.2	27	2		2.00000
699	WILLITS A SUB, Willits	Distribution	Unattended	60	12	2.4	19	3	1	1.00000
700	WILLOW CREEK SUB, Willow Creek	Distribution	Unattended	60	12	2.4	13	3	1	1.00000
701	WILLOW PASS SUB, Pittsburg	Distribution	Unattended	115	21	7.2	30	1		1.00000
702	WILLOW PASS SUB, Pittsburg	Distribution	Unattended	60	12	2.4	11	3	1	1.00000
703	WILLOWS A SUB, Willows	Distribution	Unattended	60	12		14	3	1	1.00000
704	WILSON SUB, Merced	Transmission	Unattended	115	12		14	1		1.00000
705	WINDSOR SUB, Windsor	Distribution	Unattended	60	12		30	1		1.00000
706	WINTERS SUB, Winters	Distribution	Unattended	60	12		13	1		1.00000
707	WOLFE SUB, Cupertino	Distribution	Unattended	115	12		120	3		3.00000
708	WOODCHUCK SUB, Wilson Village	Distribution	Unattended	70	21		23	3		1.00000
709	WOODLAND SUB, Woodland	Distribution	Unattended	115	12	7.2	135	3		3.00000
710	WOODSIDE SUB, Woodside	Distribution	Unattended	60	12		60	2		2.00000
711	WOODWARD SUB, Fresno	Distribution	Unattended	115	21	7.2	135	3		3.00000
712	WRIGHT SUB, Los Banos	Distribution	Unattended	70	12	2.4	13	1		1.00000
713	WYANDOTTE SUB, Oroville	Distribution	Unattended	115	12	7.2	120	3		3.00000
714	ZACA SUB, Santa Maria	Distribution	Unattended	115	12	7.2	11	1		1.00000
715	ZAMORA SUB, Zamora	Distribution	Unattended	115	12		27	2		2.00000
716	Rounding issues in column f						57
717
718	Combined Dist Subs < 10MVA (129 substations)						675	331	54
719	Total Distribution and Transmission Substations			82,440	18,872.1	4,089.56	96,173	1,780	159		13	641
720	Transmission only Substations			24,120	10,990	1,342.2	64,915	359	57
721	Total						96,848

Name of Respondent:

PACIFIC GAS AND ELECTRIC COMPANY

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/16/2019

Year/Period of Report

End of:

2018

TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general". Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No.	Description of the Good or Service (a)	Name of Associated/Affiliated Company (b)	Account(s) Charged or Credited (c)	Amount Charged or Credited (d)
1	Non-power Goods or Services Provided by Affiliated
2	PG&E Corporation	PG&E Corporation	745	31,789
3	Corporate A&G Allocations	Eureka Energy Company	923, 426.4, 426.5	94,248,645
4	Administrative & General Expenses	Eureka Energy Company	532.0	94,248,645
5	Rent Expense	Eureka Energy Company	532.0	321,288
6	Non-power Goods/Srv.provided by Affilia	Eureka Energy Company	532.0	94,569,933
19
20	Non-power Goods or Services Provided for Affiliated
21	ADMINISTRATION	PG&E Corporation	930.2	278,634
22	ACCOUNTING	PG&E Corporation	930.1	536,406
23	ADMINISTRATION	PG&E Corporation	548.2	509,322
24	AFFILIATE RULES COMPLIANCE SUPPORT	PG&E Corporation	942.2	24,463
25	FOR AFFILIATES	PG&E Corporation	987.2	4,231,914
42

FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose

Who Must Submit

What and Where to Submit

When to Submit

Where to Send Comments on Public Reporting Burden.

GENERAL INSTRUCTIONS

EXCERPTS FROM THE LAW

GENERAL PENALTIES

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report