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WISHON-7 2018-12-31 C000388 1-31 2018-01-012018-12-31 C000388 4-24 2018-01-012018-12-31 C000388 14-24 2018-01-012018-12-31 C000388 2-25 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 0-9 2018-01-012018-12-31 C000388 0-41 2018-12-31 C000388 36-9 2018-01-012018-12-31 C000388 12-25 2018-01-012018-12-31 C000388 6-11 2018-01-012018-12-31 C000388 15-10 2018-01-012018-12-31 C000388 2-33 2017-12-31 C000388 1-12 2018-01-012018-12-31 C000388 17-22 2018-01-012018-12-31 C000388 ferc:ThreeYearsMemberferc:SulfurDioxideMember 0-20.2 2018-01-012018-12-31 C000388 9-12 2018-01-012018-12-31 C000388 ferc:NuclearProductionPlantMemberferc:ElectricUtilityMember 2018-01-012018-12-31 C000388 1-11 2018-12-31 C000388 1-2 2018-01-012018-12-31 C000388 0-24 2018-01-012018-12-31 C000388 4-26 2017-12-31 C000388 3-37 2018-12-31 C000388 12-35 2018-01-012018-12-31 C000388 9-8 2018-01-012018-12-31 C000388 17-13 2018-01-012018-12-31 C000388 16-27 2018-01-012018-12-31 C000388 10-39 2018-12-31 C000388 19-10 2018-01-012018-12-31 C000388 4-6 2018-12-31 C000388 23-14 2018-01-012018-12-31 C000388 0-12 2018-01-012018-12-31 C000388 0-39 2017-12-31 C000388 3-41 2018-01-012018-12-31 C000388 0-7 2018-01-012018-12-31 C000388 1-27 2018-01-012018-12-31 C000388 34-19 2018-01-012018-12-31 C000388 8-9 2018-01-012018-12-31 C000388 0-14 2018-12-31 C000388 21-6 2018-01-012018-12-31 C000388 10-40 2018-12-31 C000388 5-5 2018-01-012018-12-31 C000388 13-34 2018-01-012018-12-31 C000388 3-21 2018-01-012018-12-31 C000388 3-4 2018-01-012018-12-31 C000388 0-4 2018-01-012018-12-31 C000388 9-4 2018-01-012018-12-31 C000388 29-23 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 5-14 2018-12-31 C000388 PIT NO. 6-5 2018-01-012018-12-31 C000388 13-25 2018-01-012018-12-31 C000388 14-39 2018-01-012018-12-31 C000388 16-9 2018-01-012018-12-31 C000388 3-5 2018-01-012018-12-31 C000388 ferc:GasUtilityMember 0-12 2017-12-31 C000388 39-24 2018-01-012018-12-31 C000388 11-10 2018-01-012018-12-31 C000388 2-4 2018-01-012018-12-31 C000388 CARIBOU NO. 1-1 2018-12-31 C000388 5-14 2018-01-012018-12-31 C000388 26-33 2018-01-012018-12-31 C000388 1-10 2018-01-012018-12-31 C000388 2-15 2018-01-012018-12-31 C000388 6-15 2018-12-31 C000388 0-3 2018-01-012018-12-31 C000388 12-7 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 0-12 2018-01-012018-12-31 C000388 ferc:CurrentYearMemberferc:NitrogenOxideMember 0-20.1 2018-01-012018-12-31 C000388 0-35 2018-01-012018-12-31 C000388 19-27 2018-01-012018-12-31 C000388 6-5 2018-01-012018-12-31 C000388 14-27 2018-12-31 C000388 0-2 2018-01-012018-12-31 C000388 16-32 2018-12-31 C000388 0-17 2017-12-31 C000388 1-15 2017-12-31 C000388 0-7 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 5-21 2018-01-012018-12-31 C000388 14-26 2018-01-012018-12-31 C000388 8-35 2018-12-31 C000388 12-10 2018-01-012018-12-31 C000388 0-27 2018-12-31 C000388 2-37 2018-01-012018-12-31 C000388 1-10 2018-12-31 C000388 8-39 2018-12-31 C000388 3-26 2018-01-012018-12-31 C000388 2-5 2018-12-31 C000388 17-14 2018-12-31 C000388 ferc:ElectricUtilityMember 1-9 2018-12-31 C000388 21-10 2018-01-012018-12-31 C000388 1-14 2018-01-012018-12-31 C000388 0-26 2018-12-31 C000388 ferc:ElectricUtilityMember 5-36 2018-12-31 C000388 ferc:OtherUtilityMember 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 7-12 2018-01-012018-12-31 C000388 ferc:ElectricPlantHeldForFutureUseMemberferc:ElectricUtilityMember 2018-12-31 C000388 11-34 2018-01-012018-12-31 C000388 2-40 2017-12-31 C000388 6-23 2018-01-012018-12-31 C000388 7-8 2018-12-31 C000388 7-12 2018-12-31 C000388 ferc:ElectricUtilityMember 4-21 2018-01-012018-12-31 C000388 3-8 2018-01-012018-12-31 C000388 6-17 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 5-37 2018-01-012018-12-31 C000388 ferc:NextTwelveMonthsMemberferc:NitrogenOxideMember 0-9 2018-01-012018-12-31 C000388 11-5 2018-12-31 C000388 4-10 2018-01-012018-12-31 C000388 33-8 2018-01-012018-12-31 C000388 2-21 2018-12-31 C000388 21-17 2018-01-012018-12-31 C000388 0-26 2018-01-012018-12-31 C000388 0-5 2017-12-31 C000388 22-14 2018-01-012018-12-31 C000388 24-16 2018-01-012018-12-31 C000388 2-11 2018-12-31 C000388 15-27 2018-01-012018-12-31 C000388 15-31 2018-01-012018-12-31 C000388 5-24 2018-12-31 C000388 0-4 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 2-32 2018-01-012018-12-31 C000388 0-4 2018-01-012018-12-31 C000388 39-21 2018-01-012018-12-31 C000388 5-35 2018-12-31 C000388 26-15 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 1-38 2018-01-012018-12-31 C000388 4-5 2018-01-012018-12-31 C000388 0-29 2018-12-31 C000388 8-15 2018-01-012018-12-31 C000388 18-17 2018-01-012018-12-31 C000388 27-6 2018-01-012018-12-31 C000388 0-32 2018-01-012018-12-31 C000388 0-43 2017-01-012017-12-31 C000388 5-2 2018-01-012018-12-31 C000388 11-8 2018-12-31 C000388 ferc:ElectricUtilityMember 2-29 2018-12-31 C000388 0-20 2018-01-012018-12-31 C000388 TIGER CREEK-6 2018-01-012018-12-31 C000388 8-24 2018-12-31 C000388 2-28 2018-12-31 C000388 19-2 2018-01-012018-12-31 C000388 4-30 2018-01-012018-12-31 C000388 5-29 2018-01-012018-12-31 C000388 2-15 2017-12-31 C000388 4-17 2018-01-012018-12-31 C000388 29-24 2018-01-012018-12-31 C000388 PIT NO. 5-5 2018-12-31 C000388 28-7 2018-01-012018-12-31 C000388 0-7 2018-01-012018-12-31 C000388 5-32 2018-01-012018-12-31 C000388 9-31 2018-12-31 C000388 ferc:ElectricUtilityMember 2-35 2018-01-012018-12-31 C000388 0-2 2018-01-012018-12-31 C000388 1-46 2018-01-012018-12-31 C000388 0-2 2018-01-012018-12-31 C000388 1-8 2018-01-012018-12-31 C000388 7-14 2018-01-012018-12-31 C000388 12-3 2018-01-012018-12-31 C000388 4-28 2017-12-31 C000388 25-15 2018-01-012018-12-31 C000388 1-17 2018-12-31 C000388 3-30 2018-01-012018-12-31 C000388 1-36 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 7-42 2018-12-31 C000388 24-28 2018-01-012018-12-31 C000388 30-29 2018-01-012018-12-31 C000388 ferc:OctoberMember EDRP 2018-01-012018-12-31 C000388 26-14 2018-01-012018-12-31 C000388 7-41 2018-01-012018-12-31 C000388 2-32 2018-01-012018-12-31 C000388 5-37 2018-01-012018-12-31 C000388 2-14 2018-01-012018-12-31 C000388 15-29 2018-01-012018-12-31 C000388 1-7 2018-01-012018-12-31 C000388 6-8 2018-12-31 C000388 7-17 2018-01-012018-12-31 C000388 35-10 2018-01-012018-12-31 C000388 0-5 2018-01-012018-12-31 C000388 4-38 2018-01-012018-12-31 C000388 34-7 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 4-24 2018-12-31 C000388 ferc:ThreeYearsMemberferc:NitrogenOxideMember 0-20.1 2018-01-012018-12-31 C000388 13-23 2018-01-012018-12-31 C000388 31-3 2018-01-012018-12-31 C000388 16-23 2018-01-012018-12-31 C000388 13-9 2018-01-012018-12-31 C000388 26-29 2018-01-012018-12-31 C000388 13-20 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 4-19 2018-12-31 C000388 1-27 2018-01-012018-12-31 C000388 1-36 2018-01-012018-12-31 C000388 0-10 2018-01-012018-12-31 C000388 0-18 2018-12-31 C000388 19-25 2018-01-012018-12-31 C000388 26-1 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 0-3 2018-01-012018-12-31 C000388 1-36 2018-12-31 C000388 19-16 2018-01-012018-12-31 C000388 1-32 2018-01-012018-12-31 C000388 7-11 2018-01-012018-12-31 C000388 3-29 2017-12-31 C000388 ferc:ElectricUtilityMember 0-42 2018-12-31 C000388 29-34 2018-01-012018-12-31 C000388 0-6 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 3-4 2018-01-012018-12-31 C000388 1-9 2018-01-012018-12-31 C000388 31-33 2018-01-012018-12-31 C000388 27-19 2018-01-012018-12-31 C000388 11-35 2018-12-31 C000388 4-3 2018-01-012018-12-31 C000388 0-5 2018-01-012018-12-31 C000388 24-2 2018-01-012018-12-31 C000388 13-24 2018-12-31 C000388 ferc:ElectricUtilityMember 2-7 2018-12-31 C000388 ferc:ElectricUtilityMember 3-1 2018-01-012018-12-31 C000388 25-7 2018-01-012018-12-31 C000388 5-3 2018-01-012018-12-31 C000388 0-8 2018-01-012018-06-30 C000388 12-26 2018-01-012018-12-31 C000388 14-36 2018-01-012018-12-31 C000388 29-9 2018-01-012018-12-31 C000388 ferc:TwoYearsMemberferc:NitrogenOxideMember 2018-12-31 C000388 19-19 2018-01-012018-12-31 C000388 16-40 2018-12-31 C000388 0-42 2018-01-012018-12-31 C000388 4-28 2018-12-31 C000388 10-26 2018-12-31 C000388 0-3 2018-01-012018-12-31 C000388 0-1 2018-12-31 C000388 0-7 2018-01-012018-12-31 C000388 ferc:ElectricUtilityMember 4-42 2018-12-31 C000388 ferc:ElectricUtilityMember 4-4 2018-12-31 C000388 21-23 2018-01-012018-12-31 utr:g utr:Btu utr:kWh iso4217:USD xbrli:shares iso4217:USD utr:kWh utr:bbl utr:kV xbrli:pure utr:Btu xbrli:pure utr:mi iso4217:USD utr:MMBTU utr:kWh utr:MWh iso4217:USD utr:mi iso4217:USD utr:MW ferc:MVa utr:Mcf utr:kV iso4217:USD utr:kW xbrli:shares utr:MW
THIS FILING IS
Item 1:
An Initial (Original) Submission
OR
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
/
Q4


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

GENERAL INFORMATION

  1. 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.
  2. 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).
  3. What and Where to Submit

    1. 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.
    2. The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
    3. 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
    4. 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:
      1. 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
      2. 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
    5. 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.
    6. 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.
    7. 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 .
  4. 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).
  5. 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

  1. 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.
  2. 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.
  3. 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.
  4. 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.
  5. 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).
  6. 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.
  7. 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.
  8. Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
  9. 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
  1. 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.
  2. 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:

  1. ’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;
  2. 'Person' means an individual or a corporation;
  3. '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;
  1. '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; ......
  1. "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
  1. '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.
  1. 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.
  1. 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.
1

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
/
Q4
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
/
Q4
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
/
Q4
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
/
Q4
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
/
Q4
CORPORATIONS CONTROLLED BY RESPONDENT
  1. 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.
  2. 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.
  3. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests.
Definitions
  1. See the Uniform System of Accounts for a definition of control.
  2. Direct control is that which is exercised without interposition of an intermediary.
  3. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control.
  4. 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
/
Q4
OFFICERS
  1. 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.
  2. 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
/
Q4
DIRECTORS
  1. 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.
  2. 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
/
Q4
INFORMATION ON FORMULA RATES
Does the respondent have formula rates?
Yes

No
  1. 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
/
Q4
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
  1. 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
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
/
Q4
INFORMATION ON FORMULA RATES - Formula Rate Variances
  1. 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.
  2. 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.
  3. 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.
  4. 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
/
Q4
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.

  1. 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.
  2. 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.
  3. 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.
  4. 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.
  5. 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.
  6. 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.
  7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments.
  8. State the estimated annual effect and nature of any important wage scale changes during the year.
  9. 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.
  10. 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.
  11. (Reserved.)
  12. 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.
  13. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period.
  14. 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
/
Q4
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
/
Q4
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
/
Q4
STATEMENT OF INCOME

Quarterly

  1. 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.
  2. 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.
  3. 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.
  4. 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.
  5. If additional columns are needed, place them in a footnote.

Annual or Quarterly if applicable

  1. Do not report fourth quarter data in columns (e) and (f)
  2. 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.
  3. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above.
  4. Use page 122 for important notes regarding the statement of income for any account thereof.
  5. 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.
  6. 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.
  7. If any notes appearing in the report to stokholders are applicable to the Statement of Income, such notes may be included at page 122.
  8. 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.
  9. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports.
  10. 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
/
Q4
STATEMENT OF RETAINED EARNINGS
  1. Do not report Lines 49-53 on the quarterly report.
  2. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year.
  3. 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).
  4. State the purpose and amount for each reservation or appropriation of retained earnings.
  5. 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.
  6. Show dividends for each class and series of capital stock.
  7. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings.
  8. 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.
  9. 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
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)
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
13,916,352
23.2
DividendsDeclaredPreferredStock
Accrued Preferred Dividends Requirement
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
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
/
Q4
STATEMENT OF CASH FLOWS
  1. 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.
  2. 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.
  3. 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.
  4. 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
/
Q4
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
/
Q4
NOTES TO FINANCIAL STATEMENTS
  1. 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.
  2. 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.
  3. 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.
  4. 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.
  5. Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
  6. 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.
  7. 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.
  8. 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.
  9. 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
/
Q4
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
  1. Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate.
  2. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges.
  3. 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.
  4. 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
/
Q4
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
/
Q4
NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
  1. Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent.
  2. 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
/
Q4
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
  1. Report below the original cost of electric plant in service according to the prescribed accounts.
  2. 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.
  3. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year.
  4. 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.
  5. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.
  6. 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.
  7. 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.
  8. 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.
  9. 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
/
Q4
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
/
Q4
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
  1. 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.
  2. 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
/
Q4
CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
  1. Report below descriptions and balances at end of year of projects in process of construction (107).
  2. 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).
  3. 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
/
Q4
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
  1. Explain in a footnote any important adjustments during year.
  2. 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.
  3. 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.
  4. 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
/
Q4
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
  1. Report below investments in Account 123.1, Investments in Subsidiary Companies.
  2. 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.
  3. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1.
  4. 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.
  5. 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.
  6. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year.
  7. 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).
  8. 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
/
Q4
MATERIALS AND SUPPLIES
  1. 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.
  2. 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
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. 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.
  4. 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).
  5. Report on line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. 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.
  7. 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).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. 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
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. 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.
  4. 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).
  5. Report on line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. 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.
  7. 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).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. 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
/
Q4
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
300
10,000
2
HIG Substation
5,010
10
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
/
Q4
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
100
3,620,556
22
DCPP Relicensing
16,403,494
2,050,437
100
14,353,057
23
DCPP Canceled Orders
50,835,492
0
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
/
Q4
Transmission Service and Generation Interconnection Study Costs
  1. Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies.
  2. List each study separately.
  3. In column (a) provide the name of the study.
  4. In column (b) report the cost incurred to perform the study at the end of period.
  5. In column (c) report the account charged with the cost of the study.
  6. In column (d) report the amounts received for reimbursement of the study costs at end of period.
  7. 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
100
3
ABC
2,610,739
2,353,572
20
Total
2,610,839
2,353,472
21
Generation Studies
22
DEF2
100
100
23
ABC2
1,120,039
2,034,585
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
/
Q4
OTHER REGULATORY ASSETS (Account 182.3)
  1. Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable.
  2. 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.
  3. 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
919,364
2
(amortization: < 12 months)
3
AB802 Memo Account - Gas
266,531
485,676
752,207
4
(amortization: < 12 months)
5
Acc Amt - Plant RA Tax
161,887,481
3,520,572
165,408,053
6
(amortization: 11 years)
7
Accum Amort - URG Plant Reg Asset
3,520,575
3,520,575
8
(amortization: < 12 months)
9
Accum Amort - URG Plant Reg Asset Non Current
646,489,723
42,243,000
688,732,723
10
(amortization: 12 years)
11
AMCDOP- Cost Adjust Mechanism
49,846,489
54,347,071
66,232,297
37,961,263
12
(amortization: < 12 months)
13
Balancing Account - Utility Generation
13,857,924
2,346,308,203
2,253,502,275
78,948,004
14
(amortization: < 12 months)
15
BCA Charge Account
440,258
3,228,320
2,721,930
946,648
16
(amortization: <12 months)
17
Biomass Memo Account
357,908
51,287,488
22,554,764
29,090,632
18
(amortization: < 12 months)
19
Bioram Memo Account
5,775,726
16,787,864
13,111,548
9,452,042
20
(amortization: < 12 months)
21
CA Alternate Rates for Energy Program-Electric
23,438,916
516,932,147
497,729,243
42,641,820
22
(amortization: < 12 months)
23
CA Alternate Rates for Energy Program-Gas
21,906,240
124,145,197
126,548,962
24,310,005
24
(amortization: < 12 months)
25
CA Solar Initiative Thermal Program Memo Account
6,742,115
7,446,999
6,190,940
7,998,174
26
(amortization: < 12 months)
27
Catastrophic Event Memorandum Account
527,923,691
821,286,585
681,331,001
667,879,275
28
(amortization: <12 months)
29
CEE Incentive Electric Balancing Account
2,471,330
21,457
3,750,049
1,257,262
30
(amortization: < 12 months)
31
CEE Incentive Gas Balancing Account
212,379
550,223
146,331
616,271
32
(amortization: < 12 months)
33
Core Brokerage Fee
1,183,803
6,507,572
6,539,622
1,151,753
34
Amortization : < 12 MONTHS
35
Core Fixed Cost Gas Balancing Account
288,383,643
2,583,642,839
2,538,624,137
333,402,345
36
(amortization: < 12 months)
37
Core Pipeline Demand Charge Account
12,944,626
507,268,450
506,722,166
13,490,910
38
(amortization: < 12 months)
39
Critical Docs Program memo Acct NC
6,260,968
5,760,560
3,577,132
8,444,396
40
(amortization: > 12 months)
41
DCRBA - DCPP Employee Retention Program
66,678,204
33,891,874
32,786,330
42
(amortization : > 12 months)
43
Deferred Debit - Gas Reserves (Contra Balancing Ac
206,150,601
338,716,664
466,934,661
334,368,598
44
(amortization: < 12 months)
45
Demand Response Expenditures BA - DRAM
4,773,654
18,298,415
13,524,761
46
(amortization: > 12 months)
47
Demand Response Expenditures B/A (DREBA)
7,884,859
36,450,378
36,287,129
7,721,610
48
amortization: < 12 months
49
Department of Energy Litigation Balancing Account
15,017,083
15,230,427
29,270,198
29,056,854
50
(amortization: > 12 months)
51
Diablo Canyon Seismic Studies Balancing Acct
17,360,285
4,636,128
12,723,018
9,273,395
52
(amortization: < 12 months)
53
Diablo Canyon Retirement Bal Acct (DEPR) - NC
24,083,136
2,090,749
21,992,387
54
(amortization: > 12 months)
55
Distribution Revenue Adjustment Mechanism
71,915,222
4,908,351,283
4,676,758,177
159,677,884
56
(amortization: < 12 months)
57
Distributed Resources Plan Memorandum Acct
1,211,975
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
292,898,890
999,999,999
63
Electric Balancing Account Reserve Account
748,968,524
999,999,999
251,031,475
64
Electric Balancing Account Reserve Account
133,840,006
133,840,006
65
(amortization: < 12 months)
66
Electric Hazardous Substance Balancing Account
35,775,193
75,060,107
71,623,102
39,212,198
67
(amortization: < 12 months)
68
Electric Price Risk Management - Current
43,680,363
149,761,224
166,073,774
27,367,813
69
Electric Price Risk Management - NonCurrent
64,887,869
286,879,321
262,053,131
89,714,059
70
Electric Program Investment Charge
4,303,871
93,744,038
100,847,846
2,799,937
71
(amortization: < 12 months)
72
End-Use Customer Refund Adjustment
18,724,310
13,531,597
2,572,825
7,765,538
73
(amortization: < 12 months)
74
Energy Recovery Bonds Balancing Account
3,772,785
47,868,046
90,491,604
46,396,343
75
(amortization: < 12 months)
76
Energy Resource Recovery Account
70,591,762
3,731,544,376
3,855,245,475
53,109,337
77
(amortization: < 12 months)
78
Environmental Compliance
159,159,599
92,687,558
28,568,149
223,279,008
79
(amortization: 32 years)
80
Environmental Compliance Non-HSM
40,989,049
4,164,084
5,883,630
39,269,503
81
(amortization: 32 years)
82
Family Electric Rate Assistance Balancing Acct
6,396,125
5,340,841
6,396,125
5,340,841
83
(amortization: < 12 months)
84
FIN 47 - Regulatory Asset
17,558,036
3,921,979
2,325,533
19,154,482
85
Financing Costs - Current
1,507,230
126,659
1,380,571
86
(amortization: < 12 months)
87
Financing Costs Regulatory Asset
17,025,505
126,659
1,495,281
15,656,883
88
(amortization: 20 years)
89
Fire Hazard Prevention Memo Acct
1,078,845
384,213,494
76,516,282
308,776,057
90
(amortization: < 12 Months)
91
Gas Core Firm Storage Account
2,836,042
73,689,333
72,263,354
4,262,021
92
(amortization: < 12 months)
93
Gas Hazardous Substance Balancing Account
83,475,448
174,970,574
166,950,894
91,495,128
94
(amortization: < 12 months)
95
Gas Hazardous Substance Regulatory Asset
375,144,418
213,630,555
67,790,619
520,984,354
96
(amortization: 32 years)
97
Gas Non-Hazardous Substance Regulatory Asset
133,533,910
1,098,204
1,559,252
133,072,862
98
(amortization: 32 years)
99
Gas Pipeline Expense and Capital Balancing Account
3,436,048
404,792
3,538,382
302,458
100
(amortization: <12 months)
101
Gas Price Risk Management - Current
1,084,177
5,561,104
4,984,714
1,660,567
102
GPBA-Greenhouse Gas Compliance Subaccount
157,201,621
97,708,033
203,017,081
51,892,573
103
(amortization: < 12 months)
104
Gas Public Purpose Program Surcharge Memo Acct
45,383,994
262,600,117
263,513,722
44,470,389
105
(amortization: < 12 months)
106
Gas Transmission and Storage Memo Account (GTSMA)
180,904,540
120,214,886
188,206,878
112,912,548
107
(amortization: < 12 months)
108
Gas Transmission and Storage Revenue Sharing Mech.
18,143,605
409,981,159
435,704,157
7,579,393
109
(amortization: < 12 months)
110
GPBA - GHG Operational Cost Subaccount
27,406,445
20,648,625
42,120,504
5,934,566
111
(amortization: < 12 months)
112
Green Tariff Shared Renewables Bal Acct
106,047
10,165,144
5,772,392
4,498,799
113
(amortization: < 12 months)
114
Greem Tariff Shared Renewables Memo Acct
4,996,470
1,545,419
883,302
5,658,587
115
(amortization: < 12 months)
116
Greenhouse Gas Expense Memo Account - E
1,892,397
901,485
28,770
1,019,682
117
Greenhouse Gas Expense Memo Account - G
334,859
889,891
374,120
850,630
118
(amortization: < 12 months)
119
Hydro Licensing Balancing Account
20,372,843
1,304,870
28,015,544
47,083,517
120
Hydro Pipeline Testing Memo Acct
90,115,840
90,115,840
121
(amortization: > 12 months)
122
Integrated Distribution Energy Resources Account
71,232
151,908
223,140
123
(amortization: > 12 months)
124
Land Conserv. Plan Env. Remediation Memo Acct.
746,381
1,400,211
746,382
1,400,210
125
(amortization: < 12 months)
126
Line 407 Memo Acct NC
301,110
3,468,913
295,206
3,474,817
127
(amortization: > 12 months)
128
Major Emergency Balancing Account
288,710
103,517,472
125,770,895
21,964,713
129
(amortization: < 12 Months)
130
Miscellaneous Elec-Current-FERC Interest Bearing
57,292,448
1,291
57,291,157
131
(amortization: < 12 months)
132
Miscellaneous Electric Reg Asset - Current
481,041,835
171,448,117
623,567,816
28,922,136
133
(amortization: < 12 months)
134
Miscellaneous Electric Reg Asset - NonCurrent
9,638,677
413,600,941
259,694,970
163,544,648
135
(amortization: 25 years)
136
Miscellaneous Gas Reg Asset - Current
3,865,759
20,518,440
443,763
23,940,436
137
(amortization: < 12 months)
138
Mobile Home Park Balancing Account - Electric
7,093,489
37,835,958
26,368,081
18,561,366
139
(amortization: < 12 months)
140
Mobile Home Park Balancing Account - Gas
7,269,902
37,119,683
26,764,471
17,625,114
141
(amortization: < 12 months)
142
Modified transition cost balancing account
10,808,975
110,636,874
81,724,460
18,103,439
143
(amortization: < 12 months)
144
Negative Ongoing Competition Transition Chrg BA
3,089,668,292
109,931,615
179,905
3,199,420,002
145
(amortization: < 12 months)
146
New System Generation BA
46,650,016
321,811,469
156,216,930
118,944,523
147
(amortization: < 12 months)
148
New Environmental Regulations Balancing Acct
34,249,572
23,699,624
10,549,948
149
(amortization: < 12 months)
150
Non Current HSM BA Elec
38,439,275
57,450,004
67,007,423
28,881,856
151
(amortization: > 12 months)
152
Non Current HSM BA Gas
89,691,641
134,050,008
156,350,654
67,390,995
153
(amortization: > 12 months)
154
Noncurr Wildfire Exp Memo Acct - Elec
213,354,963
213,354,963
155
(amortization: > 12 months)
156
Noncurr Wildfire Exp Memo Acct - Gas
103,948,670
103,948,670
157
(amortization: > 12 months)
158
Nuclear Decommissioning Adjustment Mechanism
45,752,788
69,235,497
40,935,684
17,452,975
159
(amortization: 2 years)
160
Nuclear Regulatory Commission Rulemaking Costs BA
8,001,467
42,424,044
36,255,129
14,170,382
161
(amortization: > 12 Months)
162
Pension Regulatory Asset
1,953,963,992
151,311,609
158,171,730
1,947,103,871
163
(amortization: indefinite)
164
Procurement Energy Efficiency Rev. Adj. Mechanism
11,603,488
334,265,163
337,429,250
8,439,401
165
(amortization: < 12 months)
166
Public Purpose Programs Revenue Adjustment Mech.
26,720,208
203,534,997
205,662,867
28,848,078
167
(amortization: < 12 months)
168
Purchased Gas Balancing Account
2,119,259
1,629,992,206
1,621,443,629
10,667,836
169
(amortization: < 12 months)
170
Reg Asset - Abandoned Capital Projects
18,324,235
20,622,784
13,928,167
25,018,852
171
(amortization: < 12 months)
172
Reg Asset - Mobilehome park BA - E Noncurrent
15,117,286
18,860,040
9,244,074
24,733,252
173
(amortization: < 12 months)
174
Reg Asset - Mobilehome park BA - G Noncurrent
17,475,604
16,982,398
6,741,494
27,716,508
175
(amortization: < 12 months)
176
Reg Asset - Mobilehome park BA - E Current
1,622,479
3,546,678
2,737,651
2,431,506
177
(amortization: < 12 months)
178
Reg Asset - Mobilehome park BA - G Current
1,806,908
3,990,547
3,066,169
2,731,286
179
(amortization: < 12 months)
180
Reg Asset - Hydro Non Current
10,758,023
107,529
9,107
10,856,445
181
(amortization: > 12 months)
182
Reg Asset - Cema Elec Non Current
322,049,440
910,598,355
239,781,569
992,866,226
183
(amortization: > 12 months)
184
Reg Asset - Cema Gas Non Current
26,429,472
24,417,732
2,128,697
48,718,507
185
(amortization: > 12 months)
186
Reg Asset - Miscellaneous Gas - Non-Current
101,035,834
70,274,180
30,761,654
187
(amortization: > 12 months)
188
Reliability Services Balancing Account
410,816
69,850,963
125,330,531
55,890,384
189
(amortization: < 12 months)
190
Residential Rate Reform Memorandum Account (RRRMA)
19,253,940
18,292,957
20,910,559
16,636,338
191
(amortization: < 12 months)
192
Tax Normalization Memo Account (TNMA)
9,965,012
9,464,934
4,165,656
15,264,290
193
(amortization: > 12 months)
194
Transition Cost - Noncore Balancing Account
2,314,575
180,038,106
211,168,204
33,444,673
195
(amortization: < 12 months)
196
Transmission Access Charge Balancing Account
139,010,141
455,486,736
466,887,276
127,609,601
197
(amortization: < 12 months)
198
Transmission Revenue Balancing Account
101,030,150
269,566,411
239,282,193
70,745,932
199
(amortization: < 12 months)
200
Unamortized Financial Hedging Cost
12,779,845
836,195
11,943,650
201
(amortization: 20 years)
202
Unamortized Financial Hedging Cost Current
836,195
836,195
203
(amortization: < 12 months)
204
URG Plant Regulatory Asset - current
42,239,000
42,239,000
205
(amortization: < 12 months)
206
URG Plant Regulatory Asset - noncurrent
944,805,000
944,805,000
207
(amortization: 22 years)
208
URG Plant Regulatory Asset - Tax
183,010,953
183,010,953
209
(amortization: 11 years)
210
Vegetation Management Reg. Asset - Current
15,848,080
163,110,849
156,874,793
22,084,136
211
(amortization: < 12 months)
212
Wildfires Customer Protections Memo Acct - E
2,209,780
2,209,780
213
(amortization: > 12 months)
214
Wildfires Customer Protections Memo Acct - G
1,579,497
1,579,497
215
(amortization: > 12 months)
216
Miscellaneous minor items
219,928,700
359,284,630
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
/
Q4
MISCELLANEOUS DEFFERED DEBITS (Account 186)
  1. Report below the particulars (details) called for concerning miscellaneous deferred debits.
  2. For any deferred debit being amortized, show period of amortization in column (a)
  3. 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
1,147,137,951
19,282,202
2
Customer Adv for Construction
7,277,615
1,154,553
776,326
7,655,842
3
Development Costs
62,235,288
2,661,177
19,283,495
45,612,970
4
Payments for MLX and
5
Non-Energy Invoices
1,370,556
724,044,888
724,006,244
1,409,200
6
Payments for Main Line
7
Extension
6,311,326
197,112,042
202,297,724
11,497,008
8
Clearing Account for
9
JP Morgan Chase
1,271,127
23,841,842
24,006,900
1,106,069
10
Payroll Clearing Account
201,506
12,670,981,026
12,670,843,910
338,622
11
Land Surplus
480,219
559,044
1,039,263
12
Credit Card Clearing Account
275,299
8,520,349
7,963,968
281,082
13
Miscellaneous minor items
58,403
131,790,040
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
/
Q4
ACCUMULATED DEFERRED INCOME TAXES (Account 190)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes.
  2. 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
/
Q4
CAPITAL STOCKS (Account 201 and 204)
  1. 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.
  2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year.
  3. 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.
  4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative.
  5. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year.
  6. 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
/
Q4
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.
  1. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation.
  2. 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.
  3. 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.
  4. 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
/
Q4
CAPITAL STOCK EXPENSE (Account 214)
  1. Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
  2. 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
/
Q4
LONG-TERM DEBT (Account 221, 222, 223 and 224)
  1. 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.
  2. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds.
  3. 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.
  4. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued.
  5. 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.
  6. 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.
  7. 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.
  8. 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.
  9. 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
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
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
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
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
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
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
/
Q4
FOOTNOTE DATA

(a) Concept: NominalDateOfIssue
3/23/04
(b) Concept: NominalDateOfIssue
3/13/07
(c) Concept: NominalDateOfIssue
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
/
Q4
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
  1. 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.
  2. 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.
  3. 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
/
Q4
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
  1. 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.
  2. 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.
  3. 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.
  4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
  5. 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).
  6. 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.
  7. 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.
  8. 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.
  9. 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
/
Q4
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
0
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
0
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
/
Q4
OTHER DEFERRED CREDITS (Account 253)
  1. Report below the particulars (details) called for concerning other deferred credits.
  2. For any deferred credit being amortized, show the period of amortization.
  3. 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
51,059,826
67,340,832
167,009,151
2
Deferred Cr - Electric Reserves
44,650,027
1,405
2,087,504
46,736,126
3
Other
12,716,162
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
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. 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
30
30
307
20
State Income Tax
0
1
1
2
2
3
3
0
21
Local Income Tax
0
5
5
6
6
3
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
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. 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
175,076,548
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
8,785,783
94,971,948
1,581,784,925
13
Local Income Tax
0
0
0
0
0
0
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
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes relating to amounts recorded in Account 283.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Provide in the space below explanations for Page 276 and 277. Include amounts relating to insignificant items listed under Other.
  4. 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
0
0
34,736,952
4
Balancing Accounts
142,447,428
25,734,058
81,541,543
0
0
0
102,489,643
352,212,672
5
Other
2,495,951
1,741,064
14,529,089
0
0
0
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
0
0
16,737,972
12
Balancing Accounts
268,468,323
23,957,685
99,713,602
0
0
0
25,112,667
217,825,073
13
Other
2,161,432
597,013
98,562
0
0
0
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
0
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
/
Q4
OTHER REGULATORY LIABILITIES (Account 254)
  1. Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable.
  2. 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.
  3. 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
3,536,524
3,460,596
383,952
2
(amortization: 5 years)
3
California Solar Initiative
66,414,573
14,016,129
9,220,917
61,619,361
4
(amortization: 5 years)
5
Demand Response Expenditures Balancing Account
57,642,744
69,069,154
51,492,499
40,066,089
6
Distribution Resource Plan Demo B/A Curr
107,978
235,686
1,067,647
939,939
7
(amortization: <12 months)
8
DREBA Operations Balancing Account - Current
24,840,637
25,169,788
12,458,361
12,129,210
9
Electric Vehicle Program BA Current
1,972,297
13,432,047
18,915,509
3,511,165
10
(amortization: <12 months)
11
Electric Price Risk Management - Current
26,867,115
104,655,510
120,740,007
42,951,612
12
Electric Price Risk Management - NonCurrent
101,500,411
375,684,882
439,345,727
165,161,256
13
Electric Program Investment Charge Balancing Acct
173,193,908
90,142,787
106,454,386
189,505,507
14
Engineering Critical Assessment Bal ACCT-CURRENT
9,848,830
73,668,433
63,819,603
15
(amortization: <12 months)
16
FAS 109 Reg Liability
1,020,833,435
5,397,386,422
4,660,041,025
283,488,038
17
(amortization: >12 months)
18
FAS 143 Regulatory Liability - Nuclear
999,999,999
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
13,861,210
145,886,151
21
FAS 143 Regulatory Liability - Fossil Decomm
176,633,546
7,769,312
168,864,234
22
FAS 143 Regulatory Liability-Nuclear Decomm
2,863,247,225
588,388,705
454,862,836
2,729,721,356
23
FIN 47 Regulatory Liability
709,047,472
580,609,698
584,794,371
704,862,799
24
Gas PPP Surcharge-RDD
398,165
12,095,232
12,058,377
435,020
25
(amortization: <12 months)
26
Gas Price Risk Management - Current
376,079
9,427,335
9,504,259
453,003
27
GHGRBA - Greenhouse Gas Revenue Subaccount
89,838,359
464,936,605
348,977,027
26,121,219
28
(amortization: <12 months)
29
GHGRBA - Low Carbon Fuels Stnd Rev Subaccount
18,626,564
17,572,385
61,611,607
62,665,786
30
(amortization: <12 months)
31
GPBA - Greenhouse Gas Revenue Subaccount
222,829,867
331,869,052
109,298,352
259,167
32
(amortization: <12 months)
33
GPBA - Low Carbon Fuels Stnd Rev Subaccount
685,998
443,920
391,047
633,125
34
(amortization: <12 months)
35
Miscellaneous Electric Reg Liab - Current
80,613,478
99,581,295
343,955,376
324,987,559
36
(amortization: <12 months)
37
Miscellaneous Electric Reg Liab - NonCurrent
245,025,521
50,428,889
355,395,957
549,992,589
38
MISCELLANEOUS GAS REG LIAB - CURRENT
9
61,085,215
101,987,163
40,901,957
39
Amortization : <12 MONTHS
40
MISCELLANEOUS GAS REG LIAB - NONCURRENT
19,026,468
6,158,348
3,382,670
16,250,790
41
Amortization : 2 YEARS
42
NATIONAL GAS LEAK ABATEMENT PROGRAM BALANCING ACT
1,145,007
2,166,870
1,021,863
43
(amortization: < 12 months)
44
NON CURRENT REG LIAB-CC8 SETTLEMENT
46,856,179
2,260,506
44,595,673
45
(amortization: < 12 months)
46
Amortization : 25 YEARS
47
NON-TARIFFED PRODUCTS AND SVCS BA-ELECTRIC
321,567
2,434,436
2,688,612
575,743
48
Amortization : < 12 MONTHS
49
NON-TARIFFED PRODUCTS AND SVCS BA-GAS
262,995
304,707
511,842
470,130
50
Amortization : < 12 MONTHS
51
ON BILL FINANCING BALANCING ELECTRIC
44,053,920
13,595,803
12,413,062
42,871,179
52
ON BILL FINANCING BALANCING GAS
9,541,493
2,589,677
2,387,522
9,339,338
53
PPP (PPPLIBA)-ELECTRIC
161,760,083
77,081,759
88,351,838
173,030,162
54
Amortization : < 12 MONTHS
55
PPP (PPPLIBA)-GAS
57,115,769
59,190,195
79,331,373
77,256,947
56
Amortization : < 12 MONTHS
57
PPP ENERGY EFFICIENCY-GAS
3,523,260
1,368,582
329,218
2,483,896
58
PPP SURCHARGE ENERGY EFFICIENCY - GAS
6,165,082
97,896,209
90,617,259
1,113,868
59
Amortization : < 12 MONTHS
60
PPP SURCHARGE LOW INCOME - GAS
8,697,021
79,311,319
80,449,644
7,558,696
61
Amortization : < 12 MONTHS
62
PPP SURCHARGE RDD - CURRENT
3,589,636
11,069,274
11,097,731
3,618,093
63
Amortization : < 12 MONTHS
64
PROCUREMENT ENERGY EFFICIENCY
15,108,043
6,234,784
1,480,986
10,354,245
65
PROCUREMENT ENERGY EFFICIENCY BALANCING ACCT - CT
121,365,565
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
78,711,291
94,747,059
40,651,548
68
Amortization : <12 MONTHS
69
REG LIABILITY GAS RISK MGMT - NONCURRENT
629,984
797,660
306,342
138,666
70
REG LIABILITY-MISC ELEC CURRENT -FERC INTEREST BG
1,686
74,837,561
74,835,875
71
Amortization : <12 MONTHS
72
REGULATORY LIABILITY RETIREM
418,061,715
34,704,994
37,298,481
420,655,202
73
Amortization : INDEFINITE
74
RULE 20A BALANCING ACCOUNT (RBA) NONCURRENT
18,110,041
11,472,486
6,637,555
75
Amortization : > 12 MONTHS
76
SELF GENERATION PROGARM-GAS
35,020,030
5,040,192
13,822,471
43,802,309
77
SELF GENERATION PROGRAM - ELECTRIC
180,387,537
22,960,873
63,388,316
220,814,980
78
SOLAR ON MULTIFAMILY AFFORDABLE HOUSING BAL ACCT
51,081,839
51,081,839
79
Amortization : < 12 MONTHS
80
SW MARKETING, EDUCATION AND OUTREACH PROGRAM BA
4,349,169
14,652,489
11,904,138
1,600,818
81
Amortization : < 12 MONTHS
82
SW MARKETING, EDUCATION AND OUTREACH PROGRAM BA
755,732
1,620,822
1,321,828
456,738
83
Amortization : < 12 MONTHS
84
TAMA - GAS
64,490,315
36,799,024
101,289,339
85
Amortization : 2 YEARS
86
Miscellanous minor items
45,716,209
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
/
Q4
Electric Operating Revenues
  1. 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.
  2. Report below operating revenues for each prescribed account, and manufactured gas revenues in total.
  3. 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.
  4. 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.
  5. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2.
  6. 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.)
  7. See pages 108-109, Important Changes During Period, for important new territory added and important rate increase or decreases.
  8. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts.
  9. 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
/
Q4
REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
  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
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. 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.
  2. 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.
  3. 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.
  4. 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).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. 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
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. 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.
  2. 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.
  3. 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.
  4. 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).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. 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
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. 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.
  2. 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.
  3. 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.
  4. 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).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. 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
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. 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.
  2. 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.
  3. 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.
  4. 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).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. 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
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. 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.
  2. 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.
  3. 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.
  4. 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).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. 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
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. 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.
  2. 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.
  3. 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.
  4. 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).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. 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
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. 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.
  2. 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.
  3. 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.
  4. 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).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. 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
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. 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.
  2. 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.
  3. 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.
  4. 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).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. 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
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. 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.
  2. 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.
  3. 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.
  4. 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).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. 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
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. 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.
  2. 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.
  3. 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.
  4. 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).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. 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
/
Q4
SALES FOR RESALE (Account 447)
  1. 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).
  2. 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.
  3. 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.

  4. 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).
  5. 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.
  6. 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.
  7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser.
  8. 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.
  9. 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.
  10. 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
0.4
17.7
17.7
1,843
1,071
39,544
0
40,615
2
California Independent System Operator
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
/
Q4
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
/
Q4
PURCHASED POWER (Account 555)
  1. 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.
  2. 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.
  3. 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.

  4. 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.
  5. 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.
  6. 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.
  7. 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.
  8. 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.
  9. 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
0.00000
0.05920
27
31,325,510
0
0
82
1,337
0
1,419
2
MONTEREY REGIONAL WATER
0.00000
0.21390
487
100
0
0
2,872
16,633
0
19,505
3
WASTE MANAGEMENT RENEWABLE
0.00000
4.93400
2,580
5,758
94,512
100,270
4
BIOMASS-WHEELABRATOR SHASTA
49.68000
34.28670
1,192
21,870
27,851
5,981
5
HYDRO-CHARCOAL RAVINE
0.00000
0.00050
3
14
114
128
6
EIF HAYPRESS LLC LWR
0.00000
1.54350
6,622
124,678
237,373
362,051
7
EIF HAYPRESS LLC MDL
0.00000
2.07830
9,363
167,766
334,978
502,744
8
EL DORADO MONTGOMERY CREEK
0.00000
1.49590
0.135
5,233
64,650
706,165
770,815
9
FIVE BEARS HYDROELECTRIC
0.00000
0.21400
0.135
282
1,868
10,020
11,888
10
GANSNER HYDRO
0.00000
0.04580
108
553
3,834
4,387
11
HAT CREEK HEREFORD RANCH
0.00000
0.01480
13,108
356,938
555,063
912,001
12
HYDRO PARTNERS CLOVER CREEK
0.00000
0.83990
1,317
5,373
41,539
46,912
13
HYDRO SIERRA DEADWOOD CREEK
0.00000
0.77700
1,906
23,431
62,643
86,074
14
HYPOWER INC.
0.00000
5.16950
28,312
295,160
914,232
1,209,392
15
INDIAN VALLEY HYDRO
0.00000
1.19990
2,385
20,215
81,525
101,740
16
JAMES B. PETER
0.00000
0.00000
26
103
804
907
17
JAMES CRANE HYDRO
0.00000
0.00050
4
10
150
160
18
KINGS RIVER HYDRO
0.00000
0.34220
1,406
38,356
55,517
93,873
19
LOFTON RANCH
0.00000
0.12570
964
6,059
33,463
39,522
20
MALACHA HYDRO L.P.
0.00000
25.40150
47,753
1,538,760
1,867,768
3,406,528
21
NELSON CREEK POWER
0.00000
0.28000
974
12,540
35,810
48,350
22
OLCESE WATER DISTRICT
0.00000
4.37530
23,754
198,636
903,579
1,102,215
23
OLSEN POWER PARTNERS
0.00000
1.75250
6,098
60,387
204,655
265,042
24
ORANGE COVE IRRIGATION DISTRICT
0.00000
0.46400
3,853
82,535
143,847
226,382
25
SANTA CLARA VALLEY WATER DIST.
0.00000
0.35320
2,089
77,630
77,630
26
SCHAADS HYDRO
0.00000
0.11320
365
1,954
12,605
14,559
27
SNOW MOUNTAIN BURNEY CREEK
0.00000
1.24890
3,386
36,361
124,070
160,431
28
SNOW MOUNTAIN COVE
0.00000
2.51720
9,196
143,057
698,793
841,850
29
SNOW MT. PONDEROSA BAILEY CREEK
0.00000
0.54500
1,779
28,766
43,574
72,340
30
SUTTER'S MILL SHAMROCK UTILITIES
0.00000
0.00000
139
2,273
2,412
31
SWISS AMERICA
0.00000
0.03110
212
1,823
7,631
9,454
32
TOM BENNINGHOVEN
0.00000
0.00740
49
225
1,794
2,019
33
SOLAR-VILLA SORRISO SOLAR
0.00000
0.00080
7
25
246
271
34
WIND-DONALD R. CHENOWETH
0.00000
0.00070
6
21
223
244
35
EDF RENEWABLE WINDFARM V, INC (70 MW -
0.00000
0.00000
1,361
41,924
43,285
36
EDF RENEWABLE INC 70 MW C
0.00000
1.67040
3,541
92,854
133,606
226,460
37
EDF RENEWABLE INC 10 MW
0.00000
0.00000
782
1,523
26,570
28,093
38
INTERNATIONAL TURBINE RESEARCH
0.00000
6.66540
10,720
257,011
392,665
649,676
39
THERMAL:
0.00000
0.00000
40
COGEN-1080 CHESTNUT CORP.
0.00000
0.00170
15
58
564
622
41
AIRPORT CLUB
0.00000
0.00210
17
50
626
676
42
ARDEN WOOD BENEVOLENT ASSOC.
0.00000
0.00010
1
4
36
40
43
BERKELEY COGENERATION
22.47000
2.40700
8,799
60,237
147,916
208,153
44
CALPINE KING CITY COGEN
111.00000
121.05810
393,881
24,936,469
14,695,346
39,631,815
45
CHEVRON RICHMOND REFINERY
0.00000
2.78330
1,156
2,639
55,392
58,031
46
COUNTY OF SANTA CRUZ ( WATER ST. JAIL)
0.00000
0.00000
7
7
47
CROCKETT COGEN
240.00000
239.77570
1,393,652
52,220,644
56,180,444
108,401,088
48
ECO SERVICES OPERATIONS LLC
0.00000
0.36770
357
1,029
13,330
14,359
49
FRESNO COGENERATION PARTNERS, LP
33.00000
21.42570
1,683
7,305,734
199,384
7,505,118
50
FRITO-LAY COGEN
0.00000
0.52310
632
3,859
24,677
28,536
51
GREATER VALLEJO RECREATION DIST.
0.00000
0.00380
36
109
1,269
1,378
52
GREENLEAF UNIT 1
49.20000
48.04160
73,004
9,042,139
3,506,775
12,548,914
53
GREENLEAF UNIT 2
49.20000
47.43360
224,224
10,015,038
8,021,211
18,036,249
54
HAYWARD AREA RECREATION AND PARK
0.00000
0.04570
407
1,240
15,020
16,260
55
NIHONMACHI TERRACE
0.00000
0.00130
13
40
487
527
56
ORINDA SENIOR VILLAGE
0.00000
0.00140
14
40
546
586
57
PE KES KINGSBURG LLC
34.50000
13.49420
4,443
8,851,300
311,365
9,162,665
58
PHILLIPS 66
0.00000
8.16550
22,202
127,965
870,675
998,640
59
SATELLITE SENIOR HOMES
0.00000
0.00470
2
57
57
60
SRI INTERNATIONAL
0.00000
1.79630
7,129
16,348
278,781
295,129
61
YUBA CITY COGEN
46.00000
42.79940
10,655
10,444,146
484,681
10,928,827
62
EOR-AERA ENERGY LLC COALINGA
0.00000
1.81400
5,484
27,182
230,290
257,472
63
AERA ENERGY SOUTH BELRIDGE
0.00000
1.33030
4,852
22,710
169,664
192,374
64
BERRY PETROLEUM CO - TANNEHILL
0.00000
12.11800
90,144
675,895
3,464,323
4,140,218
65
CHEVRON USA TAFT/CADET
0.00000
2.06630
4,239
36,949
166,985
203,934
66
CHEVRON USA CYMRIC
0.00000
5.28770
21,550
135,086
825,170
960,256
67
CHEVRON USA COALINGA
0.00000
3.41930
11,252
112,038
420,854
532,892
68
CHEVRON USA INC EASTRIDGE
0.00000
11.35430
14,725
78,562
584,295
662,857
69
CHEVRON USA INC SE KERN RIVER
0.00000
7.94880
4,078
34,728
155,547
190,275
70
CHEVRON MCKITTRICK FHP
0.00000
3.49840
19,701
1,260,401
1,260,401
71
COALINGA COGENERATION COMPANY
37.70000
0.00000
150,000
150,000
72
FREEPORT MCMORAN DOME
0.00000
1.83950
7,808
40,555
279,581
320,136
73
SENTINEL PEAK RESOURCES
0.00000
1.83950
82
2,957
42,290
39,333
74
WESTERN POWER & STEAM INC
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
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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
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0.00000
699,750
699,750
165
CITY OF VERNON
0.00000
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126,500
126,500
166
CLEAN PWR ALLIANCE
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338,919
338,919
167
CLEANPOWERSF
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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)
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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
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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
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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
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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
/
Q4
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
  1. 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.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
  3. 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).
  4. 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.
  5. 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.
  6. 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.
  7. 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.
  8. Report in column (i) and (j) the total megawatthours received and delivered.
  9. 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.
  10. 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.
  11. 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
Midway
Various
0
0
0
0
0
0
0
2
NORTHERN CALIFORNIA (TANC)
Various
Various
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
/
Q4
TRANSMISSION OF ELECTRICITY BY ISO/RTOs
  1. Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a).
  3. 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.
  4. 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.
  5. In column (d) report the revenue amounts as shown on bills or vouchers.
  6. 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
123
101
201
2
Name2
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
/
Q4
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
  1. 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.
  2. 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.
  3. 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.
  4. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service.
  5. 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.
  6. Enter ""TOTAL"" in column (a) as the last line.
  7. 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
100
100
1,000
500
350,010
351,510
2
PACIFICORP
100
100
149,118
500
88,602
238,220
3
ADMINISTRATION
100
100
2,256
0
0
2,256
4
INTERTIE
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
/
Q4
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
/
Q4
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
  1. 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).
  2. 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.
  3. 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.
  4. 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
4,801
10 years
1
2.18
SQ
15 years
13
113,671
(a)
75 years
2
3.46
R1
(be)
20 years
14
277,962
(b)
50 years
3
3.69
R1
(bf)
19 years
15
257,380
(c)
40 years
1
3.56
R2.5
(bg)
19 years
16
52,626
(d)
45 years
2
3.55
R2.5
(bh)
20 years
17
28,349
(e)
40 years
3
3.77
S0.5
(bi)
18 years
18
734,789
19
17,311
20 years
50
1.9
SQ
12 years
20
525,846
(f)
80 years
2
1.72
R2
(bj)
14 years
21
2,124,218
(g)
120 years
3
1.6
R2.5
(bk)
18 years
22
1,007,802
(h)
81 years
3
3.1
R1
(bl)
15 years
23
296,609
(i)
65 years
6
3.03
R1.5
(bm)
16 years
24
102,422
(j)
60 years
9
3.39
S0.5
(bn)
16 years
25
93,136
(k)
88 years
2
2.48
S1.5
(bo)
17 years
26
4,167,344
27
1,085,290
(l)
100 years
1
1.55
R1
(bp)
6 years
28
3,569,330
(m)
65 years
1
2.7
S1
(bq)
6 years
29
1,172,601
(n)
50 years
1
1.54
S2
(br)
6 years
30
844,039
(o)
75 years
1.6
R1.5
(bs)
6 years
31
1,152,130
(p)
50 years
1
5.69
S1
(bt)
6 years
32
7,823,390
33
3,121
0.64
SQ
34
210,804
(q)
59 years
1
3.69
R1,SQ
(bu)
20 years
35
11,271
(r)
50 years
2
3.69
R1
(bv)
19 years
36
227,881
(s)
40 years
3
3.57
R2.5
(bw)
20 years
37
353,878
(t)
27 years
1
4.35
R2.5,SQ
(bx)
18 years
38
213,715
(u)
31 years
2
5.71
R2.5,S2.5,SQ
(by)
16 years
39
98,646
(v)
35 years
3
3.84
S0.5,SQ
(bz)
18 years
40
1,119,316
41
247,241
(w)
42 years
4.06
R4
(ca)
26 years
42
536,335
(x)
65 years
20
1.8
R3
(cb)
56 years
43
6,478,163
(y)
2 years
0.08
R1.5
(cc)
1 year
44
961,640
(z)
75 years
66
2.25
R4
(cd)
55 years
45
1,384,181
(aa)
52 years
65
2.99
R1.5
(ce)
43 years
46
1,670,014
(ab)
65 years
70
2.57
R2
(cf)
49 years
47
511,098
(ac)
65 years
1.52
R4
(cg)
54 years
48
274,014
(ad)
55 years
10
1.99
R3
(ch)
42 years
49
103,204
(ae)
60 years
10
1.91
R1.5
(ci)
51 years
50
12,165,890
51
4,891
(af)
65 years
1.43
R3
(cj)
6 years
52
89,972
(ag)
98 years
19
7.05
R2
(ck)
12 years
53
94,863
54
122,527
(ah)
41 years
2.12
SQ
(cl)
19 years
55
323,045
(ai)
65 years
20
1.78
R3
(cm)
46 years
56
3,514,657
(aj)
46 years
40
3.06
R1.5
(cn)
32 years
57
33,497
(ak)
15 years
6.46
R2,S3
(co)
9 years
58
4,847,361
(al)
44 years
150
6.03
R1.5
(cp)
31 years
59
4,776,896
(am)
46 years
125
5.05
R2
(cq)
32 years
60
3,001,225
(an)
62 years
50
2.6
R4
(cr)
44 years
61
4,804,342
(ao)
47 years
65
3.35
R3
(cs)
31 years
62
3,790,010
(ap)
32 years
28
4.4
R2.5,R3
(ct)
21 years
63
3,423,955
(aq)
47 years
67
3.5
R2.5,R4
(cu)
28 years
64
1,201,281
(ar)
20 years
15
6.21
R1.5
(cv)
13 years
65
28,071
(as)
39 years
1
0.09
S1
(cw)
5 years
66
895
(at)
25 years
L1
67
254,680
(au)
28 years
23
3.25
R0.5,S1.5,L0,S1
(cx)
10 years
68
30,122,442
69
415
(av)
59 years
2.74
SQ
(cy)
31 years
70
11,777
(aw)
50 years
10
1.62
R2
(cz)
30 years
71
10,927
(ax)
20 years
6.2
SQ
(da)
11 years
72
145,209
(ay)
25 years
3.85
SQ
(db)
17 years
73
15,907
(az)
20 years
5.37
SQ
(dc)
13 years
74
351,873
(ba)
15 years
6.25
SQ
(dd)
12 years
75
25,736
(bb)
20 years
13.04
SQ
(de)
17 years
76
561,844
77
4,504
(bc)
20 years
5.23
SQ
(df)
16 years
78
15,863
(bd)
20 years
5.39
SQ
(dg)
16 years
79
20,367
80
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
/
Q4
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
/
Q4
REGULATORY COMMISSION EXPENSES
  1. 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.
  2. 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.
  3. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization.
  4. List in column (f), (g), and (h) expenses incurred during year which were charged currently to income, plant, or other accounts.
  5. 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
0
1,000
1,000
500
2
CDE
100
100
200
500
GAS
0
1,000
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
/
Q4
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
  1. 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).
  2. Indicate in column (a) the applicable classification, as shown below:
    Classifications:
    1. Electric R, D and D Performed Internally:
      1. Generation
        1. hydroelectric
          1. Recreation fish and wildlife
          2. Other hydroelectric
        2. Fossil-fuel steam
        3. Internal combustion or gas turbine
        4. Nuclear
        5. Unconventional generation
        6. Siting and heat rejection
      2. Transmission
        1. Overhead
        2. Underground
      3. Distribution
      4. Regional Transmission and Market Operation
      5. Environment (other than equipment)
      6. Other (Classify and include items in excess of $50,000.)
      7. Total Cost Incurred
    2. Electric, R, D and D Performed Externally:
      1. Research Support to the electrical Research Council or the Electric Power Research Institute
      2. Research Support to Edison Electric Institute
      3. Research Support to Nuclear Power Groups
      4. Research Support to Others (Classify)
      5. Total Cost Incurred
  3. 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.
  4. 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).
  5. 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.
  6. 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.""
  7. 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
250,978
1,000
2
A4, A5
Customer Energy Services -
3,501,062
200
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
/
Q4
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
/
Q4
COMMON UTILITY PLANT AND EXPENSES
  1. 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.
  2. 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.
  3. 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.
  4. 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
/
Q4
AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
  1. 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
/
Q4
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.
  1. On line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year.
  2. 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.
  3. On line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year.
  4. On line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year.
  5. 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.
  6. 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
/
Q4
MONTHLY TRANSMISSION SYSTEM PEAK LOAD
  1. 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.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. 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
/
Q4
Monthly ISO/RTO Transmission System Peak Load
  1. 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.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. 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).
  5. 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
/
Q4
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
/
Q4
MONTHLY PEAKS AND OUTPUT
  1. 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.
  2. Report in column (b) by month the system’s output in Megawatt hours for each month.
  3. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales.
  4. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system.
  5. 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
/
Q4
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
/
Q4
Hydroelectric Generating Plant Statistics
  1. Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. 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.
  3. If net peak demand for 60 minutes is not available, give that which is available specifying period.
  4. 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.
  5. 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."
  6. 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
/
Q4
Pumped Storage Generating Plant Statistics
  1. Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. 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.
  3. If net peak demand for 60 minutes is not available, give the which is available, specifying period.
  4. 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.
  5. 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."
  6. Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes.
  7. 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
/
Q4
GENERATING PLANT STATISTICS (Small Plants)
  1. 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).
  2. 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.
  3. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 403.
  4. If net peak demand for 60 minutes is not available, give the which is available, specifying period.
  5. 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
/
Q4
ENERGY STORAGE OPERATIONS (Large Plants)
  1. Large Plants are plants of 10,000 KW or more.
  2. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location.
  3. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage.
  4. 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.
  5. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy.
  6. In column (k) report the MWHs sold.
  7. 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.
  8. 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.
  9. 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
1,000
2,000
3,000
4,000
100
200
300
600
10
20
30
40
60
70
80
2
B Project
1,000
2,000
3,000
4,000
100
200
300
600
10
20
30
40
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
/
Q4
TRANSMISSION LINE STATISTICS
  1. 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.
  2. 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.
  3. Report data by individual lines for all voltages if so required by a State commission.
  4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property.
  5. 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.
  6. 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.
  7. 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).
  8. 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.
  9. 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.
  10. 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
79.23
1
2300 - AAC - BUND
2
DIABLO
MIDWAY #2
500
500
84.07
1
2300 - AAC - BUND
3
DIABLO
MIDWAY #3
500
500
84.67
1
2300 - AAC - BUND
4
DIABLO UNIT #1
500
500
0.54
1
2300 - AAC - BUND
5
DIABLO UNIT #2
500
500
0.57
1
2300 - AAC - BUND
6
GATES
MIDWAY
500
500
63.78
1
2300 - AAC - BUND
7
LOS BANOS
GATES #1
500
500
80.85
1
2300 - AAC - BUND
8
LOS BANOS
MIDWAY #2
500
500
144.82
1
2300 - AAC - BUND
9
MALIN
ROUND MTN #2
500
500
46.9
1
2300 - AAC - BUND
10
MIDWAY
WHIRLWIND
500
500
52.77
1
2156 - ACSR - BUN
11
MOSS LANDING
LOS BANOS
500
500
51.33
1
2300 - AAC - BUND
12
MOSS LANDING
METCALF
500
500
34.98
1
2300 - AAC - BUND
13
ROUND MTN
TABLE MTN #1
500
500
89.03
1
2300 - AAC - BUND
14
ROUND MTN
TABLE MTN #2
500
500
89.02
1
2300 - AAC - BUND
15
TABLE MTN
TESLA
500
500
134.99
1
2300 - AAC - BUND
16
TABLE MTN
VACA
500
500
83.3
1
2300 - AAC - BUND
17
TESLA
LOS BANOS #1
500
500
57.14
1
2300 - AAC - BUND
18
TESLA
METCALF
500
500
35.31
1
2300 - AAC - BUND
19
TESLA
TRACY
500
500
1.13
1
2300 - AAC - BUND
20
TRACY
LOS BANOS
500
500
56.23
1
2300 - AAC - BUND
21
VACA
TESLA
500
500
57
1
2300 - AAC - BUND
22
ARCO
MIDWAY
230
230
43.36
1
795 - ACSR - SING
23
ATLANTIC
GOLD HILL
230
230
11.11
1
1113 - AAC - SING
24
BAHIA
MORAGA
230
230
26.92
1
954 - ACSR - SING
25
BAKERSFIELD #1 TAP
230
230
6.67
1
1113 - AAC - SING
26
BAKERSFIELD #2 TAP
230
230
7.01
1
1113 - AAC - SING
27
BALCH
MCCALL
230
230
39.76
1
954 - AAC - SINGL
28
BELDEN TAP
230
230
0.02
1
795 - ACSR - SING
29
BELLOTA
COTTLE
230
230
19.87
1
1113 - AAC - SING
30
BELLOTA
TESLA #2
230
230
37.94
1
954 - ACSS - SING
31
BELLOTA
WARNERVILLE
230
230
22.47
1
954 - ACSR - SING
32
BELLOTA
WEBER
230
230
14.26
1
954 - ACSS - SING
33
BIRDS LANDING SW STA
SHILOH
230
230
0.11
1
954 - AAC - SINGL
34
BIRDS LANDING SW STA
CONTRA COSTA PP
230
230
10.2
1
1113 - ACSS - SIN
35
BIRDS LANDING SW STA
CONTRA COSTA SUB
230
230
9.46
1
1113 - ACSS - SIN
36
BIRDS LANDING SW STA
RUSSELL
230
230
0.11
1
1431 - AAC - SING
37
BLACK TAP
230
230
0.51
1
795 - ACSR - SING
38
BORDEN
GREGG
230
230
6.21
1
1113 - AAC - SING
39
BOTTLE ROCK TAP D.W.R.
230
230
1.07
1
1113 - AAC - SING
40
BRENTWOOD
KELSO
230
230
16.41
1
1113 - AAC - SING
41
BRIGHTON
BELLOTA
230
230
42.51
1
2300 - AAC - SING
42
BUCKS CREEK
ROCK CREEK-CRESTA
230
230
9.39
1
795 - ACSR - SING
43
BUENA VISTA PUMPING PLANT #
230
230
1.18
1
1113 - AAC - SING
44
BUENA VISTA PUMPING PLANT #
230
230
1.21
1
1113 - AAC - SING
45
BURNEY FOREST PRODUCTS TAP
230
230
0.04
1
795 - ACSR - SING
46
CALIENTE SW STA
MIDWAY #1
230
230
27.17
1
954 - ACSS - SING
47
CALIENTE SW STA
MIDWAY #2
230
230
27.16
1
954 - ACSS - SING
48
CALIFORNIA FLATS SW STA
GATES
230
230
22.57
1
1113 - AAC - SING
49
CAMANCHE PUMPING PLANT TAP
230
230
0.45
1
1113 - AAC - SING
50
CARBERRY SW STA
ROUND MTN
230
230
12.61
1
500 - CU - SINGLE
51
CARIBOU
TABLE MTN
230
230
54.34
1
954 - AAC - SINGL
52
CASTRO VALLEY
NEWARK
230
230
22.71
1
954 - AAC - SINGL
53
COBURN
LAS AGUILAS SW STA
230
230
63.97
1
1113 - AAC - SING
54
COLGATE
RIO OSO
230
230
40.89
1
795 - ACSS - SING
55
CONTRA COSTA
BRENTWOOD
230
230
10.06
1
954 - ACSR - SING
56
CONTRA COSTA
DELTA SWITCHYARD
230
230
18.46
1
954 - ACSR - SING
57
CONTRA COSTA
LAS POSITAS
230
230
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
26.76
1
954 - ACSS - SING
60
CONTRA COSTA
MORAGA #2
230
230
26.84
1
954 - ACSS - SING
61
CONTRA COSTA PP
CONTRA COSTA SUB
230
230
1.89
1
1113 - ACSS - SIN
62
CORTINA
VACA
230
230
53.29
1
954 - ACSR - SING
63
COTTLE
MELONES
230
230
25.94
1
795 - ACSR - SING
64
COTTONWOOD
DELEVAN #1
230
230
71.55
1
954 - ACSR - SING
65
COTTONWOOD
GLENN
230
230
48.33
1
643.7 - SINGLE 95
66
COTTONWOOD
LOGAN CREEK
230
230
59.28
1
643.7 - SINGLE 11
67
COTTONWOOD
DELEVAN #2
230
230
71.54
1
643.7 - SINGLE 95
68
COVE ROAD TAP
230
230
0.11
1
1113 - AAC - SING
69
COYOTE SW STA
METCALF
230
230
0.88
1
2300 - AAC - BUND
70
CRESTA
RIO OSO
230
230
64.78
1
795 - ACSR - SING
71
DELEVAN
VACA #2
230
230
71.07
1
954 - ACSR - SING
72
DELEVAN
CORTINA
230
230
17.97
1
954 - ACSR - SING
73
DELEVAN
VACA #3
230
230
71.08
1
954 - ACSR - SING
74
DELEVAN
VACA #1
230
230
71.04
1
954 - ACSR - SING
75
DELTA SWITCHING YARD
TESLA
230
230
7.7
1
954 - ACSR - SING
76
DIABLO
MESA
230
230
40.34
1
1113 - AAC - SING
77
DIABLO PP STANDBY SUPPLY
230
230
0.46
1
1113 - AAC - SING
78
DOS AMIGOS PUMPING PLANT
PANOCHE
230
230
23.68
1
795 - ACSR - SING
79
EASTSHORE
SAN MATEO
230
230
12.43
1
954 - ACSS - SING
80
EIGHT MILE ROAD
TESLA
230
230
26.64
1
1113 - AAC - SING
81
EIGHT MILE ROAD
STAGG
230
230
7.2
1
1113 - AAC - SING
82
ELECTRA
BELLOTA
230
230
29.23
1
643.7 - SINGLE 50
83
FIGARDEN #1 TAP
230
230
0.85
1
1250 KCMIL - ALUM
84
FIGARDEN #2 TAP
230
230
0.83
1
1250 KCMIL - ALUM
85
FULTON
LAKEVILLE-IGNACIO
230
230
15.84
1
2300 - AAC - SING
86
FULTON
IGNACIO #1
230
230
40.73
1
2300 - AAC - SING
87
FULTON
LAKEVILLE
230
230
25.51
1
1113 - AAC - SING
88
FULTON
LAKEVILLE
230
230
1.19
1
3500 KCMIL - ALUM
89
GATES
MUSTANG SW STA #1
230
230
13.17
1
1113 - ACSS - SIN
90
GATES
MUSTANG SW STA #2
230
230
13.18
1
1113 - ACSS - SIN
91
GATES
ARCO
230
230
35.18
1
1113 - AAC - SING
92
GATES
PANOCHE #1
230
230
43.79
1
795 - ACSR - SING
93
GATES
PANOCHE #2
230
230
43.8
1
795 - ACSR - SING
94
GATES
MIDWAY
230
230
63.86
1
795 - ACSR - SING
95
GEYSERS #12
FULTON
230
230
24.09
1
1113 - AAC - SING
96
GEYSERS #13 TAP
230
230
2.06
1
1431 - AAC - SING
97
GEYSERS #16 TAP
230
230
1.29
1
1113 - AAC - SING
98
GEYSERS #17
FULTON
230
230
26.14
1
1113 - AAC - SING
99
GEYSERS #18 TAP
230
230
0.75
1
1113 - AAC - SING
100
GEYSERS #20 TAP
230
230
0.03
1
1431 - AAC - SING
101
GEYSERS #9
LAKEVILLE
230
230
41.71
1
2300 - AAC - BUND
102
GEYSERS #9
LAKEVILLE
230
230
1.24
1
3500 KCMIL - ALUM
103
GLENN
DELEVAN
230
230
37.42
1
954 - ACSR - SING
104
GOLD HILL
EIGHT MILE ROAD
230
230
48.8
1
1113 - AAC - SING
105
GOLD HILL
LODI STIG
230
230
46.67
1
1113 - AAC - SING
106
GREGG
ASHLAN
230
230
7
1
795 - ACSR - SING
107
GREGG
HERNDON #1
230
230
0.6
1
1113 - AAC - BUND
108
GREGG
HERNDON #2
230
230
0.63
1
1113 - AAC - BUND
109
H
Z #1
230
230
6.92
1
2500 KCMIL - CU
110
H
Z #2
230
230
6.96
1
2500 KCMIL - CU
111
HAAS
MCCALL
230
230
44.21
1
954 - AAC - SINGL
112
HELM
MCCALL
230
230
30.84
1
1113 - ACSS - SIN
113
HELMS
GREGG #1
230
230
60.67
1
1431 - AAC - BUND
114
HELMS
GREGG #2
230
230
60.68
1
1431 - AAC - BUND
115
HERNDON
ASHLAN
230
230
6.39
1
795 - ACSR - SING
116
HERNDON
KEARNEY
230
230
10.82
1
1113 - AAC - SING
117
HICKS
METCALF
230
230
9.07
1
954 - ACSS - SING
118
IGNACIO
SOBRANTE
230
230
42.49
1
2300 - AAC - BUND
119
JEFFERSON
MARTIN
230
230
3.31
1
954 - ACSS - SING
120
JEFFERSON
MARTIN
230
230
24.41
1
2500 KCMIL - CU
121
KELSO
TESLA
230
230
7.95
1
954 - ACSS - SING
122
LAKEVILLE
IGNACIO #2
230
230
14.53
1
1113 - AAC - SING
123
LAKEVILLE
IGNACIO #1
230
230
15.49
1
2300 - AAC - BUND
124
LAKEVILLE
SOBRANTE #2
230
230
47.89
1
2156 - ACSS - SIN
125
LAKEVILLE
TULUCAY
230
230
17.22
1
1 - UNKNOWN - UNK
126
LAKEVILLE
TULUCAY
230
230
0.06
1
1 - UNKNOWN - UNK
127
LAMBIE SW STA
BIRDS LANDING SW STA
230
230
7.04
1
1113 - ACSS - SIN
128
LAS AGUILAS SW STA
PANOCHE #2
230
230
17.44
1
795 - ACSR - SING
129
LAS AGUILAS SW STA
PANOCHE #1
230
230
17.44
1
795 - ACSR - SING
130
LAS POSITAS
NEWARK
230
230
20.93
1
795 - ACSR - SING
131
LOCKEFORD
BELLOTA
230
230
12.32
1
2300 - AAC - SING
132
LODI STIG
EIGHT MILE ROAD
230
230
2.18
1
1113 - AAC - SING
133
LOGAN CREEK
DELEVAN
230
230
12.35
1
954 - ACSR - SING
134
LONE TREE
CAYETANO
230
230
15.4
1
954 - ACSS - SING
135
LONE TREE
CAYETANO
230
230
2.3
1
2000 KCMIL - CU
136
LOS BANOS
DOS AMIGOS
230
230
14.31
1
795 - ACSR - SING
137
LOS BANOS
PANOCHE #1
230
230
37.18
1
1113 - AAC - SING
138
LOS BANOS
PANOCHE #2
230
230
37.13
1
1113 - AAC - SING
139
LOS BANOS
SAN LUIS PUMPS #1
230
230
3.43
1
1113 - AAC - SING
140
LOS BANOS
SAN LUIS PUMPS #2
230
230
3.43
1
1113 - AAC - SING
141
LOS BANOS
QUINTO SW STA
230
230
12.06
1
795 - ACSS - PARA
142
LOS ESTEROS
METCALF
230
230
63.25
1
795 - ACSR - PARA
143
LOS ESTEROS
METCALF
230
230
2.73
1
2500 KCMIL - CU
144
MALACHA TAP
230
230
0.12
1
954 - ACSR - SING
145
MELONES
WILSON
230
230
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
35.76
1
954 - ACSS - SING
148
METCALF
MOSS LANDING #2
230
230
35.76
1
954 - ACSS - SING
149
MIDDLE FORK
GOLD HILL
230
230
44.08
1
1113 - AAC - SING
150
MIDWAY
KERN #1
230
230
41.75
1
795 - ACSR - SING
151
MIDWAY
KERN #3
230
230
20.88
1
1113 - AAC - SING
152
MIDWAY
KERN #4
230
230
20.84
1
1113 - AAC - BUND
153
MIDWAY
WHEELER RIDGE #1
230
230
52.68
1
1113 - AAC - SING
154
MIDWAY
SUNSET
230
230
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
27.83
1
2300 - AAC - BUND
157
MONTA VISTA
HICKS
230
230
13.27
1
954 - ACSS - SING
158
MONTA VISTA
JEFFERSON #1
230
230
19.72
1
1113 - AAC - SING
159
MONTA VISTA
JEFFERSON #2
230
230
19.73
1
1113 - AAC - SING
160
MONTA VISTA
SARATOGA
230
230
5.49
1
1113 - AAC - SING
161
MONTEZUMA SW STA
BIRDS LANDING SW STA
230
230
0.54
1
1431 - AAC - SING
162
MORAGA
CASTRO VALLEY
230
230
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
46.19
1
954 - AAC - SINGL
165
MORRO BAY
MESA
230
230
35.27
1
1113 - AAC - SING
166
MORRO BAY
SOLAR SW STA #1
230
230
45.55
1
954 - ACSS - SING
167
MORRO BAY
SOLAR SW STA #2
230
230
45.56
1
954 - ACSS - SING
168
MORRO BAY
TEMPLETON
230
230
16.43
1
954 - AAC - SINGL
169
MOSS LANDING
COBURN
230
230
64.03
1
795 - ACSR - SING
170
MOSS LANDING
LAS AGUILAS SW STA
230
230
51.89
1
795 - ACSR - SING
171
MOSS LANDING INTERPLANT 230
230
230
0.13
1
2300 - AAC - SING
172
MOSS LANDING TX BK 1
230 SWITCHYARD
230
230
0.24
1
1113 - AAC - SING
173
MOSS LANDING TX BK 2
230 SWITCHYARD
230
230
0.16
1
500 - SINGLE
174
MUSTANG SW STA
GREGG
230
230
45.47
1
1113 - ACSS - SIN
175
MUSTANG SW STA
MCCALL
230
230
42.11
1
1113 - ACSS - SIN
176
NEWARK
LOS ESTEROS
230
230
5.65
1
1113 - AAC - BUND
177
NEWARK
RAVENSWOOD
230
230
8.91
1
954 - ACSS - BUND
178
NEWARK
LOS ESTEROS
230
230
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
3.02
1
954 - ACSS - SING
181
NORTH DUBLIN
VINEYARD
230
230
12.46
1
954 - ACSS - SING
182
NORTH DUBLIN
CAYETANO
230
230
2.81
1
2000 KCMIL - CU
183
NORTH DUBLIN
VINEYARD
230
230
11.07
1
184
PALERMO
COLGATE
230
230
29.6
1
795 - ACSS - SING
185
PANOCHE
PANOCHE ENERGY CENTER
230
230
0.09
1
1113 - AAC - BUND
186
PANOCHE
TRANQUILLITY SW STA #1
230
230
12.14
1
1113 - ACSS - SIN
187
PANOCHE
TRANQUILLITY SW STA #2
230
230
12.14
1
1113 - ACSS - SIN
188
PARKWAY
MORAGA
230
230
23.64
1
954 - ACSR - SING
189
PEABODY
BIRDS LANDING SW STA
230
230
19.85
1
1113 - ACSS - SIN
190
PIT #1
COTTONWOOD
230
230
59.75
1
500 - CU - SINGLE
191
PIT #3
PIT #1
230
230
22.69
1
518 - ACSR - SING
192
PIT #3
CARBERRY SW STA
230
230
10.91
1
795 - ACSR - SING
193
PIT #4 TAP
230
230
7.03
1
795 - ACSR - SING
194
PIT #5
ROUND MTN #1
230
230
13.12
1
795 - ACSR - SING
195
PIT #5
ROUND MTN #2
230
230
13.11
1
795 - ACSR - SING
196
PIT #6 JCT
ROUND MTN
230
230
8.15
1
795 - ACSR - SING
197
PIT #6 TAP
230
230
3.43
1
795 - ACSR - SING
198
PIT #7 TAP
230
230
3.59
1
795 - ACSR - SING
199
PITTSBURG
EASTSHORE
230
230
34.92
1
954 - ACSS - SING
200
PITTSBURG
SAN MATEO
230
230
47.4
1
954 - ACSS - SING
201
PITTSBURG
TASSAJARA
230
230
17.36
1
954 - ACSS - SING
202
PITTSBURG
SAN RAMON
230
230
21.66
1
954 - ACSS - SING
203
PITTSBURG
TESORO
230
230
11.27
1
2300 - AAC - BUND
204
PITTSBURG
TESLA #1
230
230
31.35
1
1113 - AAC 954 -
205
PITTSBURG
TESLA #2
230
230
31.32
1
954 - ACSS - SING
206
PITTSBURG
TIDEWATER
230
230
11.27
1
2300 - AAC - BUND
207
POE
RIO OSO
230
230
56.09
1
795 - ACSR - SING
208
QUINTO SW STA
WESTLEY
230
230
57.55
1
795 - ACSS - PARA
209
RALPH TAP
230
230
0.06
1
1113 - AAC - SING
210
RANCHO SECO
BELLOTA #1
230
230
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
11.88
1
1113 - AAC - BUND
213
RAVENSWOOD
SAN MATEO #1
230
230
11.89
1
1113 - AAC - BUND
214
RIO OSO
ATLANTIC
230
230
17.68
1
1113 - AAC - SING
215
RIO OSO
BRIGHTON
230
230
27.17
1
795 - ACSR - SING
216
RIO OSO
GOLD HILL
230
230
28.63
1
1113 - AAC - SING
217
RIO OSO
LOCKEFORD
230
230
65.13
1
1113 - AAC - SING
218
ROCK CREEK
POE
230
230
26.98
1
795 - ACSR - SING
219
ROSSMOOR #1 TAP
230
230
0.69
1
1113 - AAC - SING
220
ROSSMOOR #2 TAP
230
230
0.66
1
1113 - AAC - SING
221
ROUND MTN
COTTONWOOD #2
230
230
33.67
1
795 - ACSR - SING
222
ROUND MTN
COTTONWOOD #3
230
230
33.36
1
500 - CU - SINGLE
223
RUSSELL CITY ENERGY CENTER
EASTSHORE #1
230
230
1.19
1
1113 - AAC - BUND
224
RUSSELL CITY ENERGY CENTER
EASTSHORE #2
230
230
1.2
1
1113 - AAC - BUND
225
SAN MATEO
MARTIN
230
230
13
1
3500 KCMIL
226
SAN RAMON
MORAGA
230
230
22.24
1
954 - ACSR - SING
227
SAN RAMON RESEARCH CENTER T
230
230
3.27
1
1113 - AAC - SING
228
SANTA FE GEOTHERMAL TAP
230
230
1.04
1
1113 - AAC - SING
229
SARATOGA
VASONA
230
230
3.41
1
954 - ACSS - SING
230
SHILOH II
BIRDS LANDING SW STA
230
230
3.56
1
1431 - AAC - SING
231
SOLAR SW STA
CALIENTE SW STA #1
230
230
8.22
1
954 - ACSS - SING
232
SOLAR SW STA
CALIENTE SW STA #2
230
230
8.22
1
954 - ACSS - SING
233
SPI (BURNEY) TAP
230
230
0.05
1
795 - ACSR - SING
234
STAGG
TESLA
230
230
23.64
1
1113 - AAC - SING
235
STOCKDALE #1 TAP
230
230
6.23
1
795 - ACSR - SING
236
STOCKDALE #2 TAP
230
230
6.14
1
1113 - AAC - SING
237
TABLE MTN
PALERMO
230
230
14.57
1
795 - ACSS - SING
238
TABLE MTN
RIO OSO
230
230
50.17
1
795 - ACSS - SING
239
TASSAJARA
NEWARK
230
230
31.8
1
954 - AAC - SINGL
240
TEMPLETON
GATES
230
230
52.18
1
1113 - AAC - SING
241
TES TAP
230
230
3.28
1
1113 - AAC - SING
242
TESLA
NEWARK #2
230
230
40.88
1
954 - ACSS - PARA
243
TESLA
NEWARK #1
230
230
28.19
1
2300 - AAC - BUND
244
TESLA
RAVENSWOOD
230
230
37.14
1
2300 - AAC - BUND
245
TESLA
TRACY #1
230
230
5.68
1
954 - ACSS - SING
246
TESLA
TRACY #2
230
230
5.68
1
954 - ACSS - SING
247
TESLA
WESTLEY
230
230
45.06
1
795 - ACSR - BUND
248
TESORO
SOBRANTE
230
230
12.32
1
2300 - AAC - BUND
249
TIDEWATER
SOBRANTE
230
230
12.32
1
2300 - AAC - BUND
250
TIGER CREEK
ELECTRA
230
230
13.65
1
1113 - AAC - SING
251
TIGER CREEK
VALLEY SPRINGS
230
230
24.22
1
1113 - AAC - SING
252
TRANQUILLITY SW STA
HELM
230
230
12.68
1
1113 - ACSS - SIN
253
TRANQUILLITY SW STA
KEARNEY
230
230
36.9
1
1113 - ACSS - SIN
254
TULUCAY
VACA
230
230
23.63
1
954 - ACSR - SING
255
US WINDPOWER #3 TAP
230
230
0.06
1
1113 - AAC - SING
256
VACA
BAHIA
230
230
33.9
1
954 - ACSR - SING
257
VACA
PEABODY
230
230
9.69
1
1113 - ACSS - SIN
258
VACA
LAKEVILLE #1
230
230
40.93
1
954 - ACSR - SING
259
VACA
LAMBIE SW STA
230
230
13.95
1
1113 - ACSS - SIN
260
VACA
PARKWAY
230
230
27.76
1
954 - ACSR - SING
261
VACA DIXON
MORAGA #1
230
230
3.08
1
954 - ACSS - SING
262
VALLEY SPRINGS
BELLOTA
230
230
20.67
1
643.7 - SINGLE 50
263
VASONA
METCALF
230
230
13.29
1
954 - ACSS - SING
264
VINEYARD
NEWARK
230
230
14.36
1
795 - ACSR - SING
265
VINEYARD
NEWARK
230
230
5.94
1
2000 KCMIL - CU
266
WARNERVILLE
WILSON
230
230
38.4
1
954 - ACSR - SING
267
WEBER
TESLA
230
230
23.71
1
954 - ACSS - SING
268
WHEELER RIDGE PUMPING PLANT
230
230
0.25
1
1113 - AAC - SING
269
WHEELER RIDGE PUMPING PLANT
230
230
0.23
1
1113 - AAC - SING
270
WILSON
GREGG
230
230
41.44
1
795 - ACSR - SING
271
WILSON
BORDEN
230
230
35.37
1
500 - SINGLE 1113
272
WIND GAP PUMPING PLANT #1 T
230
230
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
0.11
1
1113 - AAC - SING
275
ZA
1
230
230
3.41
1
2000 KCMIL - CU
276
7TH STANDARD
KERN
115
115
6.75
1
715.5 - AAC - SIN
277
A
P #1
115
115
2.46
1
3500 KCMIL - CU
278
A
H-W #1
115
115
4.95
1
1250 KCMIL - CU
279
A
X #1
115
115
2.67
1
1250 KCMIL
280
A
Y #1
115
115
3.33
1
1250 KCMIL - CU
281
A
Y #2
115
115
2.85
1
3000 KCMIL - ALUM
282
A
H-W #2
115
115
5.06
1
1250 KCMIL
283
ADOBE SW STA
LAMONT
115
115
21.2
1
715.5 - AAC - SIN
284
AEC SITE #1 TAP
115
115
1.6
1
4/0 - AAC - SINGL
285
AEC SITE #2 TAP
115
115
2.16
1
286
AGNEW TAP
115
115
1.32
1
715.5 - AAC - SIN
287
AIR PRODUCTS TAP
115
115
0.29
1
4/0 - AAC - SINGL
288
AMERIGAS TAP
115
115
0.49
1
715.5 - AAC - SIN
289
AMES DISTRIBUTION
AMES
115
115
0.1
1
715.5 - AAC - SIN
290
APPLE HILL #1 TAP
115
115
1.42
1
4/0 - AAC - SINGL
291
APPLE HILL #2 TAP
115
115
1.43
1
397.5 - AAC - SIN
292
APPLIED MATERIALS
BRITTON
115
115
0.47
1
477 - ACSS - SING
293
APPLIED MATERIALS
BRITTON
115
115
0.74
1
2500 KCMIL - CU
294
ARVIN EDISON TAP
115
115
1.06
1
397.5 - AAC - SIN
295
ATLANTIC
PLEASANT GROVE #1
115
115
5.33
1
477 - ACSS - SING
296
ATLANTIC
PLEASANT GROVE #2
115
115
5.36
1
715.5 - AAC - SIN
297
ATWATER
EL CAPITAN
115
115
7.31
1
715.5 - AAC - SIN
298
ATWATER
LIVINGSTON-MERCED
115
115
24.26
1
715.5 - AAC - SIN
299
ATWATER
CRESSEY
115
115
5.91
1
715.5 - AAC - SIN
300
BADGER CREEK (PSE) TAP
115
115
1.07
1
715.5 - AAC - SIN
301
BAIR
BELMONT
115
115
3.64
1
477 - ACSS - SING
302
BALCH
SANGER
115
115
35.62
1
715.5 - AAC - SIN
303
BARKER SLOUGH TAP
115
115
1.62
1
4/0 - AAC - SINGL
304
BARTON
AIRWAYS-SANGER
115
115
11.65
1
2300 - AAC - SING
305
BEAR MTN TAP
115
115
1.27
1
715.5 - AAC - SIN
306
BEARDSLEY TAP
115
115
2.2
1
4/0 - ACSR - SING
307
BELL
PLACER
115
115
7.94
1
715.5 - AAC - SIN
308
BELLOTA
RIVERBANK-MELONES SW STA
115
115
44.65
1
715.5 - AAC - SIN
309
BELLOTA
RIVERBANK
115
115
18.87
1
715.5 - AAC - SIN
310
BELRIDGE TAP
115
115
6.94
1
715.5 - AAC - SIN
311
BIG BEND
CLAYTON #1
115
0.02
1
312
BOGUE
RIO OSO
115
115
21.24
1
1113 - AAC - SING
313
BOLLMAN #1 TAP
115
115
2.14
1
4/0 - AAC - SINGL
314
BOLLMAN #2 TAP
115
115
2.19
1
4/0 - AAC - SINGL
315
BOLTHOUSE FARMS TAP
115
115
0.11
1
4/0 - AAC - SINGL
316
BRIDGEVILLE
COTTONWOOD
115
115
86.06
1
397.5 - ACSR - SI
317
BRIGHTON
CLAYTON #1
115
115
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
42.73
1
715.5 - AAC - SIN
320
BRIGHTON
DAVIS
115
115
17.36
1
715.5 - AAC - SIN
321
BRIGHTON
GRAND ISLAND #1
115
115
24.99
1
715.5 - AAC - SIN
322
BRIGHTON
GRAND ISLAND #1
115
115
0.14
1
715.5 - AAC - SIN
323
BRIGHTON
GRAND ISLAND #2
115
115
25.04
1
715.5 - AAC - SIN
324
BRIGHTON
GRAND ISLAND #2
115
115
0.14
1
715.5 - AAC - SIN
325
BRITTON
MONTA VISTA
115
115
7.17
1
477 - ACSS - SING
326
BRUNSWICK #1 TAP
115
115
6.98
1
397.5 - ACSR - SI
327
BRUNSWICK #2 TAP
115
115
7
1
397.5 - ACSR - SI
328
BUELLTON TAP
115
115
1.75
1
397.5 - AAC - SIN
329
BUTTE
SYCAMORE CREEK
115
115
18.17
1
715.5 - AAC - SIN
330
BUTTE VALLEY
CARIBOU
115
115
7.42
1
795 - ACSR - SING
331
C
X #3
115
115
3.67
1
3500 KCMIL - CU
332
C
L #1
115
115
1.1
1
3000 KCMIL
333
C
X #2
115
115
3.38
1
1250 KCMIL - CU
334
CABRILLO
SANTA YNEZ SW STA
115
115
14.59
1
715.5 - AAC - SIN
335
CAL PEAK
VACA
115
115
0.11
1
715.5 - AAC - SIN
336
CAL WATER TAP
115
115
2.15
1
715.5 - AAC - SIN
337
CALIFORNIA AVE
MCCALL
115
115
23.66
1
477 - ACSS - SING
338
CALLENDER SW STA
MESA
115
115
13.77
1
715.5 - AAC - SIN
339
CAMANCHE TAP
115
115
6.71
1
4/0 - AAC - SINGL
340
CAMP EVERS
PAUL SWEET
115
115
5.22
1
715.5 - AAC - SIN
341
CANTUA TAP
115
115
1.83
1
397.5 - AAC - SIN
342
CARIBOU
PALERMO
115
115
54.89
1
715.5 - AAC - SIN
343
CARQUINEZ #1 TAP
115
115
0.51
1
397.5 - AAC - SIN
344
CARQUINEZ #2 TAP
115
115
0.52
1
397.5 - AAC - SIN
345
CARRIZO PLAINS TAP
115
115
0.04
1
715.5 - AAC - SIN
346
CASCADE
COTTONWOOD
115
115
19.46
1
250 - CU - SINGLE
347
CAWELO C TAP
115
115
1.33
1
397.5 - AAC - SIN
348
CERTAINTEED TAP
115
115
2.53
1
397.5 - AAC - SIN
349
CHARCA
FAMOSO
115
115
7.15
1
250 - CU - SINGLE
350
CHCF TAP
115
115
3
1
397.5 - AAC - SIN
351
CHENEY #1 TAP
115
115
4.1
1
397.5 - ACSR - SI
352
CHENEY #2 TAP
115
115
1.97
1
397.5 - AAC - SIN
353
CHINESE CAMP (ULTRA POWER)
115
115
2.07
1
4/0 - ACSR - SING
354
CHOWCHILLA
KERCKHOFF
115
115
42.52
1
715.5 - AAC - SIN
355
CHOWCHILLA #1 TAP
115
115
1.25
1
397.5 - AAC - SIN
356
CHRISTIE
SOBRANTE
115
115
7.84
1
715.5 - AAC - SIN
357
CITY #1 TAP
115
115
0.07
1
397.5 - AAC - SIN
358
CITY #2 TAP
115
115
1.37
1
397.5 - AAC - SIN
359
CLAYTON
MEADOW LANE
115
115
7.06
1
715.5 - AAC - SIN
360
COLES LEVEE TAP
115
115
0.22
1
4/0 - AAC - SINGL
361
COLUMBIA SOLAR 115kV TAP
115
115
0.45
1
4/0 - AAC - SINGL
362
CONTRA COSTA #1
115
115
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
2.72
1
715.5 - AAC - SIN
365
CORCORAN
OLIVE SW STA
115
115
36.83
1
1113 - AAC - SING
366
CORONA
LAKEVILLE
115
115
5.79
1
477 - ACSS - SING
367
CORTINA
MENDOCINO #1
115
115
60.95
1
397.5 - ACSR - SI
368
COTTONWOOD
PANORAMA
115
115
2.95
1
397.5 - AAC - SIN
369
CRAG VIEW
CASCADE
115
115
21.6
1
250 - CU - SINGLE
370
CRAZY HORSE CANYON
SAN BENITO
115
115
8.95
1
477 - ACSS - SING
371
CRAZY HORSE CANYON
HOLLISTER
115
115
17.23
1
2/0 - CU - SINGLE
372
CRAZY HORSE CANYON
SALINAS-SOLEDAD #1
115
115
35.35
1
3/0 - CU - SINGLE
373
CRAZY HORSE CANYON
SALINAS-SOLEDAD #2
115
115
35.41
1
477 - ACSS - SING
374
CYMRIC TAP
115
115
0.18
1
397.5 - AAC - SIN
375
D
L #1
115
115
2.31
1
3000 KCMIL
376
DAIRYLAND
MENDOTA
115
115
28.69
1
477 - ACSS - SING
377
DANISH CREAMERY TAP
115
115
1.2
1
4/0 - AAC - SINGL
378
DE FRANCESCO TAP
115
115
1.02
1
4/0 - AAC - SINGL
379
DEEPWATER #1 TAP
115
115
2.29
1
715.5 - AAC - SIN
380
DEEPWATER #2 TAP
115
115
2.45
1
715.5 - AAC - SIN
381
DISCOVERY TAP
115
115
2.1
1
715.5 - AAC - SIN
382
DIVIDE
CABRILLO #2
115
115
11.55
1
715.5 - AAC - SIN
383
DIVIDE
CABRILLO #1
115
115
14.6
1
715.5 - AAC - SIN
384
DIXON LANDING
MCKEE
115
115
8.3
1
477 - ACSS - SING
385
DOLAN RD #1 TAP
115
115
0.32
1
266.8 - AAC - SIN
386
DOLAN RD #2 TAP
115
115
0.33
1
266.8 - AAC - SIN
387
DONNELLS
CURTIS
115
115
26.81
1
397.5 - ACSR - SI
388
DOUBLE C (PSE) TAP
115
115
0.06
1
715.5 - AAC - SIN
389
DRUM
RIO OSO #1
115
115
44.64
1
266.8 - AAC - SIN
390
DRUM
RIO OSO #2
115
115
44.65
1
266.8 - AAC - SIN
391
DRUM
SUMMIT #1
115
115
27.36
1
397.5 - ACSR - SI
392
DRUM
SUMMIT #2
115
115
28.36
1
397.5 - ACSR - SI
393
DRUM
HIGGINS
115
115
47.75
1
715.5 - AAC - SIN
394
DRUM PH #2 TAP
115
115
0.09
1
250 - CU - SINGLE
395
DUMBARTON
NEWARK
115
115
7.14
1
795 - ACSS - SING
396
DUTCH FLAT #2 TAP
115
115
0.43
1
397
EAGLE ROCK
CORTINA
115
115
43.38
1
715.5 - AAC - SIN
398
EAGLE ROCK
REDBUD
115
115
23.31
1
715.5 - AAC - SIN
399
EAGLE ROCK
FULTON-SILVERADO
115
115
46.94
1
715.5 - AAC - SIN
400
EAST GRAND
SAN MATEO
115
115
7.89
1
477 - ACSS - SING
401
EAST GRAND
SAN MATEO
115
115
0.22
1
3000 KCMIL - ALUM
402
EASTSHORE
DUMBARTON
115
115
12.38
1
477 - ACSS - BUND
403
EASTSHORE
MT EDEN #1
115
115
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
0.48
1
397.5 - AAC - SIN
406
EBMUD TAP
115
115
0.02
1
407
EBMUD TAP
115
115
0.94
1
500 KCMIL
408
EDES #1 TAP
115
115
0.05
1
715.5 - AAC - SIN
409
EDES #2 TAP
115
115
0.04
1
715.5 - AAC - SIN
410
EL CAPITAN
WILSON
115
115
8.12
1
715.5 - AAC - SIN
411
EL DORADO
MISSOURI FLAT #1
115
115
14.43
1
715.5 - AAC - SIN
412
EL DORADO
MISSOURI FLAT #2
115
115
14.41
1
715.5 - AAC - SIN
413
EL PATIO
SAN JOSE A
115
115
7.08
1
715.5 - AAC - PAR
414
ELLIS TAP
115
115
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
5.24
1
715.5 - AAC 397.5
417
EXCELSIOR SW STA
SCHINDLER #2
115
115
5.23
1
715.5 - AAC 397.5
418
EXCHEQUER
LE GRAND
115
115
29.75
1
266.8 - AAC - SIN
419
FAIRVIEW
MARTINEZ SW STA
115
115
0.1
1
420
FAIRWAY #1 TAP
115
115
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
4.73
1
715.5 - AAC - SIN
423
FELLOWS
TAFT
115
115
7.93
1
715.5 - AAC - SIN
424
FIBREBOARD STANDARD TAP
115
115
0.02
1
425
FIBREBOARD TAP
115
115
1.03
1
4/0 - AAC - SINGL
426
FLINT TAP
115
115
1.96
1
4/0 - AAC - SINGL
427
FMC
SAN JOSE B
115
115
1.61
1
795 - ACSS - SING
428
FORBESTOWN TAP
115
115
0.22
1
397.5 - ACSR - SI
429
FRITO LAY TAP
115
115
0.53
1
4/0 - AAC - SINGL
430
FROGTOWN #1 TAP
115
115
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
59.9
1
715.5 - AAC - SIN
433
FULTON
SANTA ROSA #1
115
115
6.69
1
477 - ACSS - SING
434
FULTON
SANTA ROSA #2
115
115
6.29
1
477 - ACSS - SING
435
FULTON JCT
VACA
115
115
11.93
1
477 - ACSS - SING
436
GALLO
LIVINGSTON
115
115
4.2
1
715.5 - AAC - SIN
437
GALLO
CRESSEY
115
115
14.43
1
715.5 - AAC - SIN
438
GEYSERS #11
EAGLE ROCK
115
115
0.64
1
1113 - AAC - SING
439
GEYSERS #3
CLOVERDALE
115
115
12.07
1
715.5 - AAC - SIN
440
GEYSERS #3
EAGLE ROCK
115
115
1.77
1
715.5 - AAC - SIN
441
GEYSERS #5
GEYSERS #3
115
115
0.49
1
715.5 - AAC - SIN
442
GEYSERS #7
EAGLE ROCK
115
115
1.4
1
715.5 - AAC - SIN
443
GILL RANCH TAP
115
115
9.15
1
715.5 - AAC - SIN
444
GILROY ENERGY TAP
115
115
0.28
1
715.5 - AAC - BUN
445
GISH TAP
115
115
0.96
1
1 - UNKNOWN - UNK
446
GOLD HILL
BELLOTA-LOCKEFORD
115
115
87.28
1
715.5 - AAC - SIN
447
GOLD HILL
CLARKSVILLE
115
115
5.77
1
477 - ACSS - SING
448
GOLDEN VALLEY TAP
115
115
1.59
1
4/0 - AAC - SINGL
449
GOLDTREE TAP
115
115
2.3
1
397.5 - AAC - SIN
450
GRANT
EASTSHORE #1
115
115
4.33
1
715.5 - AAC - SIN
451
GRANT
EASTSHORE #2
115
115
4.2
1
715.5 - AAC - SIN
452
GREEN VALLEY
CAMP EVERS
115
115
18.59
1
715.5 - AAC - SIN
453
GREEN VALLEY
LLAGAS
115
115
24.85
1
715.5 - AAC - SIN
454
GREEN VALLEY
PAUL SWEET
115
115
16.03
1
715.5 - AAC - SIN
455
GREENLEAF #1 TAP
115
115
4.84
1
715.5 - AAC - SIN
456
GRIZZLY TAP (SVP)
115
115
0.16
1
457
GUARDIAN #1 TAP
115
115
0.75
1
4/0 - AAC - SINGL
458
GUARDIAN #2 TAP
115
115
0.13
1
4/0 - AAC - SINGL
459
GWF
KINGSBURG
115
115
21.62
1
1113 - AAC - SING
460
H
P #3
115
115
0.17
1
715.5 - AAC - SIN
461
H
P #4
115
115
5.16
1
3500 KCMIL - CU
462
H
P #1
115
115
3.8
1
1000 KCMIL - CU
463
H
Y #1
115
115
7.23
1
1250 KCMIL - CU
464
H
P #3
115
115
3.59
1
1250 KCMIL - CU
465
HEINZ TAP
115
0.79
1
4/0 - AAC - SINGL
466
HENRIETTA
LEPRINO SW STA
115
115
6.03
1
1113 - AAC - SING
467
HERNDON
BARTON
115
115
12.68
1
477 - ACSS 1431 -
468
HERNDON
BULLARD #1
115
115
11.43
1
954 - ACSS - SING
469
HERNDON
BULLARD #2
115
115
11.42
1
954 - ACSS - SING
470
HERNDON
MANCHESTER
115
115
9.27
1
1431 - AAC - SING
471
HERNDON
WOODWARD
115
115
12.97
1
1113 - AAC - SING
472
HIGGINS
BELL
115
115
18.77
1
715.5 - AAC - SIN
473
HONCUT TAP
115
115
1.65
1
4/0 - AAC - SINGL
474
HOWLAND ROAD TAP
115
115
0.9
1
4/0 - AAC - SINGL
475
HUMBOLDT
BRIDGEVILLE
115
115
30.28
1
397.5 - ACSR - SI
476
HUMBOLDT
TRINITY
115
115
68.57
1
4/0 - ACSR - SING
477
HUMBOLDT BAY
HUMBOLDT #1
115
115
6.31
1
397.5 - AAC - SIN
478
IBM BAILEY AVE TAP
115
115
2
1
397.5 - AAC - SIN
479
IBM HARRY RD #1 TAP
115
115
0.58
1
397.5 - AAC - SIN
480
IBM HARRY RD #2 TAP
115
115
0.58
1
397.5 - AAC - SIN
481
IGNACIO
MARE ISLAND #1
115
115
39.48
1
715.5 - AAC - SIN
482
IGNACIO
MARE ISLAND #2
115
115
43.08
1
715.5 - AAC - SIN
483
IGNACIO
SAN RAFAEL #1
115
115
11.54
1
715.5 - AAC - SIN
484
IGNACIO
SAN RAFAEL #3
115
115
8.65
1
715.5 - AAC - SIN
485
IMHOFF TAP
115
115
1.43
1
2 - UNKNOWN - UNK
486
INGRAM CREEK TAP
115
115
0.5
1
4/0 - AAC - SINGL
487
JAMESON CANYON PUMPING PLAN
115
115
0.19
1
4/0 - AAC - SINGL
488
JARVIS
CRYOGENICS
115
115
0.03
1
715.5 - AAC - SIN
489
JESSUP TAP
115
115
0.86
1
397.5 - ACSR - SI
490
K
D #1
115
115
2.44
1
2000 KCMIL - CU
491
K
D #2
115
115
2.57
1
3000 KCMIL - CU
492
KAMM TAP
115
115
0.52
1
4/0 - AAC - SINGL
493
KANAKA TAP
115
115
2.59
1
4/0 - ACSR - SING
494
KANSAS PV
LEPRINO SW STA
115
115
0.17
1
1113 - AAC - SING
495
KERCKHOFF
CLOVIS-SANGER #1
115
115
37.05
1
715.5 - AAC - SIN
496
KERCKHOFF
CLOVIS-SANGER #2
115
115
32.05
1
715.5 - AAC - SIN
497
KERCKHOFF #1
KERCKHOFF #2
115
115
1.58
1
AAC - SINGLE 266.
498
KERN
KERN FRONT
115
115
12.52
1
715.5 - AAC - SIN
499
KERN
TEVIS-STOCKDALE-LAMONT
115
115
21.52
1
715.5 - AAC - SIN
500
KERN
LIVE OAK
115
115
10.74
1
715.5 - AAC - SIN
501
KERN
MAGUNDEN-WITCO
115
115
19.58
1
715.5 - AAC - SIN
502
KERN
ROSEDALE
115
115
1.71
1
715.5 - AAC - SIN
503
KERN
TEVIS-STOCKDALE
115
115
19.74
1
715.5 - AAC - SIN
504
KERN
TEVIS-STOCKDALE (21KV)
115
115
0.67
1
715.5 - AAC - SIN
505
KERN
WESTPARK #1
115
115
3.84
1
715.5 - AAC - SIN
506
KERN
WESTPARK #2
115
115
3.83
1
715.5 - AAC - SIN
507
KERN OIL
DEXZEL
115
115
0.44
1
715.5 - AAC - SIN
508
KERN OIL
WITCO
115
115
4.2
1
715.5 - AAC - SIN
509
KERNWATER TAP
115
115
0.67
1
4/0 - AAC - SINGL
510
KIFER
FMC
115
115
6.01
1
715.5 - AAC - SIN
511
KIFER
FMC
115
115
1.11
1
512
KINGS RIVER
SANGER-REEDLEY
115
115
43.35
1
715.5 - AAC - SIN
513
KINGSBURG
CORCORAN #1
115
115
27.16
1
715.5 - AAC - SIN
514
KINGSBURG
WAUKENA SW STA
115
115
24.94
1
715.5 - AAC - SIN
515
KINGSBURG COGEN TAP
115
115
1.22
1
397.5 - AAC - SIN
516
KM GREEN TAP
115
115
0.2
1
397.5 - ACSR - SI
517
KYOHO TAP
115
115
2.2
1
397.5 - AAC - SIN
518
LAKEVILLE
SONOMA #1
115
115
6.68
1
477 - ACSS - SING
519
LAKEVILLE
SONOMA #2
115
115
7.18
1
477 - ACSS - SING
520
LAKEVILLE
SONOMA #1
115
115
0.55
1
2500 KCMIL - CU
521
LAKEWOOD
MEADOW LANE-CLAYTON
115
115
9.55
1
715.5 - AAC - SIN
522
LAKEWOOD
CLAYTON
115
115
5.52
1
477 - ACSS - SING
523
LAMMERS
KASSON
115
115
8.23
1
477 - ACSS - SING
524
LAMONT
GRIMMWAY MALAGA
115
115
3.55
1
4/0 - AAC - SINGL
525
LAS PALMAS TAP
115
115
0.85
1
4/0 - AAC - SINGL
526
LAS PLUMAS TAP
115
115
0.48
1
1113 - AAC - SING
527
LAWRENCE
MONTA VISTA
115
115
9.44
1
250 - CU - SINGLE
528
LAWRENCE LIVERMORE LAB #1 T
115
115
9
1
954 - ACSS - SING
529
LAWRENCE LIVERMORE LAB #2 T
115
115
9.41
1
2/0 - CU - SINGLE
530
LE GRAND
DAIRYLAND
115
115
11.4
1
715.5 - AAC - SIN
531
LE GRAND
CHOWCHILLA
115
115
10.94
1
1113 - AAC - SING
532
LEPRINO FOODS
LEPRINO SW STA
115
115
6.41
1
715.5 - AAC - SIN
533
LEPRINO FOODS (TRACY) TAP
115
115
0.02
1
4/0 - AAC - SINGL
534
LEPRINO SW STA
HENRIETTA PV
115
115
0.06
1
1113 - AAC - SING
535
LEPRINO SW STA
GWF HANFORD SW STA
115
115
12.38
1
1113 - AAC - SING
536
LERDO
KERN OIL-7TH STANDARD
115
115
16.35
1
715.5 - AAC - SIN
537
LERDO
FAMOSO
115
115
13.45
1
715.5 - AAC - SIN
538
LINCOLN
PLEASANT GROVE
115
115
7.38
1
715.5 - AAC - SIN
539
LINDE TAP
115
115
0.62
1
397.5 - AAC - SIN
540
LIVE OAK
KERN OIL
115
115
4.4
1
715.5 - AAC - SIN
541
LIVE OAK TAP
115
115
3.97
1
715.5 - AAC - SIN
542
LLAGAS
GILROY FOODS
115
115
1.98
1
715.5 - AAC - BUN
543
LLAGAS
HOLLISTER
115
115
21.56
1
3/0 - CU - SINGLE
544
LOCKHEED #1 TAP
115
115
1.72
1
397.5 - AAC - SIN
545
LOCKHEED #2 TAP
115
115
1.28
1
397.5 - AAC - SIN
546
LOS ESTEROS
MONTAGUE
115
115
4.64
1
795 - ACSS - SING
547
LOS ESTEROS
TRIMBLE
115
115
3.73
1
795 - ACSS - SING
548
LOS ESTEROS
AGNEW
115
115
1.37
1
715.5 - AAC - SIN
549
LOS ESTEROS
NORTECH
115
115
1.98
1
715.5 - AAC - BUN
550
LOWER LAKE
HOMESTAKE
115
115
16.12
1
4/0 - AAC - SINGL
551
LUCERNE #1 TAP
115
115
0.23
1
4/0 - ACSR - SING
552
LUCERNE #2 TAP
115
115
0.23
1
4/0 - ACSR - SING
553
MABURY TAP
115
115
2.81
1
715.5 - AAC - SIN
554
MADISON
VACA
115
115
22.99
1
3/0 - CU - SINGLE
555
MALAGA
KRCD
115
115
0.99
1
1113 - AAC - SING
556
MANCHESTER
AIRWAYS-SANGER
115
115
15.07
1
1431 - AAC - SING
557
MANTECA
VIERRA
115
115
3.98
1
477 - ACSS - SING
558
MANVILLE TAP
115
115
5.54
1
715.5 - AAC - SIN
559
MARTIN
DALY CITY #1
115
115
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
3.96
1
477 - ACSS - SING
562
MARTIN
MILLBRAE #1
115
115
7.28
1
477 - ACSS - SING
563
MARTIN
SF AIRPORT
115
115
5.43
1
477 - ACSS - SING
564
MARTIN
MILLBRAE #1
115
115
0.22
1
3000 KCMIL - ALUM
565
MARTIN
SF AIRPORT
115
115
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
16.4
1
715.5 - AAC - SIN
569
MCCALL
KINGSBURG #1
115
115
11.65
1
715.5 - AAC - SIN
570
MCCALL
KINGSBURG #2
115
115
11.57
1
715.5 - AAC - SIN
571
MCCALL
MALAGA
115
115
10.96
1
715.5 - AAC - SIN
572
MCCALL
REEDLEY
115
115
15.2
1
1113 - AAC - SING
573
MCCALL
SANGER #1
115
115
9.23
1
477 - ACSS - SING
574
MCCALL
SANGER #2
115
115
9.2
1
477 - ACSS - SING
575
MCCALL
SANGER #3
115
115
8.3
1
1113 - AAC - SING
576
MCCALL
WEST FRESNO #2
115
115
19.61
1
477 - ACSS - SING
577
MCKEE
PIERCY
115
115
7.75
1
477 - ACSS - SING
578
MELONES
CURTIS
115
115
14.8
1
715.5 - AAC - SIN
579
MELONES
RACETRACK
115
115
10.2
1
397.5 - AAC - SIN
580
MENDOCINO
REDBUD
115
115
34.83
1
397.5 - ACSR - SI
581
MENDOCINO
UKIAH
115
115
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
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
4.36
1
715.5 - AAC - SIN
586
MESA
SISQUOC
115
115
17.6
1
715.5 - AAC - SIN
587
METCALF
SALINAS #1
115
115
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
7.86
1
397.5 - AAC - SIN
590
METCALF
EDENVALE #1
115
115
5.73
1
715.5 - AAC - SIN
591
METCALF
EDENVALE #2
115
115
5.6
1
715.5 - AAC - SIN
592
METCALF
EL PATIO #1
115
115
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
10.63
1
715.5 - AAC - SIN
595
METCALF
GREEN VALLEY
115
115
25.28
1
715.5 - AAC - SIN
596
METCALF
MORGAN HILL
115
115
9.72
1
715.5 - AAC - SIN
597
METCALF
HICKS 1 & 2
115
115
6.62
1
1 - UNKNOWN - UNK
598
MIDSET TAP
115
115
0.72
1
715.5 - AAC - SIN
599
MIDSUN
MIDWAY
115
115
18.86
1
715.5 - AAC - SIN
600
MIDWAY
RENFRO-TUPMAN
115
115
22.6
1
1113 - AAC - SING
601
MIDWAY
TUPMAN-RIO BRAVO-RENFRO
115
115
26.59
1
266.8 - AAC - SIN
602
MIDWAY
SHAFTER
115
115
13.63
1
715.5 - AAC - SIN
603
MIDWAY
TAFT
115
115
19.33
1
715.5 - AAC - SIN
604
MIDWAY
TEMBLOR
115
115
14.53
1
336.4 - AAC - SIN
605
MIDWAY
SANTA MARIA
115
115
46.72
1
606
MILLBRAE
SAN MATEO #1
115
115
4.71
1
477 - ACSS - SING
607
MILLER #1 TAP
115
115
21.26
1
1113 - AAC - SING
608
MILLER #2 TAP
115
115
12.32
1
4/0 - AAC - SINGL
609
MILPITAS
SWIFT
115
115
8.86
1
477 - ACSS - SING
610
MISSION POWER TAP
115
115
1.94
1
397.5 - ACSR - SI
611
MISSOURI FLAT
GOLD HILL #1
115
115
19.73
1
715.5 - AAC - SIN
612
MISSOURI FLAT
GOLD HILL #2
115
115
19.69
1
715.5 - AAC - SIN
613
MOFFETT FIELD TAP
115
115
0.16
1
4/0 - AAC - SINGL
614
MONTA VISTA
WOLFE
115
115
2.72
1
477 - ACSS - SING
615
MONTA VISTA
WOLFE
115
115
1.12
1
CU
616
MONTAGUE
TRIMBLE
115
115
2.07
1
795 - ACSS - SING
617
MONTICELLO PH TAP
115
115
0.62
1
4/0 - AAC - SINGL
618
MORAGA
CLAREMONT #1
115
115
5.28
1
715.5 - AAC - SIN
619
MORAGA
CLAREMONT #2
115
115
5.3
1
715.5 - AAC - SIN
620
MORAGA
OAKLAND #1
115
115
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
5.05
1
715.5 - AAC - SIN
623
MORAGA
OAKLAND #4
115
115
5.05
1
715.5 - AAC - SIN
624
MORAGA
OAKLAND J
115
115
17.67
1
715.5 - AAC - SIN
625
MORAGA
SAN LEANDRO #1
115
115
11.14
1
715.5 - AAC - SIN
626
MORAGA
SAN LEANDRO #2
115
115
11.01
1
715.5 - AAC - SIN
627
MORAGA
SAN LEANDRO #3
115
115
11
1
715.5 - AAC - SIN
628
MORAGA
LAKEWOOD
115
115
15.11
1
954 - ACSR - SING
629
MORGAN HILL
LLAGAS
115
115
10.84
1
715.5 - AAC - SIN
630
MORRO BAY
SAN LUIS OBISPO #1
115
115
16.01
1
715.5 - AAC - SIN
631
MORRO BAY
SAN LUIS OBISPO #2
115
115
16.02
1
715.5 - AAC - SIN
632
MOSS LANDING
DEL MONTE #1
115
115
23.35
1
715.5 - AAC - SIN
633
MOSS LANDING
DEL MONTE #2
115
115
23.38
1
715.5 - AAC - SIN
634
MOSS LANDING
GREEN VALLEY #1
115
115
14.32
1
477 - ACSS - SING
635
MOSS LANDING
GREEN VALLEY #2
115
115
14.46
1
477 - ACSS - SING
636
MOSS LANDING
SALINAS #1
115
115
12
1
477 - ACSS - SING
637
MOSS LANDING
SALINAS #2
115
115
12.11
1
477 - ACSS - SING
638
MOSS LANDING
CRAZY HORSE CANYON #1
115
115
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
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
8.28
1
715.5 - AAC - SIN
644
NEWARK
APPLIED MATERIALS
115
115
11.37
1
477 - ACSS - SING
645
NEWARK
DIXON LANDING
115
115
4.69
1
477 - ACSS - SING
646
NEWARK
FREMONT #1
115
115
3.71
1
477 - ACSS - SING
647
NEWARK
FREMONT #2
115
115
3.75
1
477 - ACSS - SING
648
NEWARK
JARVIS #1
115
115
14.25
1
715.5 - AAC - SIN
649
NEWARK
JARVIS #2
115
115
14.48
1
715.5 - AAC - SIN
650
NEWARK
KIFER
115
115
10.61
1
715.5 - AAC - SIN
651
NEWARK
LAWRENCE
115
115
10.25
1
477 - ACSS - SING
652
NEWARK
LAWRENCE LAB
115
115
12.21
1
3/0 - CU - SINGLE
653
NEWARK
MILPITAS #1
115
115
8.48
1
477 - ACSS - SING
654
NEWARK
MILPITAS #2
115
115
10.3
1
1113 - AAC - SING
655
NEWARK
NUMMI
115
115
4.94
1
4/0 - CU - SINGLE
656
NEWARK
NORTHERN RECEIVING STATION
115
115
8.76
1
715.5 - AAC - SIN
657
NEWARK
NORTHERN RECEIVING STATION
115
115
8.67
1
715.5 - AAC - SIN
658
NEWARK
TRIMBLE
115
115
12.36
1
715.5 - AAC - SIN
659
NEWARK
AMES DISTRIBUTION
115
115
8.25
1
715.5 - AAC - SIN
660
NEWARK
APPLIED MATERIALS
115
115
0.74
1
2500 KCMIL - CU
661
NORTECH
NORTHERN RECEIVING STATION
115
115
2.21
1
795 - ACSS - SING
662
NORTH TOWER
MARTINEZ JCT #1 (21KV)
115
115
2.61
1
1 - UNKNOWN - UNK
663
NORTHERN RECEIVING STATION
SCOTT #1
115
115
2.08
1
477 - ACCR - SING
664
NORTHERN RECEIVING STATION
SCOTT #2
115
115
1.98
1
477 - ACSS - SING
665
NOTRE DAME
BUTTE
115
115
2.02
1
715.5 - AAC - SIN
666
OAKHURST TAP
115
115
18.16
1
4/0 - ACSR - SING
667
OAKLAND C
MARITIME
115
115
2.36
1
4/0 - ACSR - SING
668
OAKLAND C
TURBINES
115
115
0.19
1
715.5 - AAC - SIN
669
OAKLAND J
GRANT
115
115
14.81
1
715.5 - AAC - PAR
670
OCEANO
CALLENDER SW STA
115
115
4.22
1
715.5 - AAC - SIN
671
OLEUM
G #1
115
115
11.29
1
715.5 - AAC - SIN
672
OLEUM
G #2
115
115
11.3
1
715.5 - AAC - SIN
673
OLEUM
MARTINEZ
115
115
10.5
1
715.5 - AAC - SIN
674
OLEUM
NORTH TOWER-CHRISTIE
115
115
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
0.05
1
715.5 - AAC - SIN
677
OLIVE SW STA
SMYRNA
115
115
22.09
1
1113 - AAC - SING
678
OWENS BROCKWAY TAP
115
115
1.09
1
4/0 - AAC - SINGL
679
OWENS ILLINOIS TAP
115
115
0.68
1
4/0 - AAC - SINGL
680
OXFORD TAP
115
115
3.87
1
4/0 - AAC - SINGL
681
P
X #2
115
115
0.28
1
682
P
X #1
115
115
4.01
1
1000 KCMIL - CU
683
P
X #2 (UNDERGROUND)
115
115
3.95
1
1000 KCMIL - CU
684
PALERMO
BOGUE
115
115
35.74
1
1113 - AAC - SING
685
PALERMO
NICOLAUS
115
115
41.18
1
1113 - AAC - SING
686
PALERMO
PEASE
115
115
26.53
1
715.5 - AAC - SIN
687
PALERMO
WYANDOTTE
115
115
5.3
1
715.5 - AAC - SIN
688
PANOCHE
CAL PEAK-STARWOOD
115
115
0.1
1
715.5 - AAC - BUN
689
PANOCHE
MENDOTA
115
115
10.08
1
477 - ACSS - SING
690
PANOCHE
ORO LOMA
115
115
18.96
1
477 - ACSS - SING
691
PANOCHE
EXCELSIOR SW STA #1
115
115
28.5
1
715.5 - AAC - SIN
692
PANOCHE
EXCELSIOR SW STA #2
115
115
28.5
1
715.5 - AAC - SIN
693
PARADISE
TABLE MTN
115
115
33.73
1
715.5 - AAC - SIN
694
PARADISE
BUTTE
115
115
13.58
1
715.5 - AAC - SIN
695
PARAMOUNT FARMS TAP
115
115
0.57
1
4/0 - AAC - SINGL
696
PEASE
RIO OSO
115
115
27.61
1
336.4 - ACSR - SI
697
PENNGROVE SUB TAP
115
115
0.81
1
4/0 - AAC - SINGL
698
PEORIA TAP
115
115
0.85
1
397.5 - ACSR - SI
699
PIERCY
METCALF
115
115
4.72
1
477 - ACSS - SING
700
PITTSBURG
CLAYTON #1
115
115
16.82
1
715.5 - AAC - PAR
701
PITTSBURG
CLAYTON #3
115
115
8.41
1
715.5 - AAC - BUN
702
PITTSBURG
CLAYTON #4
115
115
8.32
1
715.5 - AAC - BUN
703
PITTSBURG
COLUMBIA STEEL
115
115
9.23
1
715.5 - AAC - SIN
704
PITTSBURG
LOS MEDANOS #1
115
115
0.54
1
2300 - AAC - BUND
705
PITTSBURG
LOS MEDANOS #2
115
115
0.54
1
2300 - AAC - BUND
706
PITTSBURG
KIRKER-COLUMBIA STEEL
115
115
9.26
1
715.5 - AAC - SIN
707
PITTSBURG
MARTINEZ #1
115
115
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
0.88
1
3000 KCMIL - CU
710
PITTSBURG
LOS MEDANOS #2
115
115
0.89
1
3000 KCMIL - CU
711
PLACER
GOLD HILL #1
115
115
20.67
1
2300 - AAC - SING
712
PLACER
GOLD HILL #2
115
115
20.67
1
2300 - AAC - SING
713
POINT PINOLE TAP
115
115
1.3
1
715.5 - AAC - SIN
714
POST OFFICE TAP
115
115
0.75
1
4/0 - AAC - SINGL
715
PSE MCKITTRICK TAP
115
115
5.21
1
715.5 - AAC - SIN
716
QUEBEC TAP
115
115
4.35
1
4/0 - AAC - SINGL
717
RACETRACK TAP
115
115
3.55
1
397.5 - AAC - SIN
718
RAINBOW TAP
115
115
2.59
1
715.5 - AAC - SIN
719
RANCHERS COTTON TAP
115
115
2.1
1
397.5 - AAC - SIN
720
RAVENSWOOD
AMES #1
115
115
7.07
1
477 - ACSS - SING
721
RAVENSWOOD
AMES #2
115
115
7.09
1
477 - ACSS - SING
722
RAVENSWOOD
BAIR #1
115
115
7.43
1
715.5 - AAC - SIN
723
RAVENSWOOD
BAIR #2
115
115
11.29
1
715.5 - AAC - SIN
724
RAVENSWOOD
COOLEY LANDING #1
115
115
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
4.28
1
715.5 - AAC - SIN
727
RAVENSWOOD
PALO ALTO #2
115
115
4.26
1
715.5 - AAC - SIN
728
RAVENSWOOD
SAN MATEO
115
115
12.04
1
715.5 - AAC - SIN
729
RINCON #1 TAP
115
115
0.57
1
397.5 - AAC - SIN
730
RINCON #2 TAP
115
115
0.55
1
397.5 - AAC - SIN
731
RIO BRAVO
KERN OIL
115
115
7.28
1
266.8 - AAC - SIN
732
RIO BRAVO (FRESNO) TAP
115
115
0.32
1
4/0 - AAC - SINGL
733
RIO BRAVO (ROCKLIN) TAP
115
115
0.4
1
4/0 - AAC - SINGL
734
RIO BRAVO TOMATO TAP
115
115
0.43
1
1113 - AAC - SING
735
RIO OSO
LINCOLN
115
115
11.02
1
1113 - AAC - SING
736
RIO OSO
NICOLAUS
115
115
5.39
1
1113 - AAC - SING
737
RIO OSO
WEST SACRAMENTO
115
115
43.56
1
336.4 - ACSR - SI
738
RIO OSO
WOODLAND #1
115
115
45.25
1
715.5 - AAC - SIN
739
RIO OSO
WOODLAND #2
115
115
53.37
1
715.5 - AAC - SIN
740
RIPON TAP
115
115
4.64
1
397.5 - AAC - SIN
741
RIVERBANK JCT SW STA
MANTECA
115
115
17.65
1
4/0 - ACSR - SING
742
SAFEWAY TAP
115
115
0.68
1
477 - ACSS - SING
743
SALT SPRINGS
TIGER CREEK
115
115
16.48
1
4/0 - CU - SINGLE
744
SAN BENITO
HOLLISTER
115
115
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
0.04
1
715.5 - AAC - SIN
747
SAN JOSE A
SAN JOSE B
115
115
1.15
1
1113 - AAC - SING
748
SAN JOSE B
STONE-EVERGREEN
115
115
8.56
1
1113 - AAC - SING
749
SAN LEANDRO
OAKLND J #1
115
115
6.7
1
715.5 - AAC - SIN
750
SAN LUIS #3 TAP
115
115
16.11
1
397.5 - ACSR - SI
751
SAN LUIS #5 TAP
115
115
1.88
1
397.5 - ACSR - SI
752
SAN LUIS OBISPO
OCEANO
115
115
19.9
1
715.5 - AAC - SIN
753
SAN LUIS OBISPO
SANTA MARIA
115
115
25.96
1
336.4 - AAC - SIN
754
SAN MATEO
BAY MEADOWS #1
115
115
4.3
1
4/0 - CU - SINGLE
755
SAN MATEO
BAY MEADOWS #2
115
115
4.26
1
4/0 - CU - SINGLE
756
SAN MATEO
BELMONT
115
115
7.2
1
715.5 - AAC - SIN
757
SAN MATEO
MARTIN #3
115
115
11.55
1
477 - ACSS - SING
758
SAN MATEO
MARTIN #6
115
115
11.68
1
477 - ACSS - SING
759
SAN MATEO
MARTIN #4
115
115
11.64
1
477 - ACSS - SING
760
SAN MATEO
MARTIN #4
115
115
0.21
1
3000 KCMIL - ALUM
761
SAN MATEO
MARTIN #3
115
115
0.21
1
3000 KCMIL - ALUM
762
SAN MATEO
MARTIN #6
115
115
0.23
1
3000 KCMIL - ALUM
763
SAN PABLO #1 TAP
115
115
0.44
1
715.5 - AAC - SIN
764
SAN PABLO #2 TAP
115
115
0.45
1
715.5 - AAC - SIN
765
SANDBAR TAP
115
115
0.09
1
397.5 - ACSR - SI
766
SANGER
MALAGA
115
115
8.82
1
715.5 - AAC - SIN
767
SANGER
CALIFORNIA AVE
115
115
9.33
1
1113 - AAC - SING
768
SANGER
REEDLEY
115
115
20.42
1
1113 - AAC - SING
769
SANGER COGEN TAP
115
115
0.83
1
715.5 - AAC - SIN
770
SANTA MARIA
SISQUOC
115
115
10.57
1
715.5 - AAC - SIN
771
SANTA MARIA COGEN TAP
115
115
0.24
1
397.5 - AAC - SIN
772
SANTA PAULA
MILLBRAE
115
115
0.09
1
397.5 - AAC - SIN
773
SANTA ROSA
CORONA
115
115
14.39
1
477 - ACSS - SING
774
SANTA YNEZ TAP
115
115
4.06
1
397.5 - AAC - SIN
775
SARGENT SW STA
HOLLISTER
115
115
1.54
1
1 - UNKNOWN - UNK
776
SCHULTE SW STA
LAMMERS
115
115
0.69
1
954 - ACSS - SING
777
SCHULTE SW STA
KASSON-MANTECA
115
115
16.56
1
477 - ACSS - SING
778
SEMITROPIC
CHARCA
115
115
6.91
1
397.5 - AAC - SIN
779
SEMITROPIC
MIDWAY #1
115
115
14.1
1
1113 - AAC - SING
780
SEMITROPIC
MIDWAY #2
115
115
20.11
1
715.5 - AAC - SIN
781
SERRAMONTE TAP
115
115
2.55
1
397.5 - AAC - SIN
782
SF AIRPORT
SAN MATEO
115
115
6.09
1
477 - ACSS - SING
783
SHAFTER
RIO BRAVO
115
115
8.31
1
715.5 - AAC - SIN
784
SHARON PRISON TAP
115
115
2.57
1
4/0 - AAC - SINGL
785
SHREDDER TAP
115
115
1.38
1
2/0 - CU - SINGLE
786
SIERRA #1
115
115
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
1.81
1
715.5 - AAC - SIN
789
SIERRA PACIFIC IND TAP
115
115
0.06
1
4/0 - AAC - SINGL
790
SILVERADO
FULTON JCT
115
115
26.16
1
4/0 - CU - SINGLE
791
SISQUOC
GAREY
115
115
5.02
1
397.5 - AAC - SIN
792
SISQUOC
SANTA YNEZ SW STA
115
115
22.12
1
715.5 - AAC - SIN
793
SKAGGS ISLAND #1 TAP
115
115
0.59
1
4/0 - AAC - SINGL
794
SKAGGS ISLAND #2 TAP
115
115
0.6
1
4/0 - AAC - SINGL
795
SLY CREEK TAP
115
115
5.34
1
4/0 - ACSR - SING
796
SMYRNA
SEMITROPIC-MIDWAY
115
115
44.65
1
266.8 - AAC - SIN
797
SOBRANTE
G #1
115
115
5.34
1
715.5 - AAC - SIN
798
SOBRANTE
G #2
115
115
5.39
1
715.5 - AAC - SIN
799
SOBRANTE
GRIZZLY-CLAREMONT #1
115
115
19.58
1
715.5 - AAC - SIN
800
SOBRANTE
MORAGA
115
115
5.68
1
1113 - AAC - SING
801
SOBRANTE
GRIZZLY-CLAREMONT #2
115
115
19.3
1
715.5 - AAC - SIN
802
SOBRANTE
R #1
115
115
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
18.89
1
715.5 - AAC - SIN
805
SOBRANTE
STANDARD OIL SW STA #1
115
115
18.89
1
715.5 - AAC - SIN
806
SOBRANTE
R #1
115
115
4.16
1
3000 KCMIL - ALUM
807
SOBRANTE
R #2
115
115
4.11
1
808
SONOMA
PUEBLO
115
115
18.48
1
715.5 - AAC - SIN
809
SPRING GAP TAP
115
115
1.64
1
397.5 - ACSR - SI
810
STANISLAUS
MANTECA #2
115
115
53.95
1
715.5 - AAC - SIN
811
STANISLAUS
MELONES SW STA-MANTECA #1
115
115
61.15
1
715.5 - AAC - SIN
812
STANISLAUS
MELONES SW STA-RIVERBANK JC
115
115
43.8
1
715.5 - AAC - SIN
813
STANISLAUS
NEWARK #1 (12KV)
115
115
15.05
1
2/0 - CU - SINGLE
814
STANISLAUS
NEWARK #2 (12KV)
115
115
18.17
1
2/0 - CU - SINGLE
815
STELLING
MONTA VISTA
115
115
1.61
1
477 - ACSS - SING
816
STELLING
WOLFE
115
115
1.46
1
477 - ACSS - SING
817
STELLING
MONTA VISTA
115
115
1.14
1
CU
818
STOCKTON A
LOCKEFORD-BELLOTA #1
115
115
34.77
1
715.5 - AAC - SIN
819
STOCKTON A
LOCKEFORD-BELLOTA #2
115
115
34.49
1
715.5 - AAC - SIN
820
STONE
EVERGREEN-METCALF
115
115
12.86
1
715.5 - AAC - SIN
821
STONY POINT TAP
115
115
3.08
1
397.5 - AAC - SIN
822
SURF TAP
115
115
11.38
1
397.5 - AAC - SIN
823
SWIFT
METCALF
115
115
8.93
1
477 - ACSS - SING
824
SYCAMORE CREEK
NOTRE DAME-TABLE MTN
115
115
20.33
1
715.5 - AAC - SIN
825
TABLE MTN
BUTTE #1
115
115
19.54
1
715.5 - AAC - SIN
826
TABLE MTN
BUTTE #2
115
115
15.82
1
715.5 - AAC - SIN
827
TAFT
CHALK CLIFF
115
115
7.18
1
715.5 - AAC - SIN
828
TEICHERT TAP
115
115
2.11
1
4/0 - AAC - SINGL
829
TEMBLOR
KERNRIDGE
115
115
4.78
1
715.5 - AAC - SIN
830
TEMBLOR
SAN LUIS OBISPO
115
115
57.79
1
715.5 - AAC - SIN
831
TESLA
SCHULTE SW STA #2
115
115
7.34
1
715.5 - AAC - SIN
832
TESLA
SCHULTE SW STA #1
115
115
7.39
1
715.5 - AAC - SIN
833
TESLA
SALADO #1
115
115
32.07
1
715.5 - AAC - SIN
834
TESLA
SALADO-MANTECA
115
115
53.96
1
715.5 - AAC - SIN
835
TESLA
STOCKTON COGEN JCT
115
115
44.47
1
715.5 - AAC - SIN
836
TESLA
TRACY
115
115
25.23
1
1113 - AAC - SING
837
THERMAL ENERGY TAP
115
115
0.74
1
715.5 - AAC - SIN
838
TRIMBLE
SAN JOSE B
115
115
2.53
1
715.5 - AAC - SIN
839
TRIMBLE
SAN JOSE B
115
115
1.11
1
840
TRINITY
COTTONWOOD
115
115
45.97
1
336.4 - ACAR - SI
841
TULLOCH TAP
115
115
0.31
1
397.5 - AAC - SIN
842
TUPMAN-NORCO TAP
115
115
6.67
1
715.5 - AAC - SIN
843
UC DAVIS #1 TAP
115
115
1.64
1
715.5 - AAC - SIN
844
UC DAVIS #2 TAP
115
115
1.61
1
715.5 - AAC - SIN
845
UKIAH
HOPLAND-CLOVERDALE
115
115
31.17
1
715.5 - AAC - SIN
846
ULTRAPOWER (OGLE) TAP
115
115
2.45
1
1113 - AAC - SING
847
UNION OIL TAP
115
115
0.5
1
4/0 - AAC - SINGL
848
UNITED COGEN INC TAP
115
115
0.68
1
397.5 - AAC - SIN
849
UNIVERSITY COGEN TAP
115
115
0.22
1
715.5 - AAC - SIN
850
VACA
SUISUN
115
115
23.06
1
715.5 - AAC - SIN
851
VACA
SUISUN-JAMESON
115
115
25.46
1
715.5 - AAC - SIN
852
VACA
VACAVILLE-CORDELIA
115
115
22.04
1
715.5 - AAC - SIN
853
VACA
VACAVILLE-JAMESON-NORTH TOW
115
115
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
0.96
1
715.5 - AAC - SIN
856
VALLEY VIEW #2 TAP
115
115
0.97
1
715.5 - AAC - SIN
857
VEDDER TAP
115
115
11.09
1
3/0 - AAC - SINGL
858
VIERRA
TRACY-KASSON
115
115
10.49
1
715.5 - AAC - SIN
859
WASCO PRISON TAP
115
115
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
4.9
1
715.5 - AAC - SIN
862
WEST SACRAMENTO
BRIGHTON
115
115
13.97
1
477 - ACSS - SING
863
WEST SACRAMENTO
DAVIS
115
115
12.14
1
715.5 - AAC - SIN
864
WESTLANDS #1 RA PUMPING PLA
115
115
1.05
1
4/0 - AAC - SINGL
865
WESTLANDS #18 RA TAP
115
115
3.52
1
4/0 - AAC - SINGL
866
WESTPARK
MAGUNDEN
115
115
12.29
1
715.5 - AAC - SIN
867
WHEELER RIDGE
ADOBE SW STA
115
115
1.34
1
715.5 - AAC - SIN
868
WHISMAN
MONTA VISTA
115
115
5.97
1
715.5 - AAC - SIN
869
WHISMAN
MTN VIEW
115
115
3.54
1
715.5 - AAC - SIN
870
WILSON
DAIRYLAND (12KV)
115
115
11.37
1
266.8 - AAC - SIN
871
WILSON
ATWATER #2
115
115
15.41
1
715.5 - AAC - SIN
872
WILSON
LE GRAND
115
115
14.04
1
715.5 - AAC - SIN
873
WILSON
MERCED #1
115
115
5.58
1
715.5 - AAC - SIN
874
WILSON
MERCED #2
115
115
6.2
1
266.8 - AAC - SIN
875
WILSON
ORO LOMA
115
115
43.56
1
715.5 - AAC - SIN
876
WITCO (REFINERY) TAP
115
115
0.03
1
4/0 - AAC - SINGL
877
WOODLAND
DAVIS
115
115
11.71
1
715.5 - AAC - SIN
878
WOODLAND BIOMASS TAP
115
115
0.87
1
4/0 - AAC - SINGL
879
WOODLEAF
PALERMO
115
115
19.62
1
715.5 - AAC - SIN
880
WOODWARD
SHEPHERD
115
115
4.84
1
2300 - AAC - SING
881
X
Y #1
115
115
0.57
1
1250 KCMIL - CU
882
ZAMORA TAP
115
115
1.92
1
397.5 - AAC - SIN
883
ZANKER #1 TAP
115
115
0.6
1
715.5 - AAC - SIN
884
ZANKER #2 TAP
115
115
0.72
1
4/0 - AAC - SINGL
885
AERA ENERGY TAP
70
60
0.35
1
397.5 - ALUM - SI
886
ANTELOPE TAP
70
70
4.33
1
4/0 - AAC - SINGL
887
ARBURUA TAP
70
70
3.57
1
2 - ACSR - SINGLE
888
ARCO
CARNERAS
70
70
17.97
1
715.5 - AAC - SIN
889
ARCO
CHOLAME
70
70
26.74
1
397.5 - AAC - SIN
890
ARCO
POLONIO PASS PP
70
70
21.27
1
715.5 - AAC - SIN
891
ARCO
TULARE LAKE
70
70
16.11
1
3/0 - AAC - SINGL
892
ARCO
TWISSELMAN
70
70
6.52
1
715.5 - AAC - SIN
893
ARMSTRONG TAP
70
70
0.44
1
4/0 - AAC - SINGL
894
ATASCADERO
CAYUCOS
70
70
11.8
1
3/0 - AAC - SINGL
895
ATASCADERO
SAN LUIS OBISPO
70
70
15.47
1
715.5 - AAC - SIN
896
AUBERRY TAP
70
70
2.27
1
1/0 - ACSR - SING
897
AVENAL TAP
70
70
5.4
1
397.5 - AAC - SIN
898
BADGER HILL TAP
70
70
1.56
1
1/0 - ACSR - SING
899
BERRENDA A TAP
70
70
2.25
1
4/0 - AAC - SINGL
900
BERRENDA C TAP
70
70
1.87
1
4/0 - AAC - SINGL
901
BIOLA
GLASS-MADERA
70
70
18.84
1
715.5 - AAC - SIN
902
BONITA TAP
70
70
3.04
1
2 - CU - SINGLE
903
BORDEN
COPPERMINE
70
70
19.95
1
4/0 - CU - SINGLE
904
BORDEN
GLASS
70
70
6.62
1
715.5 - AAC - SIN
905
BORDEN
MADERA #2
70
70
5.81
1
715.5 - AAC - SIN
906
BORDEN
MADERA #1
70
70
4.91
1
715.5 - AAC - SIN
907
BORDEN
GLASS; XLPE; 70 KV
70
70
0.39
1
1750 KCMIL - ALUM
908
BOSWELL TAP
70
70
1.39
1
4/0 - ACSR - SING
909
BRICEBURG JCT-MARIPOSA TAP
70
70
7.78
1
715.5 - AAC - SIN
910
CADET TAP
70
70
0.12
1
397.5 - AAC - SIN
911
CALIFORNIA AVE
KEARNEY
70
70
3.2
1
715.5 - AAC - SIN
912
CAMDEN
KINGSBURG
70
70
14.91
1
266.8 - AAC - SIN
913
CANANDAIGUA WINERY TAP
70
70
0.29
1
4/0 - AAC - SINGL
914
CARNATION TAP
70
70
0.61
1
4/0 - AAC - SINGL
915
CARNERAS
TAFT
70
70
34.92
1
3/0 - AAC - SINGL
916
CARUTHERS
LEMOORE NAS-CAMDEN
70
70
25.17
1
3/0 - AAC - SINGL
917
CASTAIC TAP
70
70
0.02
1
2 - ACSR - SINGLE
918
CAWELO B TAP
70
70
0.4
1
4/0 - AAC - SINGL
919
CAYUCOS
CAMBRIA
70
70
17.73
1
307.1 - AAC - SIN
920
CELERON TAP
70
70
0.04
1
4/0 - AAC - SINGL
921
CHEVRON (LOST HILLS) TAP
70
70
14.75
1
397.5 - AAC - SIN
922
CHEVRON PIPELINE KETTLEMAN
70
70
1.17
1
4/0 - AAC - SINGL
923
COALINGA #1
COALINGA #2
70
70
8.61
1
1113 - AAC - SING
924
COALINGA #1
SAN MIGUEL
70
70
38.01
1
266.8 - ACSR - SI
925
COALINGA COGEN TAP
70
70
4.91
1
715.5 - AAC - SIN
926
COPPERMINE
TIVY VALLEY
70
70
24.01
1
715.5 - AAC - SIN
927
COPUS
OLD RIVER
70
70
19.61
1
715.5 - AAC - SIN
928
CORCORAN
ANGIOLA
70
70
8.96
1
4/0 - CU - SINGLE
929
CORCORAN
GUERNSEY
70
70
13.57
1
1113 - AAC - SING
930
CRESCENT SW STA
SCULPIN PV
70
0.04
1
1113 - AAC - SING
931
CRESCENT SW STA
SCHINDLER
70
70
10.8
1
1113 - AAC - SING
932
CRESCENT SW STA
STROUD
70
70
3.61
1
1113 - AAC - SING
933
DERRICK TAP
70
70
0.85
1
397.5 - AAC - SIN
934
DINOSAUR POINT TAP
70
70
2
1
2/0 - CU - SINGLE
935
DINUBA
OROSI
70
70
9.83
1
715.5 - AAC - SIN
936
DINUBA ENERGY TAP
70
70
3.16
1
397.5 - AAC - SIN
937
DIVIDE
VANDENBERG #1
70
70
6.64
1
266.8 - AAC - SIN
938
DIVIDE
VANDENBERG #2
70
70
6.57
1
715.5 - AAC - SIN
939
DIVIDE
ZACA-LOMPOC (12KV)
70
70
10.55
1
397.5 - AAC - SIN
940
DUNLAP TAP
70
70
16.21
1
715.5 - AAC - SIN
941
EISEN TAP
70
70
1.86
1
1/0 - ACSR - SING
942
EL PECO TAP
70
70
3.02
1
397.5 - AAC - SIN
943
EMIDIO TAP
70
70
3.07
1
1/0 - ACSR - SING
944
EXCHEQUER
MARIPOSA
70
70
19.3
1
715.5 - AAC - SIN
945
EXCHEQUER
YOSEMITE
70
70
34.91
1
3/0 - ACSR - SING
946
FIVE POINTS SW
WHITNEY POINT PV
70
70
0.06
1
715.5 - AAC - SIN
947
FIVE POINTS SW STA
HURON-GATES
70
70
19.78
1
715.5 - AAC - SIN
948
FRESNO COGEN (AGRICO) TAP
70
70
3.17
1
715.5 - AAC - SIN
949
FRIANT
COPPERMINE
70
70
8.3
1
715.5 - AAC - SIN
950
FRUITVALE TAP
70
70
0.12
1
4/0 - CU - SINGLE
951
GARDNER TAP
70
70
3.77
1
4/0 - AAC - SINGL
952
GATES
JAYNE SW STA
70
70
0.68
1
715.5 - AAC - SIN
953
GATES
COALINGA #2
70
70
17.26
1
715.5 - AAC - SIN
954
GATES
HURON
70
70
4.5
1
715.5 - AAC - SIN
955
GATES
TULARE LAKE
70
70
18.34
1
715.5 - AAC - SIN
956
GIFFEN TAP
70
70
4.95
1
1113 - AAC - SING
957
GRAPEVINE TAP
70
70
0.14
1
1/0 - ACSR - SING
958
GUERNSEY
HENRIETTA
70
70
18.44
1
266.8 - AAC - SIN
959
GWF
HENRIETTA
70
70
0.12
1
477 - ACSS - SING
960
GWF HANFORD COGEN TAP
70
70
0.32
1
397.5 - AAC - SIN
961
HAAS
WOODCHUCK
70
70
6.79
1
4/0 - ACSR - SING
962
HARDWICK TAP
70
70
2.74
1
266.8 - AAC - SIN
963
HELM
KERMAN
70
70
13.25
1
715.5 - AAC - SIN
964
HELM
CRESCENT SW STA
70
70
4.92
1
715.5 - AAC - SIN
965
HELM
STROUD
70
70
7.43
1
715.5 - AAC - SIN
966
HENRIETTA
LEMOORE
70
70
9.37
1
715.5 - AAC - SIN
967
HENRIETTA
LEMOORE NAS
70
70
1.69
1
715.5 - AAC - SIN
968
HENRIETTA
KENT SW STA
70
70
1.47
1
715.5 - AAC - SIN
969
HERDLYN
TRACY
70
70
2.06
1
715.5 - AAC - SIN
970
JAYNE SW STA
COALINGA
70
70
11.81
1
715.5 - AAC - SIN
971
KEARNEY
BIOLA
70
70
19.13
1
4/0 - CU - SINGLE
972
KEARNEY
BOWLES
70
70
9.29
1
4/0 - AAC - SINGL
973
KEARNEY
CARUTHERS
70
70
12.05
1
715.5 - AAC - SIN
974
KEARNEY
KERMAN
70
70
10.98
1
715.5 - AAC - SIN
975
KEARNEY ALTERNATE TIE
70
70
0.3
1
1113 - AAC - SING
976
KEARNEY TIE
70
70
0.15
1
1113 - AAC - SING
977
KELLEY TAP
70
70
2.79
1
1/0 - ACSR - SING
978
KENT SW STA
TULARE LAKE
70
70
15.93
1
715.5 - AAC - SIN
979
KERN
FRUITVALE
70
70
0.16
1
397.5 - AAC - SIN
980
KERN
KERN OIL-FAMOSO
70
70
24.69
1
715.5 - AAC - SIN
981
KERN
MAGUNDEN
70
70
20.61
1
715.5 - AAC - SIN
982
KERN
OLD RIVER #1
70
70
11.94
1
795 - ACSS - SING
983
KERN
OLD RIVER #2
70
70
23.07
1
1/0 - CU - SINGLE
984
KERN CANYON
MAGUNDEN-WEEDPATCH
70
70
20.65
1
397.5 - AAC - SIN
985
KETTLEMAN HILLS TAP
70
70
1.02
1
715.5 - AAC - SIN
986
KINGSBURG
LEMOORE
70
70
27.49
1
3/0 - CU - SINGLE
987
LAS PERILLAS TAP
70
70
0.39
1
1/0 - ACSR - SING
988
LEPRINO TAP
70
70
0.47
1
4/0 - AAC - SINGL
989
LIGHTNER TAP
70
70
3.06
1
1 - UNKNOWN - UNK
990
LIVINGSTON
LIVINGSTON JCT
70
70
23.36
1
715.5 - AAC - SIN
991
LOS BANOS
MERCY SPRINGS SW STA
70
70
14.73
1
715.5 - AAC - SIN
992
LOS BANOS
LIVINGSTON JCT-CANAL
70
70
14.29
1
715.5 - AAC - SIN
993
LOS BANOS
O'NEILL PGP
70
70
3.88
1
715.5 - AAC - SIN
994
LOS BANOS
PACHECO
70
70
20.78
1
715.5 - AAC - SIN
995
LOST HILLS TAP
70
70
2.89
1
1/0 - ACSR - SING
996
MARICOPA
COPUS
70
70
7.86
1
715.5 - AAC - SIN
997
MCFARLAND TAP
70
70
5.99
1
1/0 - CU - SINGLE
998
MCSWAIN TAP
70
70
1.37
1
4/0 - AAC - SINGL
999
MENDOTA
SAN JOAQUIN-HELM
70
70
26.96
1
715.5 - AAC - SIN
1000
MENDOTA BIOMASS TAP
70
70
3.84
1
397.5 - AAC - SIN
1001
MERCED
MERCED FALLS
70
70
20.93
1
715.5 - AAC - SIN
1002
MERCED #1
70
70
39.88
1
2 - UNKNOWN - SIN
1003
MERCED FALLS
EXCHEQUER
70
70
6.29
1
3/0 - CU - SINGLE
1004
MERCY SPRINGS SW STA
CANAL-ORO LOMA
70
70
23.32
1
715.5 - AAC - SIN
1005
MOCO TAP
70
70
1.64
1
397.5 - AAC - SIN
1006
MUSTANG TAP
70
70
0.71
1
4/0 - AAC - SINGL
1007
OIL CITY TAP
70
70
0.05
1
4/0 - AAC - SINGL
1008
ORO LOMA
CANAL #1
70
70
24.56
1
397.5 - AAC - SIN
1009
ORO LOMA
MENDOTA
70
70
29.58
1
266.8 - AAC - SIN
1010
PASO ROBLES
TEMPLETON
70
70
4.9
1
1113 - AAC - SING
1011
PENN ZIER TAP
70
70
4.99
1
715.5 - AAC - SIN
1012
PENTLAND TAP
70
70
0.55
1
4/0 - AAC - SINGL
1013
REEDLEY
DINUBA #1
70
70
7.7
1
715.5 - AAC - SIN
1014
REEDLEY
OROSI
70
70
10.89
1
715.5 - AAC - SIN
1015
RESERVE OIL TAP
70
70
0.58
1
1/0 - ACSR - SING
1016
RIO BRAVO HYDRO
70
70
0.24
1
4/0 - AAC - SINGL
1017
RIVER ROCK TAP
70
70
1.21
1
4/0 - AAC - SINGL
1018
ROSE TAP
70
70
0.31
1
4/0 - AAC - SINGL
1019
SAN BERNARD
TEJON
70
70
6.96
1
715.5 - AAC - SIN
1020
SAN LUIS OBISPO
CAYUCOS
70
70
23.39
1
715.5 - AAC - SIN
1021
SAN LUIS OBISPO
SANTA MARIA *
70
70
13.33
1
4/0 - AAC - SINGL
1022
SAN MIGUEL
PASO ROBLES
70
70
9.92
1
4/0 - AAC - SINGL
1023
SANGER
CALIFORNIA AVE #1
70
70
9.23
1
266.8 - AAC - SIN
1024
SCHINDLER
COALINGA #2
70
70
17.26
1
715.5 - AAC - SIN
1025
SCHINDLER
FIVE POINTS SW STA
70
70
1.7
1
4/0 - CU - SINGLE
1026
SEMITROPIC
WASCO
70
70
6.32
1
1113 - AAC - SING
1027
SOLAR TANNEHILL TAP
70
70
2.65
1
715.5 - AAC - SIN
1028
STONE CORRAL TAP
70
70
7.56
1
3/0 - AAC - SINGL
1029
SYCAMORE TAP
70
70
2.04
1
4/0 - AAC - SINGL
1030
TAFT
CUYAMA #1
70
70
19.25
1
715.5 - AAC - SIN
1031
TAFT
CUYAMA #2
70
70
18.75
1
2 - ACSR - SINGLE
1032
TAFT
ELK HILLS
70
70
12.39
1
4 - CU - SINGLE 4
1033
TAFT
MARICOPA
70
70
5.98
1
3/0 - CU - SINGLE
1034
TECUYA TAP
70
70
1.91
1
1/0 - ACSR - SING
1035
TEJON
LEBEC
70
70
13
1
1/0 - ACSR - SING
1036
TEMPLETON
ATASCADERO
70
70
8.82
1
1113 - AAC - SING
1037
TEXACO (LOST HILLS) TAP
70
70
0.01
1
397.5 - AAC - SIN
1038
TEXACO BASIC SCHOOL TAP
70
70
0.75
1
4/0 - AAC - SINGL
1039
TEXACO BUENA VISTA HILLS TA
70
70
0.1
1
4/0 - AAC - SINGL
1040
TIVY VALLEY
REEDLEY
70
70
12.3
1
397.5 - AAC - SIN
1041
TORNADO TAP
70
70
0.06
1
1/0 - ACSR - SING
1042
TULE
SPRINGVILLE
70
70
15.24
1
1/0 - CU - SINGLE
1043
WASCO
FAMOSO
70
70
7.13
1
715.5 - AAC - SIN
1044
WEEDPATCH
SAN BERNARD
70
70
9.29
1
715.5 - AAC - SIN
1045
WEEDPATCH
WELLFIELD
70
70
5.82
1
4/0 - AAC - SINGL
1046
WESIX TAP
70
70
2.51
1
2 - ACSR - SINGLE
1047
WESTLANDS TAP
70
70
1.07
1
1/0 - ACSR - SING
1048
WHEELER RIDGE
LAKEVIEW
70
70
7.51
1
715.5 - AAC - SIN
1049
WHEELER RIDGE
SAN BERNARD
70
70
5.88
1
397.5 - ACSR - SI
1050
WHEELER RIDGE
TEJON
70
70
5.01
1
715.5 - AAC - SIN
1051
WHEELER RIDGE
WEEDPATCH
70
70
22.43
1
3/0 - CU - SINGLE
1052
WISHON
COPPERMINE
70
70
19.99
1
336.4 - AAC - SIN
1053
WISHON
SAN JOAQUIN #3
70
70
7.68
1
1 - CU - SINGLE
1054
WRIGHT TAP
70
70
1.18
1
4/0 - AAC - SINGL
1055
YANKE (NORTH FORK) TAP
70
70
0.44
1
397.5 - AAC - SIN
1056
ALMADEN
LOS GATOS
60
60
6.38
1
336.4 - AAC - SIN
1057
ALMENDRA JCT
NICOLAUS
60
60
24.9
1
2/0 - CU - SINGLE
1058
AMFOR TAP
60
60
1.08
1
1/0 - ACSR - SING
1059
ARBUCKLE TAP
60
60
0.82
1
715.5 - AAC - SIN
1060
ARCATA
HUMBOLDT
60
60
7.28
1
715.5 - AAC - SIN
1061
AUBURN TAP
60
60
0.75
1
2/0 - CU - SINGLE
1062
BAIR
COOLEY LANDING #1
60
60
5.55
1
4/0 - CU - SINGLE
1063
BAIR
COOLEY LANDING #2
60
60
5.6
1
715.5 - AAC - SIN
1064
BASALT #1 TAP
60
60
1.18
1
477 - ACSS - SING
1065
BEALE AFB (WAPA) #1 TAP
60
60
0.11
1
2/0 - CU - SINGLE
1066
BEALE AFB (WAPA) #2 TAP
60
60
0.14
1
2/0 - CU - SINGLE
1067
BELLE HAVEN #1 TAP
60
60
0.45
1
477 - ACSS - SING
1068
BELLE HAVEN #2 TAP
60
60
0.4
1
477 - ACSS - SING
1069
BIXLER TAP
60
60
0.55
1
4/0 - AAC - SINGL
1070
BLUE CHIP MILLING TAP
60
60
0.42
1
4/0 - AAC - SINGL
1071
BLUE LAKE TAP
60
60
3.7
1
4/0 - ACAR - SING
1072
BRIDGEVILLE
GARBERVILLE
60
60
36.16
1
4/0 - ACSR - SING
1073
BRIONES TAP
60
60
7
1
4/0 - AAC - SINGL
1074
BUENA VISTA BIOMASS POWER T
60
60
1.02
1
715.5 - AAC - SIN
1075
BURNEY TAP
60
60
1.09
1
1/0 - ACSR - SING
1076
BURNS
LONE STAR #1
60
60
5.42
1
3/0 - CU - SINGLE
1077
BURNS
LONE STAR #2
60
60
6.34
1
3/0 - CU - SINGLE
1078
BUTTE
CHICO #1
60
60
0.79
1
397.5 - AAC - SIN
1079
BUTTE
CHICO #2
60
60
0.74
1
4/0 - AAC - SINGL
1080
BUTTE
ESQUON
60
60
9.87
1
4/0 - ALUM - SING
1081
CACHE SLOUGH TAP
60
60
6.85
1
1/0 - ACSR - SING
1082
CALVO TAP
60
60
0.54
1
2 - ACSR - SINGLE
1083
CAPE HORN TAP
60
60
0.31
1
2 - ACSR - SINGLE
1084
CARBONA #2 TAP
60
60
5.64
1
397.5 - AAC - SIN
1085
CARIBOU
PLUMAS JCT
60
60
21.25
1
397.5 - ACSR - SI
1086
CARIBOU
WESTWOOD
60
60
21.06
1
795 - ACSR - SING
1087
CARIBOU #2
60
60
42.12
1
397.5 - ACSR - SI
1088
CASCADE
BENTON-DESCHUTES
60
60
15.98
1
715.5 - AAC - SIN
1089
CENTERVILLE
TABLE MTN
60
60
21.5
1
715.5 - AAC - SIN
1090
CENTERVILLE
TABLE MTN-OROVILLE
60
60
26.11
1
350 - AAC - SINGL
1091
CHICO A
DAYTON RD
60
0.8
1
1 - UNKNOWN - UNK
1092
CHRISTIE
FRANKLIN #1
60
60
5.01
1
715.5 - AAC - SIN
1093
CHRISTIE
FRANKLIN #2
60
60
5.11
1
336.4 - AAC - SIN
1094
CHRISTIE
WILLOW PASS
60
60
15.93
1
3/0 - CU - SINGLE
1095
CHUALAR TAP
60
60
1.43
1
1 - UNKNOWN - UNK
1096
CIC TAP
60
60
0.13
1
397.5 - AAC - SIN
1097
CISCO GROVE TAP
60
60
0.34
1
2 - ACSR - SINGLE
1098
CLAY
MARTEL
60
60
21.49
1
715.5 - AAC - SIN
1099
CLEAR LAKE
HOPLAND
60
60
11.54
1
4/0 - AAC - SINGL
1100
CLEAR LAKE
KONOCTI
60
60
10.95
1
715.5 - AAC - SIN
1101
CLOVER CREEK TAP
60
60
0.02
1
1102
COBURN
BASIC ENERGY
60
60
3.39
1
1431 - AAC - BUND
1103
COBURN
OIL FIELDS #1
60
60
29.46
1
715.5 - AAC - SIN
1104
COBURN
OIL FIELDS #2
60
60
31.05
1
715.5 - AAC - SIN
1105
COGENERATION NATIONAL TAP
60
60
0.56
1
715.5 - AAC - SIN
1106
COLEMAN
COTTONWOOD
60
60
8.58
1
715.5 - AAC - SIN
1107
COLEMAN
RED BLUFF
60
60
48.31
1
1/0 - CU - SINGLE
1108
COLEMAN
SOUTH
60
60
13.39
1
715.5 - AAC - SIN
1109
COLEMAN HATCHERY TAP
60
60
0.56
1
4/0 - AAC - SINGL
1110
COLGATE
ALLEGHANY
60
60
24.55
1
4 - ACSR - SINGLE
1111
COLGATE
CHALLENGE
60
60
13.04
1
4/0 - ACSR - SING
1112
COLGATE
GRASS VALLEY
60
60
13.17
1
2/0 - CU - SINGLE
1113
COLGATE
PALERMO
60
60
22.65
1
715.5 - AAC - SIN
1114
COLGATE
SMARTVILLE #1
60
60
11.26
1
477 - ACSS - SING
1115
COLGATE
SMARTVILLE #2
60
60
11.19
1
4/0 - CU - SINGLE
1116
COLGATE PH
COLGATE SW STA
60
60
0.19
1
1113 - AAC - BUND
1117
COLLINS PINE TAP
60
60
1
1
2 - ACSR - SINGLE
1118
COLUSA JCT #1
60
60
16.98
1
715.5 - AAC - SIN
1119
CONTRA COSTA
DU PONT
60
60
2.65
1
715.5 - AAC - SIN
1120
CONTRA COSTA
PITTSBURG
60
60
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
11.55
1
397.5 - AAC - SIN
1123
COOLEY LANDING
LOS ALTOS
60
60
14.89
1
715.5 - AAC - SIN
1124
COOLEY LANDING
LOS ALTOS (I2KV)
60
60
1.41
1
715.5 - AAC - SIN
1125
COOLEY LANDING
STANFORD
60
60
6.04
1
715.5 - AAC - SIN
1126
COOLEY LANDING
STANFORD
60
60
1.59
1
2000 KCMIL - ALUM
1127
CORDELIA #1 TAP
60
60
7.69
1
1 - CU - SINGLE 2
1128
CORDELIA #2 TAP
60
60
6.87
1
2/0 - CU - SINGLE
1129
CORDELIA INTERIM PUMPING PL
60
60
0.36
1
1/0 - ACSR - SING
1130
CORTINA #1
60
60
26.29
1
715.5 - AAC - SIN
1131
CORTINA #2
60
60
26.61
1
715.5 - AAC - SIN
1132
CORTINA #3
60
60
24.8
1
715.5 - AAC - SIN
1133
CORTINA #4
60
60
45.28
1
715.5 - AAC - SIN
1134
COTTONWOOD
BENTON #1
60
60
15.53
1
715.5 - AAC - SIN
1135
COTTONWOOD
BENTON #2
60
60
14.68
1
250 - CU - SINGLE
1136
COTTONWOOD
RED BLUFF
60
60
16.74
1
300 - AAC - SINGL
1137
COTTONWOOD #1
60
60
48.16
1
4/0 - AAC - SINGL
1138
COTTONWOOD #2
60
60
23.63
1
715.5 - AAC - SIN
1139
CROW CREEK SW STA
FRONTIER SOLAR PV
60
60
0.02
1
715.5 - SINGLE
1140
CROW CREEK SW STA
NEWMAN
60
60
11.14
1
4/0 - CU - SINGLE
1141
CROWS LANDING TAP
60
60
5.28
1
4/0 - CU - SINGLE
1142
CRUSHER TAP
60
60
1.95
1
1/0 - ACSR - SING
1143
CRYSTAL SPRINGS TAP
60
60
0.28
1
4/0 - AAC - SINGL
1144
DEAN FOODS TAP
60
60
0.51
1
397.5 - AAC - SIN
1145
DEER CREEK
DRUM
60
60
6.24
1
2/0 - CU - SINGLE
1146
DEL MAR
ATLANTIC #1
60
60
2.78
1
477 - ACSS - SING
1147
DEL MAR
ATLANTIC #2
60
60
4.45
1
715.5 - AAC - SIN
1148
DEL MAR
ATLANTIC #1
60
60
1.18
1
3000 KCMIL - CU
1149
DEL MONTE
MONTEREY
60
60
2.53
1
715.5 - AAC - SIN
1150
DEL MONTE
VIEJO
60
60
7.92
1
715.5 - AAC - SIN
1151
DEL MONTE
FORT ORD #1
60
60
6.13
1
715.5 - AAC - SIN
1152
DEL MONTE
FORT ORD #2
60
60
5.6
1
715.5 - AAC - SIN
1153
DELTA
MTN GATE JCT
60
60
15.14
1
518 - ACSR - SING
1154
DESABLA
CENTERVILLE
60
60
5.86
1
350 - AAC - SINGL
1155
DISTRICT 1001 TAP
60
60
1.47
1
4 - CU - SINGLE
1156
DISTRICT 1500 TAP
60
60
3.61
1
6 - CU - SINGLE 2
1157
DIXON
VACA #1
60
60
18.35
1
715.5 - AAC - SIN
1158
DIXON
VACA #2
60
60
26.77
1
715.5 - AAC - SIN
1159
DRUM
GRASS VALLEY-WEIMAR
60
60
31.17
1
397.5 - ACSR - SI
1160
DRUM
SPAULDING
60
60
9.36
1
4/0 - CU - SINGLE
1161
DU PONT TAP
60
60
0.52
1
715.5 - AAC - SIN
1162
EAST DUBLIN (BART) TAP
60
60
0.04
1
715.5 - AAC - SIN
1163
EEL RIVER TAP
60
60
2.31
1
4/0 - ACSR - SING
1164
ELK
GUALALA
60
60
29.01
1
1/0 - CU - SINGLE
1165
ELK CREEK TAP
60
60
20.44
1
2 - ACSR - SINGLE
1166
ENCINAL TAP
60
60
1.43
1
4 - CU - SINGLE
1167
ESSEX JCT
ARCATA-FAIRHAVEN
60
60
16.08
1
715.5 - AAC - SIN
1168
ESSEX JCT
ORICK
60
60
31.29
1
2/0 - CU - SINGLE
1169
EUREKA
STA A
60
60
0.22
1
715.5 - AAC - SIN
1170
EVERGREEN
ALMADEN
60
60
4.96
1
715.5 - AAC - SIN
1171
EVERGREEN
MABURY
60
60
5.48
1
4/0 - CU - SINGLE
1172
FAIRHAVEN
HUMBOLDT
60
60
15.56
1
715.5 - AAC - SIN
1173
FAIRHAVEN #1
60
60
0.41
1
715.5 - AAC - SIN
1174
FAIRHAVEN POWER CO TAP
60
60
0.55
1
397.5 - AAC - SIN
1175
FITCH MTN #1 TAP
60
60
0.87
1
477 - ACSS - SING
1176
FITCH MTN #2 TAP
60
60
0.07
1
2/0 - CU - SINGLE
1177
FORKS OF THE BUTTE TAP
60
60
0.2
1
350 - AAC - SINGL
1178
FORT BRAGG
ELK
60
60
24.02
1
397.5 - AAC - SIN
1179
FORT ROSS
GUALALA
60
60
29.76
1
715.5 - AAC - SIN
1180
FORT SEWARD TAP
60
60
7.7
1
4/0 - ACSR - SING
1181
FRENCH MEADOWS
MIDDLE FORK
60
60
13.19
1
4/0 - ACSR - SING
1182
FRESH EXPRESS TAP
60
60
0.56
1
2/0 - CU - SINGLE
1183
FRUITLAND TAP
60
60
4.26
1
4/0 - ACSR - SING
1184
FULTON
WINDSOR
60
60
6.59
1
477 - ACSS - SING
1185
FULTON
CALISTOGA
60
60
64.6
1
4/0 - AAC - SINGL
1186
FULTON
HOPLAND
60
60
41.09
1
715.5 - AAC - SIN
1187
FULTON
MOLINO-COTATI
60
60
20.52
1
715.5 - AAC - SIN
1188
FULTON
MOLINO-COTATI
60
60
0.35
1
715.5 - AAC - SIN
1189
GARBERVILLE
LAYTONVILLE
60
60
39.99
1
715.5 - AAC - SIN
1190
GARCIA TAP
60
60
3.04
1
1/0 - ACSR - SING
1191
GLENN #1
60
60
33.37
1
715.5 - AAC - SIN
1192
GLENN #2
60
60
34.69
1
715.5 - AAC - SIN
1193
GLENN #3
60
60
28.51
1
715.5 - AAC - SIN
1194
GLENN #4
60
60
12.54
1
715.5 - AAC - SIN
1195
GLENN #5
60
60
7.41
1
715.5 - AAC - SIN
1196
GOLD HILL #1
60
60
27.85
1
715.5 - AAC - SIN
1197
GONZALES #1 TAP
60
60
0.2
1
2/0 - CU - SINGLE
1198
GONZALES #2 TAP
60
60
0.3
1
2/0 - CU - SINGLE
1199
GRANITE ROCK TAP
60
60
2.39
1
4/0 - AAC - SINGL
1200
GREEN VALLEY
WATSONVILLE
60
60
4.74
1
397.5 - AAC - SIN
1201
GREENLEAF #2 TAP
60
60
0.62
1
715.5 - AAC - SIN
1202
GRONEMEYER TAP
60
60
0.83
1
1/0 - ACSR - SING
1203
GUSTINE #1 TAP
60
60
7.56
1
4/0 - AAC - SINGL
1204
GUSTINE #2 TAP
60
60
4.44
1
715.5 - AAC - SIN
1205
GWF #4 TAP
60
60
0.25
1
397.5 - AAC - SIN
1206
HALSEY
PLACER
60
60
4.94
1
397.5 - AAC - SIN
1207
HAMILTON BRANCH
CHESTER
60
60
12.27
1
4/0 - ACSR - SING
1208
HAMMER
COUNTRY CLUB
60
60
8.82
1
715.5 - AAC - SIN
1209
HARRINGTON TAP
60
60
0.53
1
1/0 - ACSR - SING
1210
HARTLEY
CLEARLAKE
60
60
6.66
1
4/0 - AAC - SINGL
1211
HAT CREEK #1
PIT #1
60
60
6.08
1
1/0 - ACSR - SING
1212
HAT CREEK #1
WESTWOOD
60
60
55.87
1
4/0 - CU - SINGLE
1213
HEADGATE TAP
60
60
0.97
1
4/0 - AAC - SINGL
1214
HEALDSBURG #1 TAP
60
60
0.25
1
4/0 - AAC - SINGL
1215
HEALDSBURG #2 TAP
60
60
0.16
1
471 - AAC - SINGL
1216
HERDLYN
BALFOUR
60
60
20.5
1
1/0 - CU - SINGLE
1217
HILLSDALE JCT
HALF MOON BAY
60
60
6.82
1
397.5 - AAC - SIN
1218
HUMBOLDT
EUREKA
60
60
4.7
1
715.5 - AAC - SIN
1219
HUMBOLDT
MAPLE CREEK
60
60
14.13
1
4/0 - ACSR - SING
1220
HUMBOLDT #1
60
60
11.05
1
715.5 - AAC - SIN
1221
HUMBOLDT BAY
EUREKA
60
60
5.61
1
715.5 - AAC - SIN
1222
HUMBOLDT BAY
HUMBOLDT #1
60
60
8.34
1
715.5 - AAC - SIN
1223
HUMBOLDT BAY
HUMBOLDT #2
60
60
6.45
1
1113 - AAC - SING
1224
HUMBOLDT BAY
RIO DELL JCT
60
60
18.4
1
1113 - AAC - SING
1225
IGNACIO
STAFFORD
60
6.13
1
715.5 - AAC - SIN
1226
IGNACIO
BOLINAS #1
60
60
15.06
1
715.5 - AAC - SIN
1227
IGNACIO
ALTO
60
60
17.79
1
715.5 - AAC - SIN
1228
IGNACIO
ALTO-SAUSALITO #1
60
60
17.83
1
4/0 - ACSR - SING
1229
IGNACIO
ALTO-SAUSALITO #2
60
60
17.83
1
4/0 - ACSR - SING
1230
IGNACIO
BOLINAS #2
60
60
28.22
1
715.5 - AAC - SIN
1231
INDUSTRIAL TAP
60
60
0.97
1
715.5 - AAC - SIN
1232
IONE TAP
60
60
4.09
1
4/0 - AAC - SINGL
1233
IUKA TAP
60
60
0.49
1
4 - CU - SINGLE
1234
JANES CREEK TAP
60
60
1.78
1
4/0 - AAC - SINGL
1235
JEFFERSON
HILLSDALE JCT
60
60
14.72
1
715.5 - AAC - SIN
1236
JEFFERSON
LAS PULGAS
60
60
6
1
715.5 - AAC - SIN
1237
JEFFERSON
STANFORD
60
60
7.64
1
715.5 - AAC - SIN
1238
JEFFERSON
STANFORD (UNDERGROUND)
60
60
1.52
1
1239
JEFFERSON
LAS PULGAS
60
60
0.18
1
1750 KCMIL - ALUM
1240
JEFFERSON #1
60
60
9.05
1
715.5 - AAC - SIN
1241
JENNINGS TAP
60
60
0.14
1
336.4 - AAC - SIN
1242
JOLON TAP
60
60
15.87
1
4/0 - AAC - SINGL
1243
KASSON
CARBONA
60
60
7.32
1
715.5 - AAC - SIN
1244
KASSON
BANTA #1
60
60
1.05
1
715.5 - AAC - SIN
1245
KASSON
LOUISE
60
60
8.79
1
715.5 - AAC - SIN
1246
KASSON #1
60
60
0.19
1
715.5 - AAC - SIN
1247
KESWICK
CASCADE
60
60
9.35
1
4/0 - AAC - SINGL
1248
KESWICK
TRINITY
60
60
30.42
1
336.4 - ACSR - SI
1249
KILARC
CEDAR CREEK
60
60
13.33
1
1/0 - ACSR - SING
1250
KILARC
DESCHUTES
60
60
27.28
1
2 - ACSR - SINGLE
1251
KILARC
VOLTA TIE
60
60
1.94
1
1/0 - ACSR - SING
1252
KING CITY
COBURN #1
60
60
21.91
1
715.5 - AAC - SIN
1253
KING CITY
COBURN #2
60
60
15.79
1
715.5 - AAC - SIN
1254
KONOCTI
MIDDLETOWN
60
60
19.87
1
715.5 - AAC - SIN
1255
KONOCTI
EAGLE ROCK
60
60
9.66
1
715.5 - AAC - SIN
1256
LAGUNA TAP
60
60
1.68
1
4/0 - AAC - SINGL
1257
LAGUNITAS TAP
60
60
0.6
1
1258
LAKEVILLE
PETALUMA C
60
60
5.36
1
250 - CU - SINGLE
1259
LAKEVILLE #1
60
60
11.16
1
397.5 - AAC - SIN
1260
LAKEVILLE #2
60
60
21.62
1
1/0 - CU - SINGLE
1261
LAS POSITAS
VASCO
60
60
1.5
1
715.5 - AAC - SIN
1262
LAURELES
OTTER
60
60
15.56
1
4/0 - ACSR - SING
1263
LAYTONVILLE
COVELO
60
60
16.09
1
715.5 - AAC - SIN
1264
LAYTONVILLE
WILLITS
60
60
23.14
1
715.5 - AAC - SIN
1265
LEE TAP
60
60
5.85
1
4/0 - AAC - SINGL
1266
LIMESTONE TAP
60
60
1.73
1
2 - ACSR - SINGLE
1267
LIVERMORE
LAS POSITAS
60
60
3.63
1
715.5 - AAC - SIN
1268
LOCKEFORD
INDUSTRIAL
60
60
6.03
1
715.5 - AAC - SIN
1269
LOCKEFORD
LODI #2
60
60
9.41
1
715.5 - AAC - SIN
1270
LOCKEFORD
LODI #3
60
60
15.42
1
715.5 - AAC - SIN
1271
LOCKEFORD #1
60
60
12.85
1
715.5 - AAC - SIN
1272
LODI
INDUSTRIAL
60
60
0.97
1
715.5 - AAC - SIN
1273
LONE STAR TAP
60
60
1.18
1
1274
LOS COCHES TAP
60
60
1.33
1
4/0 - AAC - SINGL
1275
LOUISIANA PACIFIC (OROVILLE
60
60
0.16
1
1/0 - ACSR - SING
1276
LP FLAKEBOARD TAP
60
60
0.51
1
397.5 - AAC - SIN
1277
LYOTH TAP
60
60
1.34
1
4/0 - AAC - SINGL
1278
MANTECA
LOUISE
60
60
12.53
1
715.5 - AAC - SIN
1279
MANTECA #1
60
60
34.52
1
1/0 - CU - SINGLE
1280
MAPLE CREEK
HOOPA
60
60
29.13
1
1/0 - ACSR - SING
1281
MARSH TAP
60
60
3.97
1
1/0 - ACSR - SING
1282
MARTIN
SNEATH LANE
60
60
7.19
1
715.5 - AAC - SIN
1283
MCDONALD TAP
60
60
5.88
1
1/0 - ACSR - SING
1284
MENDOCINO
HARTLEY
60
60
23.17
1
4/0 - ACSR - SING
1285
MENDOCINO
PHILO JCT-HOPLAND
60
60
23.55
1
3/0 - CU - SINGLE
1286
MENDOCINO
WILLITS
60
60
14.52
1
2/0 - CU - SINGLE
1287
MENDOCINO
WILLITS-FORT BRAGG
60
60
43.77
1
715.5 - ALUM - SI
1288
MENDOCINO #1
60
60
7.48
1
3/0 - CU - SINGLE
1289
MENLO TAP
60
60
0.36
1
715.5 - AAC - BUN
1290
MIDDLE FORK #1
60
60
9.43
1
4/0 - ACSR - SING
1291
MIDDLE RIVER TAP
60
60
7.02
1
3 - CU - SINGLE 3
1292
MILLBRAE
SNEATH LANE
60
60
6.49
1
715.5 - AAC - SIN
1293
MONTA VISTA
BURNS
60
60
18.06
1
3/0 - CU - SINGLE
1294
MONTA VISTA
LOS ALTOS
60
60
7.13
1
715.5 - AAC - SIN
1295
MONTA VISTA
LOS GATOS
60
60
10.88
1
715.5 - AAC - SIN
1296
MONTA VISTA
PERMANENTE
60
60
1.19
1
397.5 - AAC - SIN
1297
MONTE RIO
FORT ROSS
60
60
14.3
1
715.5 - AAC - SIN
1298
MONTE RIO
FULTON
60
60
22.56
1
715.5 - AAC - SIN
1299
MTN GATE JCT
CASCADE
60
60
6.57
1
2/0 - CU - SINGLE
1300
MTN GATE TAP
60
60
0.7
1
1/0 - ACSR - SING
1301
MTN QUARRIES TAP
60
60
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
2.65
1
715.5 - AAC - SIN
1304
NARROWS #2 TAP
60
60
3.1
1
715.5 - AAC - SIN
1305
NAVY LAB TAP
60
60
0.19
1
2 - CU - SINGLE
1306
NEW HOGAN TAP
60
60
2.21
1
1/0 - ACSR - SING
1307
NEWARK
DECOTO
60
60
6.28
1
715.5 - AAC - SIN
1308
NEWARK
LIVERMORE
60
60
19.05
1
4/0 - CU - SINGLE
1309
NEWARK
VALLECITOS
60
60
12.39
1
715.5 - AAC - SIN
1310
NEWARK-SIERRA PAPERBOARD TA
60
60
0.29
1
715.5 - AAC - SIN
1311
NICOLAUS
CATLETT JCT
60
60
20.16
1
715.5 - AAC - SIN
1312
NICOLAUS
CATLETT JCT
60
60
18.63
1
715.5 - AAC - SIN
1313
NICOLAUS
CATLETT JCT (12KV)
60
60
18.63
1
715.5 - AAC - SIN
1314
NICOLAUS
MARYSVILLE
60
60
18.74
1
4/0 - CU - SINGLE
1315
NICOLAUS
PLAINFIELD
60
60
30.63
1
715.5 - AAC - SIN
1316
NICOLAUS
WILKINS SLOUGH
60
60
42.72
1
4 - CU - SINGLE 3
1317
OAK PARK TAP
60
60
0.87
1
4 - CU - SINGLE
1318
OILFIELDS
SARGENT CANYON
60
60
2.02
1
715.5 - AAC - SIN
1319
OILFIELDS
SALINAS RIVER
60
60
1.46
1
715.5 - AAC - SIN
1320
ORO FINO TAP
60
60
1.3
1
2 - ACSR - SINGLE
1321
OXBOW TAP
60
60
0.15
1
4/0 - ACSR - SING
1322
PACIFIC ETHANOL TAP
60
60
0.68
1
715.5 - AAC - SIN
1323
PACIFIC LUMBER (SCOTIA) TA
60
60
0.52
1
4/0 - AAC - SINGL
1324
PACIFIC OROVILLE POWER TAP
60
60
0.78
1
4/0 - AAC - SINGL
1325
PALERMO
OROVILLE #1
60
60
6.97
1
715.5 - AAC - SIN
1326
PALERMO
OROVILLE #2
60
60
10.13
1
715.5 - AAC - SIN
1327
PARDEE #1 TAP
60
60
4.33
1
2/0 - CU - SINGLE
1328
PARDEE #2 TAP
60
60
0.09
1
2/0 - CU - SINGLE
1329
PARKS TAP
60
60
0.45
1
1/0 - ACSR - SING
1330
PEACHTON
PEASE
60
60
16.34
1
715.5 - AAC - SIN
1331
PEASE
HARTER
60
60
15.88
1
715.5 - AAC - SIN
1332
PEASE
MARYSVILLE-HARTER
60
60
10.29
1
715.5 - AAC - SIN
1333
PERMANENTE #1 TAP
60
60
0.31
1
397.5 - AAC - SIN
1334
PERMANENTE #2 TAP
60
60
0.51
1
397.5 - AAC - SIN
1335
PHILO JCT
ELK
60
60
37.25
1
397.5 - ACSR - SI
1336
PINE GROVE TAP
60
60
2.67
1
397.5 - ACSR - SI
1337
PIT #1
HAT CREEK #2-BURNEY
60
60
12.96
1
3/0 - CU - SINGLE
1338
PIT #1
MCARTHUR
60
60
7.3
1
1/0 - ACSR - SING
1339
PITTSBURG #1 TAP (NO FLY)
60
60
1.15
1
4/0 - CU - SINGLE
1340
PITTSBURG #2 TAP
60
60
1.19
1
3/0 - CU - SINGLE
1341
PLACER
DEL MAR
60
60
10.81
1
715.5 - AAC - SIN
1342
PLUMAS-SIERRA TAP
60
60
0.75
1
397.5 - ACSR - SI
1343
PORT COSTA BRICK TAP
60
60
1.9
1
3/0 - CU - SINGLE
1344
POTTER VALLEY
MENDOCINO
60
60
10.94
1
3/0 - CU - SINGLE
1345
POTTER VALLEY
WILLITS
60
60
13.16
1
1/0 - ACSR - SING
1346
RADUM
LIVERMORE
60
60
4.66
1
715.5 - AAC - SIN
1347
RADUM
VALLECITOS
60
60
10.62
1
715.5 - AAC - SIN
1348
RED BANK TAP
60
60
0.68
1
1/0 - ACSR - SING
1349
RIO DELL JCT
BRIDGEVILLE
60
60
21.25
1
1/0 - CU - SINGLE
1350
RIO DELL TAP
60
60
5.36
1
1/0 - CU - SINGLE
1351
ROBERTSON TAP
60
60
0.82
1
1/0 - ACSR - SING
1352
ROLLINS TAP
60
60
0.73
1
4/0 - ACSR - SING
1353
ROUGH & READY TAP
60
60
0.95
1
4/0 - AAC - SINGL
1354
SALADO
CROW CREEK SW STA
60
60
3.77
1
715.5 - ACSR - SI
1355
SALADO
NEWMAN #2
60
60
21.56
1
715.5 - AAC - SIN
1356
SALINAS
FORT ORD #1
60
60
10.22
1
715.5 - AAC - SIN
1357
SALINAS
FIRESTONE #1
60
60
6.18
1
715.5 - AAC - SIN
1358
SALINAS
FIRESTONE #2
60
60
17.21
1
715.5 - AAC - SIN
1359
SALINAS
LAGUNITAS
60
60
5.81
1
4/0 - CU - SINGLE
1360
SALINAS
LAURELES
60
60
27.46
1
266.8 - AAC - SIN
1361
SALINAS
FORT ORD #2
60
60
10.12
1
715.5 - AAC - SIN
1362
SALMON CREEK TAP
60
60
10.51
1
397.5 - AAC - SIN
1363
SAN ANDREAS (CCSF) TAP
60
60
0.39
1
397.5 - AAC - SIN
1364
SAN ARDO TAP
60
60
0.34
1
715.5 - AAC - SIN
1365
SAN BRUNO TAP
60
60
1.13
1
1/0 - ACSR - SING
1366
SAN MATEO
BAIR
60
60
13.99
1
397.5 - AAC - PAR
1367
SAN MATEO
HILLSDALE JCT
60
60
6.89
1
397.5 - AAC - SIN
1368
SAN RAMON
RADUM
60
60
7.06
1
715.5 - AAC - SIN
1369
SEBASTIANI TAP
60
60
0.01
1
4/0 - AAC - SINGL
1370
SENTER #1 TAP
60
60
0.23
1
336.4 - AAC - SIN
1371
SEQUOIA TAP
60
60
0.4
1
4/0 - AAC - SINGL
1372
SIERRA PAC IND (QUINCY) TAP
60
60
0.17
1
1373
SIERRA PINES LIMITED
60
60
0.4
1
4/0 - AAC - SINGL
1374
SIMPSON-KORBEL TAP
60
60
0.39
1
4/0 - AAC - SINGL
1375
SLAC TAP
60
60
1.41
1
397.5 - AAC - SIN
1376
SMARTVILLE
CAMP FAR WEST
60
60
17.81
1
715.5 - AAC - SIN
1377
SMARTVILLE
CAMP FAR WEST (12KV)
60
60
7.15
1
715.5 - AAC - SIN
1378
SMARTVILLE
MARYSVILLE
60
60
20.11
1
715.5 - AAC - SIN
1379
SMARTVILLE
NICOLAUS #1
60
60
29.6
1
715.5 - AAC - SIN
1380
SMARTVILLE
NICOLAUS #2
60
60
30.16
1
715.5 - AAC - SIN
1381
SMARTVILLE TAP
60
60
0.09
1
715.5 - AAC - SIN
1382
SNEATH LANE
HALF MOON BAY
60
60
15.41
1
715.5 - AAC - SIN
1383
SNEATH LANE
PACIFICA
60
60
3.26
1
715.5 - AAC - SIN
1384
SOLEDAD #1
60
60
15.5
1
397.5 - AAC - SIN
1385
SOLEDAD #2
60
60
18.86
1
4/0 - AAC - SINGL
1386
SOLEDAD #3
60
60
1.63
1
397.5 - AAC - SIN
1387
SOLEDAD #4
60
60
6.08
1
397.5 - AAC - SIN
1388
SPAULDING
SUMMIT
60
60
19.65
1
4/0 - CU - SINGLE
1389
SPAULDING #3
SPAULDING #1
60
60
1.09
1
1/0 - CU - SINGLE
1390
STAGG
COUNTRY CLUB #1
60
60
2.43
1
715.5 - AAC - SIN
1391
STAGG
COUNTRY CLUB #2
60
60
2.46
1
715.5 - AAC - SIN
1392
STAGG
HAMMER
60
60
4.25
1
715.5 - AAC - SIN
1393
STANDARD #1 & #2 (12KV)
60
60
4.16
1
1 - UNKNOWN - UNK
1394
STANISLAUS RECOVERY TAP
60
60
0.11
1
397.5 - AAC - SIN
1395
STAUFFER TAP
60
60
0.58
1
1/0 - ACSR - SING
1396
STOCKTON
NEWARK
60
60
14.59
1
3/0 - CU - SINGLE
1397
STOCKTON A
WEBER #1
60
60
13.2
1
715.5 - AAC - SIN
1398
STOCKTON A
WEBER #2
60
60
9.87
1
715.5 - AAC - SIN
1399
STOCKTON A
WEBER #3
60
60
9.81
1
715.5 - AAC - SIN
1400
STOCKTON A #1
60
60
5.58
1
715.5 - AAC - SIN
1401
SUMIDEN WIRE PRODUCTS TAP
60
60
0.19
1
397.5 - AAC - SIN
1402
SUNOL TAP
60
60
0.08
1
4/0 - AAC - SINGL
1403
SUTTER HOME
SUTTER HOME SW STA
60
60
0.03
1
715.5 - AAC - SIN
1404
SUTTER HOME SW STA
LOCKEFORD-LODI
60
60
29.74
1
715.5 - AAC - SIN
1405
SUTTER HOME SW STA
STAGG
60
60
17.13
1
715.5 - AAC - SIN
1406
TABLE MTN
PEACHTON
60
60
14.84
1
715.5 - AAC - SIN
1407
TERMINOUS TAP
60
60
3.01
1
2/0 - ACSR - SING
1408
TEXACO TAP
60
60
0.72
1
397.5 - AAC - SIN
1409
TOCALOMA TAP
60
60
1.03
1
2 - ACSR - SINGLE
1410
TRAVIS TAP
60
60
2.88
1
715.5 - AAC - SIN
1411
TRINIDAD TAP
60
60
1.34
1
1 - CU - SINGLE
1412
TRINITY
MAPLE CREEK
60
60
55.45
1
4/0 - ACSR - SING
1413
TULUCAY
NAPA #1
60
60
9.72
1
715.5 - AAC - SIN
1414
TULUCAY
NAPA #2
60
60
3.93
1
715.5 - AAC - SIN
1415
ULTRA POWER TAP
60
60
1.17
1
4/0 - AAC - SINGL
1416
UNION CHEMICAL TAP
60
60
1.04
1
715.5 - AAC - SIN
1417
URICH TAP
60
60
0.21
1
4/0 - AAC - SINGL
1418
US WINDPOWER TAP
60
60
1.52
1
4/0 - AAC - SINGL
1419
VACA
PLAINFIELD
60
60
29.83
1
715.5 - AAC - SIN
1420
VALLEY SPRINGS
CALAVERAS CEMENT
60
60
7.91
1
715.5 - AAC - SIN
1421
VALLEY SPRINGS
MARTELL #1
60
60
12.75
1
1113 - AAC - SING
1422
VALLEY SPRINGS
CLAY
60
60
17.3
1
715.5 - AAC - SIN
1423
VALLEY SPRINGS #1
60
60
27.27
1
1113 - AAC - SING
1424
VALLEY SPRINGS #2
60
60
25.65
1
1113 - AAC - SING
1425
VASCO
HERDLYN
60
60
10.97
1
715.5 - AAC - SIN
1426
VICTOR TAP
60
60
0.06
1
4/0 - AAC - SINGL
1427
VIEJO
MONTEREY
60
60
2.28
1
715.5 - AAC - SIN
1428
VOLTA
DESCHUTES
60
60
20.86
1
2/0 - CU - SINGLE
1429
VOLTA
SOUTH
60
60
4.86
1
1 - CU - SINGLE 2
1430
WADHAM TAP
60
60
1.68
1
4/0 - AAC - SINGL
1431
WASHOE TAP
60
60
1.04
1
4/0 - AAC - SINGL
1432
WATERSHED TAP
60
60
0.28
1
4/0 - AAC - SINGL
1433
WATSONVILLE
SALINAS
60
60
28.39
1
3/0 - CU - SINGLE
1434
WEBER
FRENCH CAMP #1
60
60
6.07
1
715.5 - AAC - SIN
1435
WEBER
FRENCH CAMP #2
60
60
10.89
1
715.5 - AAC - SIN
1436
WEBER
MORMON JCT
60
60
17.67
1
715.5 - AAC - SIN
1437
WEIMAR
HALSEY
60
60
6.28
1
397.5 - AAC - SIN
1438
WEIMAR #1
60
60
13.98
1
80 - ACSR - SINGL
1439
WEST POINT
VALLEY SPRINGS
60
60
21.66
1
715.5 - AAC - SIN
1440
WEST SAC COM TOWERS
60
0.02
1
1441
WESTINGHOUSE TAP
60
60
7.97
1
4/0 - CU - SINGLE
1442
WILLOW PASS
CONTRA COSTA
60
60
10.82
1
715.5 - AAC - SIN
1443
WIND FARMS
60
60
3.75
1
715.5 - AAC - SIN
1444
WINDSOR
FITCH MOUNTAIN
60
60
21.24
1
4/0 - ACSR - SING
1445
WINTU TAP
60
60
1.86
1
1/0 - ACSR - SING
1446
WOHLER TAP
60
60
1.44
1
2 - ACSR - SINGLE
1447
WOODBRIDGE TAP
60
60
0.53
1
4/0 - AAC - SINGL
1448
YUBA CITY COGEN TAP
60
60
0.8
1
477 - ACSS - SING
1449
ZOND WIND TAP
60
60
1.19
1
1450
A
Y #1 (UNDERGROUND IDLE)
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
/
Q4
TRANSMISSION LINES ADDED DURING YEAR
  1. 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.
  2. 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).
  3. 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.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
LengthOfTransmissionLineAdded
Line Length in Miles
SupportingStructureOfTransmissionLineType
Type
AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles
Average Number per Miles
NumberOfTransmissionCircuitsPerStructurePresent
Present
NumberOfTransmissionCircuitsPerStructureUltimate
Ultimate
ConductorSize
Size
ConductorSpecification
Specification
ConductorConfigurationAndSpacing
Configuration and Spacing
OperatingVoltageOfTransmissionLine
Voltage KV (Operating)
CostOfLandAndLandRightsTransmissionLinesAdded
Land and Land Rights
CostOfPolesTowersAndFixturesTransmissionLinesAdded
Poles, Towers and Fixtures
CostOfConductorsAndDevicesTransmissionLinesAdded
Conductors and Devices
AssetRetirementCostsTransmissionLines
Asset Retire. Costs
CostOfTransmissionLinesAdded
Total
SupportingStructureConstructionType
Construction
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
(q)
1
Semitropic Sub
Midway Substation
14.2
17
1
1
T1 8.5 FT
115
100
4,773,741
1,267,713
100
6,041,654
2
Headgate Metering station
Glenn #3
111.1
146
1
1
T1 8.5 FT
60
4,327,626
47,491,469
61,411,844
100
113,231,039
44
TOTAL
125.3
163
2
2
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
/
Q4
SUBSTATIONS
  1. Report below the information called for concerning substations of the respondent as of the end of the year.
  2. Substations which serve only one industrial or street railway customer should not be listed below.
  3. 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.
  4. 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).
  5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
  6. 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
/
Q4
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
  1. Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies.
  2. 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".
  3. 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
31,789
3
Corporate A&G Allocations
Eureka Energy Company
94,248,645
4
Administrative & General Expenses
Eureka Energy Company
94,248,645
5
Rent Expense
Eureka Energy Company
321,288
6
Non-power Goods/Srv.provided by Affilia
Eureka Energy Company
94,569,933
19
20
Non-power Goods or Services Provided for Affiliated
21
ADMINISTRATION
PG&E Corporation
278,634
22
ACCOUNTING
PG&E Corporation
536,406
23
ADMINISTRATION
PG&E Corporation
509,322
24
AFFILIATE RULES COMPLIANCE SUPPORT
PG&E Corporation
24,463
25
FOR AFFILIATES
PG&E Corporation
4,231,914
42