ML032120055

Petition for Review of Memorandum and Order CLI-02-16 of NRC and Supplemental Excerpts of Record of Respondent-intervenor Pacific Gas and Electric Company, Dated 02/10/2003

ML032120055
Person / Time
Site:	Diablo Canyon
Issue date:	02/10/2003
From:	Locke R, Manheim W, Poole B, Repka D Pacific Gas & Electric Co, Winston & Strawn
To:	Office of Nuclear Reactor Regulation, State of CA, California Public Utilities Commission, US Federal Judiciary, Court of Appeals, 9th Circuit
References
02-72735, CLI-02-16
Download: ML032120055 (27)

Text

NO. 02-72735 IN THE UNITED STATES COURT OF APPEALS FOR THE NINTH CIRCUIT

/ .

CALIFORNIA PUBLIC UTILITIES COMMISSION, ET AL.,

Petitioners V.

UNITED STATES NUCLEAR REGULATORY COMMISSION, Respondent and PACIFIC GAS AND ELECTRIC COMPANY, ET AL.,

Intervenors PETITION FOR REVIEW OF MEMORANDUM AND ORDER CLI-02-16 OF THE U.S. NUCLEAR REGULATORY COMMISSION SUPPLEMENTAL EXCERPTS OF RECORD OF RESPONDENT-INTERVENOR PACIFIC GAS AND ELECTRIC COMPANY William V. Manheim David A. Repka Richard F. Locke Brooke D. Poole Pacific Gas and Electric Company *Winston & Strawn 77 Beale Street, B30A 1400 L Street, N.W.

San Francisco, CA 94105 Washington, DC 20005 (415) 973-6616 (202)'371-5700 Counsel for Intervenor PACIFIC GAS AND ELECTRIC COMPANY

RESPONDENT-INTERvENoR PACIF[C GAS AND ELEcTIc COMPANY'S SUPPLEMENTAL EXCERPTS OF RECORD INDEX I,. I I Description of Document Date Tab Application for Consent to License Transfers and November 30,2001 1 Conforming License Amendments for Diablo Canyon Power Plant, Units 1 and 2, Enclosure 9, "Decommissioning FundingAssurance:

Calculation Demonstrating Adequacy of Trepayment Amount"'

Application for Consent to License Transfers and November 30,2001 2 Conforming License Amendments for Diablo Canyon Power Plant, Units 1 and 2, pages 12-17 Application for Consent to License Transfers and September 20, 2001 3 Conforming License Amendments for Diablo Canyon Power Plant, Units 1 and 2, Attachment 1- Disclosure Statement for Plan of Reorganization Under Chapter 11 of the Bankruptcy Code for Pacific Gas and Electric Company Proposed by Pacific Gas and Electric Company and PG&E Corporation, pages 70-74 Application for Consent to License Transfers and September 20, 2001 4 Conforming License Amendments for Diablo Canyon Power Plant, Units 1 and 2, Attachment 1-Plan of Reorganization Under Chapter 11 of the Bankruptcy Code for Pacific Gas and Electric Company, Exhibit C (Partial)

DC:2950111

Enclosure 9 PG&E Letter DCL-01-119 Decommissioning Funding Assurance:

Calculation Demonstrating Adequacy of "Prepavment Amount"

,i A 000001

Enclosure 9 PG&E Letter DCL-01-1 19 Diablo Canyon Power Plant, Unit I License Expires September 22,2021 Funding Status Assuming 0.84% Net After-Tax Earnings20

($ Millions)

I, A,

Calendar Contribution Earnings Balance NRC Minimum NRC Minimum Year _2_ _ _ Status 2001 1.92 - 482.75' 347.88 Fully Funded 2002 7.68 30.61 521.04 367.01 Fully Funded 2003 - 33.03 554.07 387.20 Fully Funded 2004 - 35.13 589.20 408.50 Fully Funded 2005 - 37.36 626.56 430.96 Fully Funded 2006 - 39.72 666.28 454.67 Fully Funded 2007 - 42.24 708.52 479.67 Fully Funded 2008 - 44.92 753.44 506.06 Fully Funded 2009 - 47.77 801.21 533.89 Fully Funded 2010 - 50.80 852.01 563.25 Fully Funded 2011 - 54.02 906.03 594.23 Fully Funded 2012 - 57.44 963.47 626.91. Fully Funded 2013 - 61.08 1,024.55 661.39 Fully Funded 2014 - 64.96 1,089.51 697.77 Fully Funded 2015 - 69.07 1,158.58 736.15 Fully Funded 2016 - 73.45 1,232.04 776.64 Fully Funded 2017 , 78.11 1,310.15 819.35 Fully Funded 2018 - 83.06 1,393.21 864A2 Fully Funded 2019 188.33 '11,481.54 911.96 _ Fully Funded 2020 193.93 1,575.47 962.12 Fully Funded 2021 - 72.05 1,647.53 1,000.33' Fully Funded 20 The assumption Is based upon the current California Public Utilities Commission authorized after-tax earnings rate.

21 Reflects projected end-of-year 2001 balance, including contributions made In 2001. Liquldation value as of September 30, 2001, was $473.5 million.

I 000002

Enclosure 9 PG&E Letter DCL-01-1 19 Calculation Notes for DCPP Uni 1 Contribution: PG&E is currently authorized to contribute a total of $24.003 million per year to the Diablo Canyon Nuclear Decommissioning Master Trusts. Unit 1's portion of the total contribution is $7.68 million. For 200,/1, only the 4th Quarter contribution, to be made December 28, 2001, is shown as a contribution. Contributions for the first three Quarters are included in the end-of-year 2001 balance.

Eamings! PG&E has assumed after-tax earnings to the trust of 6.34 percent per year.

(The liability (cost estimate) Is grown at 5.5 percent per year, resulting Ina 0.84 percent after-tax real growth rate on the trust.) Earnings are calculated each year by multiplying the prior year's balance by 6.34 percent. Year 2021 earnings are calculated on a partial-year basis.

Balance: The end-of-year 2002 balance Is determined as follows-PG&E used the liquidation value of the Unit 1 trust ($473.5 million) as of September 30, 2001 and determined an end-of-year 2001 balance by escalating the trust asset at 6.34 percent per annum for the remaining 3 months of 2001.

After adding in the 4th Quarter 2001 contribution, the resulting end-of-year 2001 balance was $482.75 million. ($473.5 * (1.0634^(3112)) + $1.92)

Contributions of $7.68 million and earnings of $30.61 million (calculated at 6.34 percent of the year 2001 balance) are then added to the year end 2001 balance of $482.75 million to derive the end-of-year 2002 balance of $521.04 million.

Current year end balances are calculated by adding prior end-of-year balances to the current years earnings and contributions.

Year 2021 balances are calculated on a partial-year basis.

NRC Minimum: The Calendar Year 2002 NRC Minimum for Unit I of $367.01 million is calculated as follows -

PG&E's March 2001 letter to the NRC (DCL-01-026) indicated the total NRC decommissioning fund estimate in January 2001 dollars, based on preliminary October 2000 through January 2001 data, was $793.4 million. That number represents the combined Unit I and Unit 2 NRC decommissioning fund estimate.

PG&E updated the January 2001 estimate to reflect actual October 2000 through January 2001 data. The January 2001 actual combined Unit I and Unit 2 NRC decommissioning fund estimate is $795.6 million.

To determine the end-of-year 2001 total decommissioning fund estimate, PG&E escalated the balance at 5.5 percent per annum for the remaining II months of 2 000003

Enclosure 9 PG&E Letter DCL-01-1 19 2001. The resulting end-of-year 2001 balance was $835.6 million. ($795.6 *

(1.055A(11112)).

The $835.6 million was allocated to Units I and 2 using site-specific decommissioning cost estimates prepared for PG&E by TLG, Inc. By Unit, the NRC amount is as follows: / X TLG Estimate Percent of Total NRC Decom Unit I 436.6 41.6% $347.88 (41.6% * $835.6)

Unit 2 612.1 58.4 % $487.72 (58A% * $835.6)

Total 1,048.7 100.0% $835.6 Years 2002 forward, are deternined by multiplying the end-of-year 2001 amount by an escalation factor of 5.5 percent 3 000004

Enclosure 9 PG&E Letter DCL-01-119 Diablo Canyon Power Plant, Unit 2 License Expires April 26,2025 Funding Status Assumina 0.84% Net After-Tax Earnings22

($ Millions)

I Calendar Contribution Earnings Balance NRC NRC Minimum Year Minimum Status

. {20~~~~~~~~~~~02) 2001 4.08 - 641.2 487.72 Fully Funded 2002 16.32 40.66 698.26 514.54 Fully Funded 2003 0.00 . 44.27 742.53 542.84 Fully Funded 2004 0.00 47.08 789.60 572.70 Fully Funded 2005 0.00 50.06 839.67 604.20 Fully Funded 2006 0.00 53.23 892.90 637A3 Fully Funded 2007 0.00 56.61 949.51 672A9 Fully Funded 2008 0.00 60.20 1,009.71 709.47 Fully Funded 2009 0.00 64.02 1,073.72 748.50 Fully Funded.

2010 0.00 68.07 1,141.80 789.66 Fully Funded 2011 0.00 72.39 1,214.19 833.09 Fully Funded 2012 0.00 76.98 1,291.17 878.91 Full Funded 2013 0.00 81.86 1,373.03 927.25 Fully Funded 2014 0.00 87.05 1,460.08 978.25 Fully Funded 2015 0.00 92.57 1,552.65 1,032.06 Fully Funded 2016 0.00 98.44 1,651.09 1,088.82 Fully Funded 2017 0.00 104.68 1,755.76 1,148.71 Fully Funded 2018 0.00 111.32 1,867.08 1,211.88 Fully Funded 2019 0.00 118.37 1,985.45 1,278.54 Fully Funded 2020 0.00 125.88 2,111.33 1,348.86 Fully Funded 2021 0.00 133.86 2,245.19 1,423.05 Fully Funded 2022 0.00 142.34 2,387.53 1,501.31 Fully Funded 2023 0.00 151.37 2,538.90 1,583.89 Fully Funded 2024 0.00 160.97 2,699.87 1,671.00 Fully Funded 2025 0.00 55.89 2,755.76 1,701.09 Fully Funded 22 The assumption Is based upon the current California Public Utilities Commission authorized after-tax earnings rate.

2a Reflects projected end-of-year 2001 balance, Including contributions made In 2001. Liquidation value as of September 30,2001, was $627.5 million.

000005

Enclosure 9 PG&E Letter DCL-01-119 Calculation Notes for DCPP Unit 2 Contribution: PG&E is currently authorized to contribute a total of $24.003 million per year to the Diablo Canyon Nuclear Decommissioning Master Trusts. Unit 2's portion of the total contribution Is $16.32 million. For 2Q01, only the 4th Quarter contribution, to be made December 28, 2001, Is shown as a contribution. Contributions for the first three Quarters are included Inthe end-of-year 2001 balance.

Earnings: PG&E has assumed after-tax earnings to the trust of 6.34 percent per year.

(The liability (cost estimate) Is grown at 5.5 percent per year, resulting Ina 0.84 percent after-tax real growth rate on the trust.) Earnings are calculated each year by multiplying the prior year's balance by 6.34 percent Year 2025 earnings are calculated on a partial-year basis.

Balance: The end-of-year 2002 balance is determined as follows-PG&E used the liquidation value, of the Unit 2 trust ($627.48 million) as of September 30, 2001 and determined an end-of-year 2001 balance by escalating the trust asset at 6.34 percent per annum for the remaining 3 months of 2001.

After adding in the 4th Quarter 2001 contribution, the resulting end-of-year 2001 balance was $641.28 million. ($627.48 * (1.0634^(3/12)) + $4.08)

Contributions of $16.32 million and earnings of $40.66 million (calculated at 6.34 percent of the year 2001 balance) are then added to the year end 2001 balance of $641.28. million to derive the end-of-year 2002 balance of $698.26 million.

Current year end balances are calculated by adding prior end-of-year balances to the current year's earnings and contributions.

Year 2025 balances are calculated on a partial-year basis.

NRC Minimum: The Calendar Year 2002 NRC Minimum for Unit 2 of $514.54 million is calculated as follows -

PG&E's March 2001 letter to the NRC (DCL-01-026) Indicated the total NRC decommissioning fund estimate In January 2001 dollars, based on preliminary October 2000 through January 2001 data, was $793.4 million. That number represents the combined Unit I and Unit 2 NRC decommissioning fund estimate.

PG&E updated the January 2001 estimate to reflect actual October 2000 through January 2001 data. The January 2001 actual combined Unit I and Unit 2 NRC decommissioning fund estimate is $795.6 million.

To determine the end-of-year 2001 total decommissioning fund estimate, PG&E escalated the balance at 5.5 percent per annum for the remaining 11 months of 5 000006

Enclosure 9 PG&E Letter DCL-01-1 19 2001. The resulting end-of-year 2001 balance was $835.6 million. ($795.6 *

(1.055A(1 1/12)).

The $835.6 million was allocated to Units 1 and 2 using site-specific decommissioning cost estimates prepared for PG&E by TLG, Inc. By Unit, the NRC amount is as follows: / A TLG Estimate Percent of Total NRC Decom Unit I 436.6 41:6% $347.88 (41.6% * $835.6)

Unit 2 612.1 58A % $487.72 (58A% * $835.6)

Total 1,048.7 100.0%° $835.6 Years 2002 forward, are determined by multiplying the end-of-year 2001 amount by an escalation factor of 5.5 percent.

225069.10 6 000007

PG&E Letter DCL-O1-119 APPLICATION FOR CONSENT TO LICENSE TRANSFERS AND CONFORMING LICENSE AMENDMENTS FOR DIABLO CANYON POWER PLANT, UNITS I AND 2

.. ~~~~~~.I 000008

PG&E Letter DCL-01-119 For NRC decommissioning purposes, the minimum amount as of December 31, 2001, that would need to be transferred, as a condition of the NRC license transfer, in order to meet NRC requirements, would be approximately $347.9 million for Unit 1 and

$487.7 million for Unit 2. These amounts would satisfy NRC requirements for financial Assurance for decommissioning Inthe form of prepayment In accordance with 10 CFR 50.75(eXl)(i)."'

Additional amounts, beyond the NRC minimum and up to the total amount Inthe Nuclear Decommissioning Trust associated with DCPP at the time of the transfer, will be included in the beneficial interest transferred to Nuclear if and to the extent such transfer is approved by FERC and the Bankruptcy Court, as required.

3. Nuclear Insurance Gen will, upon transfer of the assets and assumption of the licenses, assume the responsibility for providing the financial protection as required by 10 CFR Part 140, and for continuing site Insurance coverage as required by Price-Anderson 10 CFR 50.54(w).-

Gen's obligations will Include the responsibilities with respect to retrospective liability required in accordance with 10 CFR 140.21.

Based upon the financial Information provided in Enclosure 8, Gen will have the financial ability to meet this obligation.

G. Antitrust Considerations The NRC has determined that antitrust reviews of post-operating license transfer applications are neither required nor authorized by the Atomic Energy Act, and therefore no antitrust Information is required to be submitted with this post-operating license transfer application.13 The NRC formulas hI 10 CFR 50.75(c) Include only those decommissioning costs Incurred by licensees to remove a facility or site safely from service and reduce residual radioactivity to levels that permit: (1) release of the property for unrestricted use and termination of the license; or (2) release of the property under restricted conditions and termination of the license. The cost of dismantling or demolishing nonradiological systems and structures Is not induded In the NRC decommissioning cost estimates. The costs of managing and storing spent fuel on site until transfer to DOE are not Included In the cost formulas. 'The Nuclear Decommissioning Trust for DCPP currently Includes funds for non-NRC decommissioning costs.

12 PG&E and/or Gen will In due course request modified Price-Anderson Indemnity agreements and will make changes to nuclear liability and property coverages to reflect Gen as the operator and Nuclear as the owner, and each as an additional named Insured.

13 Final Rule, Antitrust Review Authority: Clarification, 65 Fed. Reg. 44,649 (July 19, 2000); see also Kansas Gas and Electric Co. (Wolf Creek Generating Station, Unit 1), CLI-99-19, 49 NRC 441 (June 18, 1999).

12 000009

PG&E Letter DCL-01-1 19 However, because the Plan calls for a restructuring that would split generation assets from the transmission and distribution businesses, the antitrust conditions currently included in Appendix C of the DCPP licenses would not and could not apply directly to Gen or Nuclear. The conditions also could not apply solely to PG&E.

Under the Plan, reorganized PG$E will be a local electric and gas distribution company serving retail customers in Northern and Central California. The company will have a service territory that covers 70,000 square miles. PG&E will contribute Its approximately 18,500 circuit miles of electric transmission lines and cables located in California to ETrans. This will include approximately 1,300 circuit miles of 500 kV lines, 5,300 circuit miles of 230 kV lines, 6,000 circuit miles of 115kV lines and 4,000 circuit miles of 70 and 60 kV lines, and the towers, poles and underground conduit used to support the lines and cables. In addition, ETrans and Its subsidiaries will receive all transmission substations, transmission control centers and associated operations systems, junctions and transmission switching stations and associated equipment necessary to support the lines and cables and all of the other land, entitlements, rights of way, access rights, personal, real and intellectual property and the business records necessary to operate the electric transmission business.

Currently, PG&E is a participating transmission owner in the Califomia Independent System Operator (ISO), the entity that operates and controls most of the electric transmission facilities owned by the State's three major investor-owned utilities and provides open access to electric transmission services on a non-discriminatory basis. The ISO uses PG&E's transmission facilities to provide open access transmission service. As part of the restructuring, PG&E will assign to ETrans its contractual obligations as a participating transmission owner in the ISO. 14 Accordingly, with respect to the existing antitrust license conditions, PG&E proposes to retain those conditions at this time. In order to preserve as nearly as possible the current antitrust obligations, PG&E proposes to retain reorganized PG&E on the license with respect to antitrust conditions and to add ETrans as a licensee for those conditions, as PG&E's successor with respect to the transmission system. PG&E and ETrarWs would be licensees for the limited purpose of the antitrust license 14 In December 1999, the FERC Issued ts final rule on Regional Transmission Organizations (RTOs) and encouraged utilities that own transmission systems to form RTOs on a voluntary basis. In several orders Issued on July 12.2001, the FERC indicated ts strong preference for a single RTO that encompasses most of the Western United States, including California, and potentially Canadian provinces as well, that are Interconnected In the region encompassed by the Western Systems Coordinating Council. No RTO Is operational hI the Western United States at this time. ETrans Intends to join a FERC-approved Western RTO at such time as one Is established and approved by FERC.

13 000010

PG&E Letter DCL-01-119 conditions. Along with Gen, PG&E and ETrans will be jointly and severally responsible for those conditions. This arrangement Is reflected in the proposed license mark-ups provided in Enclosures 4 and 5.

H. Resfdcted Data This application does not contain any Restricted Data or other classified defense information, and It is not expected that any such information will become involved. However, Gen and Nuclear will appropriately safeguard such information if any such Information does become involved and will not permit any individual to have access to any such information until the Office of Personnel Management (the successor to the Civil Service Commission) shall have made an Investigation and report to the NRC on the character, associations, and loyalty of such individual, and the NRC shall have determined that permitting such person to have access to Restricted Data will not endanger the common defense and' security of the United States.

. 'No EnvironmentalImpact The proposed license transfers and conforming license amendments meet the categorical exclusion criteria of 10 CFR 51.22(c)(21), in that this application does'no more than request the approval of a direct transfer of the NRC licenses and the associated conforming amendments to the licenses.

The proposed license transfers and conforming license amendments do not involve any changes to the physical operation of the plants and, accordingly, do not involve any increase in the amount or type of radiological effluents that may be allowed to be released offsite. The proposed transfers and' license amendments also do not involve any increase in the amount or type of any non-radiological effluents that may be released offsite. Further, the proposed transfers and license amendments do not Involve any increase in individual or cumulative occupational radiation exposure. In sum, the proposed actions will have no environmental impact. Accordingly, if necessary, PG&E requests that the NRC issue and publish a finding of no significant environmental impact pursuant to 10 CFR 51.32 and 51.35.

IV. Additional rnformation on Re-tulatory Issues A. Design and Ucensing Basesftndates to FSAR The proposed license transfers and conforming license amendments will designate Gen as the licensee authorized to possess, use, and operate the DCPP nuclear units. The transfers and amendments will not affect the physical configuration of the facilities or alter any substantive Technical Specification requirements under which the units operate. Gen will control or have access to the design and licensing basis documents to 14 000011

PG&E Letter DCL-01-119 the same extent as PG&E does now, and the proposed transfers and conforming amendments will not affect tHte design and licensing bases.

Changes to the Updated Final Safety Analysis Report necessary to reflect the change in responsible licensee will be Incorporated on a schedule that complies with 10 CFR 50.71 (e) following NRC approval of the transfers.

B. Emermencv Planninq Concurrent with the transfers of operating authority, Gen will assume authority and responsibility for functions necessary to fulfill the emergency planning and preparedness requirements of 10 CFR 50.47(b)yand Part 50, Appendix E. No changes will be made that reduce the effectiveness of the emergency plans or that adversely impact compliance with the NRC's emergency planning requirements.

Prior to Implementation of the reorganization, the emergency plans will be reviewed in detail and any needed changes to the plans or Implementing procedures will be made Inaccordance with 10 CFR 50.54(q) and Part 50, Appendix E,Section V, as appropriate. No major substantive changes to the existing emergency plans presently implemented by PG&E are anticipated as a result of the transfer. Likewise, no substantive changes are anticipated to the existing emergency planning organization.

Generally, the current emergency facilities, equipment, and organizations will be transferred to Gen or Nuclear. As necessary, ownership of off-site emergency sirens will be transferred to Gen or Nuclear and provisions will be made, as needed, for the sirens to continue to be located on poles owned by the distribution company.

As part of the transition process, PG&E will evaluate offsite corporate support for the emergency plan and will make provisions for continued offsite corporate support, if needed. Existing agreements for support from outside organizations and agencies also will be reviewed such that appropriate actions can be taken, at an appropriate time prior to the transfers, to notify the parties to such agreements of the Plan and Gen's anticipated responsibility for management and operation of DCPP.

Support agreements will be assigned to Gen, if necessary.

C. Offslte Power Offsite power Is currently provided to DCPP over transmission facilities owned by PG&E and operated by the ISO. As a result of the disaggregation of assets, certain transmission assets will be transferred to ETrans. However, the physical facilities will not change as a result of the change in ownership of and operating authority for DCPP. Independent sources of offsite power will continue to be provided to the stations in compliance with 10 CFR Part 50, Appendix A, General Design Criterion 17.

15 000012

PG&E Letter DCL-01-1 19 Gen will establish an Interconnection agreement with ETrans and will have power for DCPP pursuant to the bilateral contract between Gen and PG&E. Additionally, certain, nuclear protocols related to the operation of the transmission system are already established by agreement between PG&E and the ISO, and these nuclear protocols will remain in place.

Under an agreement between Gen and ETrans, ETrans will be . ,

responsible for the relationship with the ISO. Also, the agreements with

{ ETrans will address continued maintenance of the transmission equipment that ETrans will own.

D. Exclusion Area Control As the current owner and plant operator of DCPP, PG&E has the authority to determine and control activities within the exclusion areas for the DCPP plant site at least to the extent required by 10 CFR Part 100. As a result of the transfer of ownership of DCPP and related assets to Nuclear, and the lease agreement between Nuclear and Gen, Gen will have the required exclusion area control. Nuclear will own, and lease to Gen, essentially the same property as PG&E presently owns and controls, with the exception of certain transmission facilities. With respect to the transmission facilities, maintenance and switchyard agreements with ETrans will provide Gen with the right to determine activities in the exclusion area to the extent necessary to meet Part 100. This authority will extend to any activibes of ETrans or other authorized entity with respect to maintenance of the switchyard and transmission facilities.

With respect to other activities unrelated to plant operations that will occur within the exclusion area previously Identified in the DCPP Updated Final Safety Analysis Reports, there will be no changes. Gen will assume responsibility for the emergency plans as discussed above.

E. Security Concurrent with the transfer of ownership and- operating authority, Gen will assume authority and responsibility for the functions necessary to fulfill the security requirements of 10 CFR Part 73. No material changes are expected to the existing physical security organization, guard training and qualifications, safeguards contingency plans, or equipment Accordingly, the proposed license transfers will not impact compliance with the NRCs security requirements.

Existing agreements for support from outside organizations and ageincies will be reviewed such that appropriate actions can be taken prior to the transfers to notify parties to such agreements of Gen's relationship with PG&E, the plan of reorganization, and Gen's anticipated responsibility for management and operation of DCPP. Support agreements will be assigned to Gen, if necessary.

16 000013

PG&E Letter DCL-01-119 Any changes to the security plans to reflect the transfer of responsibility will not decrease the effectiveness.of the plans and will be made in accordance with 10 CFR 50.54(p).

F. Qualif Assurance The proposed transfers will not impact compliance with the quality assurance requirements of 10 CFR Part 50, Appendix B. nor will they reduce the commitments in the NRC-accepted quality assurance programs for DCPP. Concurrent with the transfers of ownership and operating authority, Gen will assume authority and ultimate responsibility for present functions associated with the quality assurance programs. The transfers of the licenses to Gen will not degrade the effectiveness of these functions. Any changes to the Quality Assurance Program to reflect the transition will not reduce the commitments in the quality assurance program description and will be handled in accordance with 10 CFR 50.54(a).

G. Tralntnh The proposed license transfer will not impact compliance with the operator re-qualification program requirements of 10 CFR Part 50.54 and related sections, nor maintenance of the Institute of Nuclear Power Operations accreditation for licensed and non-licensed personnel training.

Concurrent with the license transfers, Gen will assume responsibility for implementation of the present operator training programs. Changes to the programs to reflect the transition will not decrease the scope of the approved operator requalification program and will be made in accordance with 10 CFR 50.54(i).

H. Spent Fuel Storage Upon transfer of ownership and operating responsibility, Gen will assume responsibility for safe storage of the fuel as one of its DCPP operational responsibilities. Nuclear will assume title to spent nuclear fuel located at DCPP. PG&E will assign to Nuclear its rights and obligations under the Standard Contract with the Department of Energy, as well as related claims.

By separate license and amendment applications, PG&E in the near futureowill request a site-specific Part 72 license for the proposed DCPP ISFSI and will request related amendments to the DCPP Part 50 license.

PG&E anticipates that, given the current anticipated schedules, the Part 72 ISFSI license will be issued after the license transfers requested herein and after the implementation of the proposed reorganization.

Accordingly, PG&E anticipates that Gen will become the initial ISFSI licensee as operator of that facility.

17 000014

ORIGINAL I THIS PROPOSED DISCLOSURE STATEMENT IS NOT A SOLCITATION OF ACCEPTANCE OR REJECTION OF THE PLAN. ACCEPTANCES OR REJECTIONS MAY NOT BE SOLICITED UNTIL A 2 DISCLOSURE STATEMENT HAS BEEN APPROVED BY THE BANKRUPTCY COURT. THIS PROPOSED DISCLOSURE STATEMENT IS BEING SUBMTTED FOR APPROVAL BUT HAS NOT BEEN APPROVED 3 BY THE BANKRUPTCY COURT.

4 5 UNITED STATES BANKRUPTCY COURT 6 NORTHERN DtSTRICT OF CALIFORNIA FI LED 7 SAN FRANCISCO DIVISION SEP 202i01 1UNIED :C 8

9 In re Case No. 01 30923 DM t0 PACIFIC GAS AND ELECTRIC COMPANY, Chapter I ICase a California corporation, 11 [No Hearing Requested]

• Debtor.

12 Federal LD. No. 94-0742640 4

E3 13 4 ox~

a~ 14 DISCLOSURE STATEMENT FOR PLAN OF REORGANIZATION tvem UNDER CHAPTER II OF THE BANKRUPTCY CODE FOR

. .15 PACIFIC GAS AND ELECTRIC COMPANY PROPOSED BY PACIFIC GASR AND eFL.MMCOMPANY 20 G&001RATN 16 ' [Dated September20, 2001) 17 Counsel for the Debtor, Pacific Gas and Counsel for PG&E Corporation:

18 Electric Company:

19 HOWARD, RICE, NEMEROVSKI, WVVL, GOTSHAL & MANGES LLP 20 CANADY, FALK & RABKIN 700 Louisiana, Suite 1600 A Professional Corporation Houston, Texas 77002 21 Three Enbarcadero Center, 7th Floor (713) 546-5000 San Francisco, California 94111 22 (415)434-1600 23 DEWEY BALLANTINE LLP Co-Cotmsel to PG&E Corporation for 1301 Avenue of the Amiericas

. 24 Constitutional Law Matters: New York, New York 10019-6092 (212) 259-8000

25. Professor Laurence Tribe 26 Hauser Hall 420 1575 Massachusetts Avenue 27 Cambridge, Massachusetts 02138 (617) 49S-4621 28 DISCLOSURE STATEMENT FOR PLAN OF REORGANIZAlON 000015

1 the Plan represents dhe best method for the holders of Allowed Claims and Equity Interests to be 2 paid in full for such Allowed Claims and Equity Interests. The Plan is annexed hereto as Exhibit A 3 and forms a part of this Disclosure Statement The summary of the Plan is qualified in its entirety 4 by reference to the provisions of the Plan.

5 B. RESTRUCTURING OF THE ELECTRIC TRANSMISSION BUSINESS.

6 1. GeneraL 7 On or before the Effective Date, the majority of the assets generally associated with the 8 Debtor's current electric transmission business (the "ETrans Assets) will be transferred to ETrans 9 and its subsidiaries or affiliates, and ETrans will operate as a separate electric transnmission company 10 thereafter. Other assets necessary to support the ETrans business, including certain minor assets 11 currently classified as distribution for ratemaking purposes, will also be transferred by the Debtor to 12 ETrans or its subsidiaries or affiliates. Specifically, the Debtor will transfer approximately 18,500 13 circuit miles of electric transmission lines and cables, located in California, which will include 1,300 GV#= 14 circuit miles of 500 kV lines, 5,300 circuit miles of 230 kV lines, 6,000 circuit miles of 115 kV lines 15 and 4,000 circuit miles of 70 and 60 kV lines, and the towers, poles and underground conduits used 16 to support the lines and cables. In additdon, ETrans and its subsidiaries or affiliates will receive all 17 transmission substations, transmission control centers and associated operations systems, junctions 18 and transmission switching stations and associated equipment necessary to support the lines and 19 cables and all of the other land, entitlements, rights of way, access rights, personal, real and 20 intellectual property and the business records necessary to operate the Debtor's electric transmission 21 business. The Debtor's existing internal telecommunications backbone assets will also be 22 transferred to ETrans or one of its subsidiaries or affiliates.

123 Pursuant to section 365 of the Bankruptcy Code, the Debtor will also assume and assign 24 to ETrans certain of the continuing contractual rights and obligations of the Debtor that are 25 associated with the operation of the electric transmission business, after which the Debtor will be 26 relieved ofany obligations thereunder. Such contracts include those related to service over the 27 Pacific Intertie, including certain "EHV" tranrsission agreements and contracts for the ownership, 28 use and coordinated operation of the California-Oregon Transmission Project In addition, the DISCLOSURE STATEMENT FOR PLAN OF REORGANIZATION 000016

I Debtor will assume and assign to ETrans several interonnection agreements with utilities and 2 agencies in the Debtor's service area and certain other entities. ETrans will also enter into contracts 3 with the Reorganized Debtor to enable the Reorganized Debtor to continue to provide 4 interconnection and transmission services under contracts to be assumed by the Reorganized Debtor, S including those with (a) the Western Area Ppwer Administration, U.S. Department of Energy and 6 certain of its customers and (b) the City and County of San Francisco.

7 2. Formation and Capitalization.

8 ETrans will be a California limited liability company with Newco as its sole member.

9 The Debtor will be the sole shareholder of Newco. On or before the Effetive Date, the ETrans 10 Assets set forth on Schedule 7.2(a) to the Plan Supplement will be transferred to ETrans and its 11 subsidiaries or affiliates in partial exchange for an estimated $770 million in cash (subject to 12 adjustment), approximately $380 million in long-term notes and the assumption by ETrans and its 13 subsidiaries of certain liabilities and obligations of the Debtor, all as set forth on Schedule 7.2(b) to Cm+= 14 the Plan Supplement. Thereafter, but prior to the Reorganized Debtor Spin-ft the Debtor will IS declare and pay a dividend of the outstanding common stock of Newco to the Parent, and ETrans 16 will continue as an indirect wholly-owned subsidiary of the Parent.

17 3. Operational Control of ETrans Assets.

18 Currently, the Debtor is a participating transmission owner in the ISO, the entity that 19 operates and controls most of the electric transmission facilities owned by the State's three major 20 investor-owned utilities and provides open access to electric transmission services on a non-21 discriminatory basis. As part of the Debtor's participation, the ISO uses the Debtor's transnission 22 facilities to provide transmission service. On or before the Effective Date, the Debtor will assume 23 and assign to ETrans certain of its contractual obligations associated with its participation as a' 24 transmission owner in the ISO.

25 In December 1999, the FERC issued its final rule on Regional Transmission 26 Organizations ("RTO") and encouraged utilities that own transmission systems to form RTOs on a 27 voluntary basis. In several orders issued on July 12,2001, the FERC indicated its strong preference 28 for a single RTO that encompasses most of the Western United States, including California, and DISCLOSURE STATEMENT FOR PLAN OF REORGANIZATION 000017

I potentially Caiadian provinces as well, that are interconnected in the region encompassed by the 2 Western Systems Coordinating Council. No RTO is operational in the Western United States at this 3 time. ETrans intends to join a FERC-approved Western RTO at such time as one is established and 4 approved by FERC. If the FERC certifies the ISO as a RTO, ETrans may decide to remain with te 5 ISO. Prior to any withdrawal from the ISO,*ETrans will provide notice of its withdrawal to the ISO 6 pursuant to the terms of the Transmission Control Agreement.

7 4. Management and Employees.

8 A list of the individuals who will initially serve as members of the board of control and 9 executive officers of ETrans, together with biographical information for such persons, will be 10 provided supplementally.

11 Most of the current employees of the Debtor who provide services primarily for the 12 'electric transmission business will be transferred to or offered comparable positions with ETrans or 13 its subsidiaries on or before the Effective Date. Job assignments or employment offers will be made

" 14 consistent with theDebtor's and ETrans' respective rights and obligations under applicable law, 15 labor contracts and policies. The Debtor anticipates that a totalvof 1,100 to 1,300 managerial, 16 professional, administrative and union employees will be employed by ETrans and its subsidiaries.

17 In addition, ETrans will use independent contractors consistent with the historical practices of the 18 Debtor to perform certain of its core services and provide support during peak service periods.

19 Certain employees of the Debtor currently provide engineering, maintenance, construction and other 20 services that relate to both the distribution and electric transmission businesses of the Debtor. After 21 the Effective Date, such employees may be employees of ETrans or the Reorganized Debtor and 22 provide services between the Reorganized Debtor and ETrans pursuant to a service and maintenance 23 agreement to be entered into between ETrans and the Reorganized Debtor to allow for a transition to 24 independent operations. See Section VIJ. and Section VLK of this Disclosure Statement for more 25 information on separation issues and human resources following the Restructuring Transactions.

26 "S. Regulation.

27 a. Regulatory Approvals for Restructuring.

28 In connection with the transfer of the ETrans Assets to ETrans and its subsidiaries or DISCLOSURE STATEMENT FOR PLAN OF REORGANIZATION 000018

I affiliates, the assumption of certain of the electric transmission contracts by ETrans and the indirect 2 transfer of interests in ETrans to the Parent, the Debtor will take certain actions with the following 3 governmental agencies:

4 F*

FER: Pursuant to Section 203 of the FPA, the Debtor will request FERC approval for the transfer of the ETrans Assets and the interests in EMrans. In reviewing the 5 . application, the FERC will determiine if the transfer of such assets aridinterests is consistent with the public interest based on the anticipated impact on competition, rates 6 and regulation. In conjunction with the application, the Debtor may seek a FERC 7 determination that all assets proposed for transfer to ETans and its subsidiaries are under FPA jurisdiction. In addition, the Debtor will request FERC approval under Section 8 of the FPA in connection with the transfer of transmission lne-only licenses to 8 ETrans. In reviewing the application, the FERC will determine the nial and technical ability of ETans to operate the transmission facilities. FERC confirmation, 9 approval or acceptance will also be quested under Sections 204 and 305 of the FPA relating to the issuance of securities and assumption of liabilities in connection with the

10. transfer of interests and, if applicable, te creation of interlocldng directorates, and under Section 205 of the FPA with respect to new or modified service tariffs. In conjunction 1! with the application under Section 203 of theFPA, ETrans will commit to participate in a FERC-approved RTO and, as necessary or appropriate to satisfy that commitment,-

12 withdraw from participation in the ISO. Assuming no evidentiary hearing, the Debtor anticipates that the FERC approvals will be obtained within eight months after the date H0W,,D 13 the applications are filed. TheDebtor currently intends to submit such applications on

.or before November 30,2001.

ON" 14 emM SEC: Following the Restructuring Transactions, the Parent will be, as it is currently, a 15 holding conmpy exempt from registration under Section 3(aXI) of the Public Utility Holding Company Act of 1935 ('PUHCA!). As the Parent will own two public utilities 16 (ETrans and Gen) after the Restructuring Transactions are completed, the Parent will request SEC approval for the indirect acquisition of the ETrans membership interests 17 pursuant to Section 9(aX2) of PUHCA. There wil be a period of time prior to the Reorganized Debtor Spin-Off in which the Parent will also own the Reorganized Debtor.

19 Approval for such interim ownership will also be sought. In connection with its review process, the SEC will examine and, as necessary, determine whether (i) the acquisition 19 will unduly concentrate control of utility systems, (ii) the purchase price is reasonable, (iii) the acquisition will unduly complicate the capitalization of the resulting system, (iv) 20 applicable state laws have been complied with or preempted, and (v) the transaction will serve the public interest by facilitating the economic and efficient development of an 21 integrated public utility system. Assuming no evidentiary hearing, it is anticipated that SEC approval will be obtained within one to three months after all other regulatory 22 approvals have been obtained.

23

• iC: Ifthe Debtor were not subject to thejurisdiction ofthe Banknuptcy Court, under the California Public Utilities Code the approval of the CPUC would be required to 24 transfer many of the ETrans Assets to ETrans and its subsidiaries or affiliates, to transfer operational control of its transmission facilities from the ISO to a FERC-approved RTO, 25 for the operation ofthe ETrans Assets and to otherwise effect the Restructuring Transactions. In connection with the confirmation of the Plan, however, the Debtor will 26 seek an affirmative ruling from the Bankruptcy Court that such approval is not required i 27 because section 1123 of the Bankruptcy Code preempts such state law.

• *Other Federal Agencies: The Debtor and ETrans and its subsidiaries or affiliates will 28 seek approval of various federal agencies for the transfer of federal permits, rights-of-DISCLOSURE STATEMENT FOR PLAN OF REORGANIZATON 000019

way and other authorizations as required.

2

• Other State and Agencies:

ca If the Debtor were not subject to the jurisdiction of the-Banruptcy Court, the Debtor would seek the approval ofnumerous state and local 3 agencies for the transfer and use of various permits, licenses, leases and other entitlemenlts in connection wih the transfer and operation of the ETrans Assets. In 4 connection with the confirmation of the Plan, however, the Debtor will seek an afliinative ruling from Ban ptcy Court that such approvils are not required to S effect the transfers because sectibn l 123 of the Bankauptcy Code preempts such state and local laws.

6

.7 b. Post Restructuring Regulation of ETmns.

8 Upon consuniation of the Plan, the operations of ETrans will be subject to the 9 jurisdiction of the following governmental agencies:

10

• FEEC: The FERC will have jurisdiction over ETrans' rates, terms and conditions for all transmission and transmission-related services, including, but not limited to, conditions 11 of transmission access and interconnection. In addition, the FERC will havejurisdiction over ETrans' participation in the ISO or any future Western RTO which will hav, 12 operating control over the transmission assets pursuant to FERC tariffs.

4 W 13 * £PUO  : The CPUC will retain junsdiction over siting of transmission construction and a) non-ratejurisdiction over certain aspects of ETrans' operations to the extent not teA3 xT14 otherwise preempted by the overriding jurisdiction of FERC.

=IS 15

• Th-Ot6 Federal. State and Local Ageficies: The ongoing operations of ETrans will continue to be subject to a variety of other federal, state and local agencies following 16 consummation of the Plan.

17 C RESTRUCTURING OF THE GAS TRANSMISSION BUSINESS.

18 1. General.

1.9 On or before the Effective Date, the majority of the Debtor's assets associated with its 20 current gas transmission business (the "GTrans Assets) will be transferred to GTrans and its 21 subsidiaries or affiliates and GTrans will operate as a separate interstate gas transmission company 22 therealfer. Specifically, tie Debtor will transfer approximately 6,300 miles of transmission 23 pipelines, three gas storage facilities and certain end-use customer service lines. GTrans and its 24 subsidiaries will receive all of the land, entitlements, rights of way, access rights, personal and 25 intellectual property and the business records necessary to operate the Debtor's current gas 26 transmission business. Pursuant to section 365 of the Bankruptcy Code, the Debtor will also assume 27 and assign to GTrans certain of the continuing contractual obligations of the Debtor that are 28 associated inth the operation of the gas transmission and storage business, after which the Debtor DISCLOSURE STATEMENT FOR PLAN OF REORGANIZAON 000020

Plan of Reorganization Under Chapter 11 of the Bankruptcy Code for Pacific Gas and Electric Company Exhibit C (Partial)

I, IA 000021

ETrans ($Miions) 121tXU2 12131103 12431104 1==U0 INCOME STATEMENT Total Operating Revenues 773.8 847.0 905.5 Qpemfgenses:

Grd Serces 263.0 260.0 258.0 M&O nd A&G Costs 166.3 169.4 172.6 Dipredacton 111.4 122.3 134.8 Properdy & OtlerTaxes 23.6 26.9 30.0 Total Operating Expenses 564.3 57e6 96.3 Operat k=me 209.5 267.5 309.2 Total Interest Income 0.0 0.0 0.0 I Total bnterest Expense Othercoe 6? 101.0 111.6 5.6 6.6 6.1 Pretax Income 11&4 1?3.0 203.7 Total B0ooed Income Taxes 48.3 ?0.5 U3.0 Pefened DWIdend Req 0.0 0.0 0.0 Total Earnings AvaSl fr Common

• 70.2 102.5 120.7 I

ii 000022

EBrans (SMamons) 1* 12131102 12131103 12131104 12m1los BALANCE SHEET Assets Plant hIServie 3192 3514.8 3895.3 4231.6 Acc:mulated De (11A39) (1247.3) (1307A) (1381.7)'

NetPlant 2056.6 2267.5 2587.9 2850.0 I Constructon Work In Progress Oter Noncurrent Assets 57.6 0.0 58.8 0.0 60.0 0.0 612 0.0 I ToWal LaQ4erm Assets CUrrenfAssets:

2114.2 2326.2 2647.9 2911.1 Short-term Investnents (Net) 0.0 0.0 0.0 0.0 Accaounts Receivable 74.9 827 90.5 96.6 U Other Current Assets Total Cument Assets 58 80.7 5.9 886 6.1 96.6 6.1 1029 Deferred Caes 204.3 204.3 204.3 204.3 TOTAL ASSETS 23992 2619.1 298.7 32183 I

qI 000023

Man E~~~~rans

~~~~~($MurWon)

CoGu on Strk Equity 5363 754.3 964 1062.3 Pmeferred Stock od QCIDS) o.0 0.0 0.0 OA O Lerlongerm Debt 1250.0 1250Q 1362.8 1525.6/

Totl Capttarmza0on 1786. 2004.3 2327.6 25861 Ctnnt Liabitiew Short-Term Bauroologs plet) 0.0 0.0 0.0 0.0

_cco" Payable 423 42.3 42.4 42.6 Balancing Acccant Payable 0.0 0.0 0.0 6.0 Accrued Tws Pyable 4.3 45.6 46.9 47.6 Long-Term Deb -Current 0. 0.0 0.0 0.0 Interest Pay" 0.0 O0 0. 0.0

-Dividends Payable 0.0 0.0 0.0 0.0 Other Current Uab![Wes 42.4 424 4Z4 424 Total Current Uabes 131.0 1313 131.7 132.5 Oefenred Credits and OUter NC Labx's Deferred Income Tsxes 307.3 3i3. 3202 328.8 Deferred ITC 142 13.6 13.1 12.6 Noncent Balanclng Acct Uab 0.0 Q.O 0. OA CustomerAdvances for Constuction O 0.0 0.0 0.0 Other Deferred Credits 155.1 155.7 1562 156.3 Other Noncurrent uab. 52 0.5 0.0 0.0 Total Deferred Credits &NC Lbs 481.9 483.5 489.5 497.6 TOTAL CAPITAL L& UABTMES 23992 2619.1 2948.7 3218&3 000024

Errans -$ilas 12131102 12131103 12131104 12=3115 CASH FLOW STATMENT COs Rom Fiom OperatOoS Net himome 702 102S 120.7 Deprelation 1222S 134. ' .

Change hi Deferred Taxes &4 L9 82 Change hIAccrs Receivable (7.8) (7.8) (63)

Change hi hentoies 0.0 0.0 0.0 Change hIAcrts Payable 0.1 0.1 0.1 Change hi Accrued Taxes Payable 0.3 0.3 0.7 Change hi Other Waldng Capital (0.0) 0.0 0.0 Oher Net Cash ton Operations (6).3 0.0 - 0.0 Net Cash fom Operations 174.3 223.3 2 Capaal Expemftzw (322.3) (444.0) (398.1)

Other Net hwestlng Actvltes 0.0 0.0 0.0 Net Cash Used hI investIg (322.2) (444.C) (398.1)

FinncbigAdMies Cornan Stock Issued Feprchased) 148.0 107.9 (232)

Prefesred Stock bisued 0.0 0.0 0.0 Preferred Stock redeemed 0.0 0.0 0.0 Long-erm Debt Issued 0.0 112.e 163.0 Lang-erm Debt mraturedfredeemed 0.0 0.0 0.0 Long4ermn Debt purchsthkig 0.0 0.0 0.0 Change In Short-erm Position 0.0 0.0 0.0 Dividends Disbtused 0.0 0.0 0.0 Other Net Financing Activities 0.0 0.0. 0.0 Net Cash Used In Fia 148.0 220.7 139.

Net Change hI Cash 0.0 - 0.0 0.0 000025