DCL-09-021, Submittal of Decommissioning Funding Report

Submittal of Decommissioning Funding Report

ML090990542
Person / Time
Site:	Diablo Canyon
Issue date:	03/31/2009
From:	Becker J Pacific Gas & Electric Co
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
DCL-09-021
Download: ML090990542 (34)

Text

Pacific Gas and Electric Company James R.Becker Diablo Canyon Power Plant Site Vice President Mail Code 104/5/601 P.0. Box 56 Avila Beach, CA 93424 805.545.3462 Internal: 691.3462 March 31, 2009 Fax: 805.545.6445 PG&E Letter DCL-09-021 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Docket No. 50-275, OL-DPR-80 Docket No. 50-323, OL-DPR-82 Diablo Canyon Units 1 and 2 Decommissioning Funding Report for Diablo Canyon Power Plant Units 1 and 2

Dear Commissioners and Staff:

PG&E is submitting the decommissioning fund report for Diablo Canyon Power Plant (DCPP) Units 1 and 2, pursuant to the requirements of 10 CFR 50.75(f).

Diablo Canyon Units 1 and 2 At the end of calendar year 2008, the market value of the DCPP Units 1 (3411 MWt) and 2 (3411 MWt) decommissioning trust fund Market value was $612.5 million and

$843.6 million respectively. Based on the site-specific decommissioning cost estimate prepared by TLG Services, Inc. and adjusted per the Nuclear Decommissioning Cost Triennial Proceeding (NDCTP) Decision 07-01-003 from the California Public Utilities Commission (CPUC), PG&E is confident that the DCPP Units 1 and 2 decommissioning trust fund balance in 2024 and 2025 will meet the minimum NRC decommissioning amount of $540.8 million (2009 dollars) for each unit that was calculated pursuant to the requirements specified in 10 CFR 50.75(c).

Supportinq Cost Estimates Based on site-specific cost estimates prepared by TLG Services, Inc., and adjustments as a result of the NDCTP Decision 07-01-003, PG&E has estimated that the decommissioning costs are approximately $679.5 million for DCPP Unit 1 and

$720.9 million for Unit 2 in 2009 dollars. These costs do not include site restoration of the facilities ($256.4 million) nor spent fuel management costs after shutdown of Units 1 and 2 ($261.0 million).

To assure that sufficient funds will be available for decommissioning, PG&E has established separate external sinking trust fund accounts for DCPP Units 1 and 2.

A member of the STARS (Strategic Teaming and Resource Sharing) Alliance Callaway

• Comanche Peak

• Diablo Canyon - Palo Verde

• San Onofre

• South Texas Project

• Wolf Creek

Document Control Desk PG&E Letter DCL-09-021

~ March 31, 2009 6 Page 2 Supporting Enclosures Supporting documentation for this report is included as Enclosures 1 through 3.

Enclosure 1 provides decommissioning funding status information in a format suggested by NEI and the NRC.

Enclosure 2 provides information on the escalation of the required decommissioning funding amounts from 1986 dollars to 2009 dollars. As required by 10 CFR 50.75(c)(2),

and using NUREG 1577, "Standard Review Plan on Power Reactor Licensee Financial Qualifications and Decommissioning Funding Assurance," Revision 1 and NUREG 1307, "Report on Waste Burial Charges," Revision 13, the information includes escalation factors for energy, labor, and waste burial costs.

Enclosure 3 provides the TLG Services, Inc. decommissioning cost estimate report prepared in August 2005 for PG&E for DCPP Units 1 and 2. The TLG Services, Inc.

cost estimate has then been adjusted to reflect the costs in 2009 dollars per CPUC Decision 07-01-003 by applying the escalation factors; adjusting the burial costs of Class A Low Level Radioactive Waste to $248 per cubic foot; and the contingency to 35 percent. The report provides cost estimates for decommissioning of both nuclear and non-nuclear facilities, including the Independent Spent Fuel Storage Installation.

There are no Regulatory commitments in this letter. Should you have any questions in regard to this document pies feel free to call Robert Kapus at (707) 444-0810.

SSinc* rely, James R. Becker Site Vice President Enclosures cc/enc: Elmo E. Collins, Regional Administrator, NRC Region IV Michael A. Dusaniwskyj, US NRC Headquarters Michael S. Peck, NRC Senior Resident Inspector Alan B. Wang, NRC Project Manager Diablo Distribution INPO A member of the STARS (Strategic Teaming and Resource Sharing) Alliance Callaway

• Comanche Peak

• Diablo Canyon

• Palo Verde o San Onofre

• South Texas Project

• Wolf Creek

Enclosure 1 PG&E Letter DCL-09-021 NRC Decommissioning Funding Status Report Diablo Canyon Power Plant - Units 1 (3411 MWt) & 2 (3411 MWt)

As provided in 10 CFR 50.75(f)(1), each power reactor licensee is required to report to the NRC on a calendar year basis, beginning on March 31, 1999, and every 2 years thereafter, on the status of its decommissioning funding for each reactor or share of reactor it owns.

1. The minimum decommissioning fund estimate, pursuant to 10 CFR 50.75 (b) and (c)1

$ in Millions Value in January 2009 dollars Unit 1 $ 540.8 Unit 2 $ 540.8

2. The amount accumulated at the end of the calendar year preceding the date of the report for items included in 10 CFR 50.75 (b) and (c). (Alternatively, the total amount accumulated at the end of the calendar year preceding the date of the report can be reported here if the cover letter transmitting the report provides the total estimate and indicates what portion of that estimate is for items not included in 10 CFR 50.75'(b) and (c)).

Market Value (December 2008 dollars) Unit 1 $ 612.5 Unit2 $ 843.6

3. A schedule of the annual amounts remaining to be collected; for items in 10 CFR 50.75 (b) and (c). (Alternatively, the annual amounts remaining to be collected can include items beyond those required in 10 CFR 50.75 (b) and (c) if the cover letter transmitting the report provides a total cost estimate and indicates what portion of that estimate is for items that are not included in 10 CFR 50.75 (b) and (c). (See item 6 of this enclosure describing the collection of additional funds)

Unit 1 amount remaining $ 5.5

($1.8 million for 3 years beginning 2007)

Unit 2 amount remaining $0 The NRC formulas in section 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 included 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.

Enclosure 1 PG&E Letter DCL-09-021

4. The assumptions used regarding escalation in decommissioning cost, rates of earnings on decommissioning funds (anticipates that the portfolio of each trust will be gradually converted to a more conservative all income portfolio beginning in 2020 for Unit 1 and Unit 2), and rates of other factors used in funding projections; Escalation in decommissioning costs 4.50 percent Rate of Return on Qualified Trust Unit 1 2006 6.02 percent Rate of Return on Qualified Trust Unit 1 2007 5.85 percent Rate of Return on Qualified Trust Unit 1 2008 5.73 percent Rate of Return on Qualified Trust Unit 1 2009 5.64 percent Rate of Return on Qualified Trust Unit 1 2010 5.57 percent Rate of Return on Qualified Trust Unit 1 2011 5.53 percent Rate of Return on Qualified Trust Unit 1 2012 5.49 percent Rate of Return on Qualified Trust Unit 1 2013 5.47 percent Rate of Return on Qualified Trust Unit 1 2014 5.45 percent Rate of Return on Qualified Trust Unit 1 2015 5.44 percent Rate of Return on Qualified Trust Unit 1 2016 5.43 percent Rate of Return on Qualified Trust Unit 1 2017 5.42 percent Rate of Return on Qualified Trust Unit 1 2018 5.41 percent Rate of Return on Qualified Trust Unit 1 2019 5.41 percent Rate of Return on Qualified Trust Unit 1 2020 5.18 percent Rate of Return on Qualified Trust Unit 1 2021 4.86 percent Rate of Return on Qualified Trust Unit 1 2022 4.59 percent Rate of Return on Qualified Trust Unit 1 2023 4.38 percent Rate of Return on Qualified Trust Unit 1 2024 4.23 percent Rate of Return on Qualified Trust Unit 1 (Post 2025) 4.13 percent Rate of Return on Qualified Trust Unit 2 2006 6.02 percent Rate of Return on Qualified Trust Unit 2 2007 5.85 percent Rate of Return on Qualified Trust Unit 2 2008 5.73 percent Rate of Return on Qualified Trust Unit 2 2009 5.64 percent Rate of Return on Qualified Trust Unit 2 2010 5.57 percent Rate of Return on Qualified Trust Unit 2 2011 5.52 percent Rate of Return on Qualified Trust Unit 2 2012 5.49 percent Rate of Return on Qualified Trust Unit 2 2013 5.46 percent Rate of Return on Qualified Trust Unit 2 2014 5.45 percent Rate of Return on Qualified Trust Unit 2 2015 5.43 percent Rate of Return on Qualified Trust Unit 2 2016 5.42 percent Rate of Return on Qualified Trust Unit 2 2017 5.42 percent Rate of Return on Qualified Trust Unit 2 2018 5.41 percent Rate of Return on Qualified Trust Unit 2 2019 5.41 percent Rate of Return on Qualified Trust Unit 2 2020 5.17 percent Rate of Return on Qualified Trust Unit 2 2021 4.86 percent Rate of Return on Qualified Trust Unit 2 2022 4.59 percent Rate of Return on Qualified Trust Unit 2 2023 4.38 percent

Enclosure 1 PG&E Letter DCL-09-021 Rate of Return on Qualified Trust Unit 2 2024 4.23 percent Rate of Return on Qualified Trust Unit 2 (Post 2025) 4.13 percent

5. Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v).

NONE

6. Any modifications to a licensee's current method providing financial assurance occurring since the last submitted report.

NONE

7. Any material changes to trust agreements.

NONE

8. CPUC Submittal in 2009 Dollars in Millions Total Unit 1 (Decommission 2024) $ 865.0 Scope Excluded from NRC calculations $ 185.5 Total NRC Decommissioning Costs $ 679.5 Total Unit 2 (Decommission 2025) $1,052.8 Scope Excluded from NRC calculations $ 331.9 Total NRC Decommissioning Costs $ 720.9

2009 Decommisioning Estimate Ul Enclosure 2 PG Letter DCL-09-021 Nuclear Regulatory Commission Estimate of Decommission Costs for PWR DCPP Unit 1 in 2009 DCPP PWR (millions)

Jan 1986 Estimate 105 Escalated to 1999 $118.2 (Table 2.1 in NUREG 1307 Rev 10 has no value for 1999 Burial)

Escalated to 2000 (No Submittal Required)

Escalated to 2001 $387.2 ($396.7 in 2001 Submittal)

Escalated to 2002 (No Submittal Required)

Escalated to 2003 $405.6 ($404.8 in 2003 Submittal)

Escalated to 2004 (No Submittal Required)

Escalated to 2005 $467.3 ($427.2 in 2005 Submittal)

Escalated to 2006 (No Submittal Required)

Escalated to 2007 $495.8 ($494.8 in 2007 Submittal)

Escalated to 2008 (No Submittal Required)

Escalated to 2009 $540.8 Jan 1986 based on 10 CFR 50.75 (c) Table of minimum amounts BWR based on minimum 1, 200 MWt = ($.104 + (.009xMWt)) million per unit Jan 1986 based on 10 CFR 50.75 (c) Table of minimum amounts PWR Greater than or equal to 3400 MWt = $105 million per unit between 1200 MWt and 3400 MWt (for PWR less than 1200 MWt, use P=1200MWt $75+0.0088P)

Page 1

2009 Decommissiong Estimate U2 Enclosure 2 PG&E Letter DCL-09-021 Nuclear Regulatory Commission Estimate of Decommission Costs for PWR DCPP Unit 2 in 2009 DCPP PWR (millions)

Jan 1986 Estimate 105 Escalated to 1999 $118.2 (Table 2.1 in NUREG1307 Rev 10 has no value for 1999 Burial)

Escalated to 2000 (No Submittal Required)

Escalated to 2001 $387.2 ($396.7 in 2001 Submittal)

Escalated to 2002 (No Submittal Required)

Escalated to 2003 $405.6 ($404.8 in 2003 Submittal)

Escalated to 2004 (No Submittal Required)

Escalated to 2005 $467.3 ($427.2 in 2005 Submittal)

Escalated to 2006 (No Submittal Required)

Escalated to 2007 $495.8 ($494.8 in 2007 Submittal)

Escalated to 2008 (No Submittal Required)

Escalated to 2009 $540.8 Jan 1986 based on 10 CFR 50.75 (c) Table of minimum amounts BWR based on minimum 1, 200 MWt =. ($104 + (.009xMWt)) million per unit Jan 1986 based on 10 CFR 50.75 (c) Table of minimum amounts PWR Greater than or equal to 3400 MWt = $105 million per unit between 1200 MWt and 3400 MWt (for PWR less than 1200 MWt, use P=1200MWt $75+0.0088P)

Composite Escalation Enclosure 2 PG&E Letter DCL-09-021 Calculating Overall Escalation Rate PWR Combined Escalation Rate for:

PWR Jan-86 Jan-99 Jan-00 Jan-01 Jan-02 Jan-03 Jan-14 Jan-05 Jan-0B Jan-B7 Jan-08 Jan-09 Weight (1) Jan-86 Jan-99 Jan-0S Jan-01 Jan-02 Jan-03 Jan-04 Jan-S5 Jan-OS Jan-07 Jan-S8 Jan-09 L (Labor) 1.0000 1.5624 1.6370 1.7183 1.7862 1.8630 1.9521 2.02g0 2.0724 2.1465 2.2207 2.2557 0.65 1.0000 1.1260 3.5748 3.6874 3.7458 3.8628 4.3031 4.4505 4.6044 4.7224 5.0538 5.1504 E (Energy) 1.0000 0.8499 1.0297 1.1850 0 S99091.2027 1.2164 1.4656 1.8306 1.795B 2.3262 1.7B40 0.13 B (Burial) 1.0000 0.0000 10.8039 10.9840 11.1633 11.3430 13.0733 13.3951 13.7247 14.0626 15.0364 15.6922 0.22 (1) from NUREG 1307 Revision 12, Report on Waste Burial Charges, Section 2 Summary, Page 3 ... where A, B, and C are the fractions ofthe total 19t6 dollar costs that are attributable to labor (0.65), energy (0.13), and burial (0.22), respectively, and sum to 1.5.

(2) Jan-01, Jan-03, Jan-05 and Jan-07 B (Burial) value in this table see calculation notes in Development of B Component spreadsheet Page 1

Development of E Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Energy Escalation Factor - REFERENCE NUREG-1307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)

REBASED TO 1986 = 100 PPI for Fuels & PPI for Light PPI for Fuels & PPI for Light Energy Escalation Related Products Fuel Oils Related Products Fuel Oils Factor (E)

(1982 = 100) (1982=100) (1986 = 100) (1986=100) for PWR (P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils (Diablo Canyon)

PWR wt = 0.58 PWR wt = 0.42 Jan-86 114.2 82.0 1.0000 1.0000 1.0000 Feb-86 115.0 62.4 1.0070 0.7610 0.9037 Mar-86 114.4 51.3 1.0018 0.6256 0.8438 Apr-86 113.7 49.8 0.9956 0.6073 0.8325 May-86 114.1 47.0 0.9991 0.5732 0.8202 Jun-86 115.3 44.7 1.0096 0.5451 0.8145 Jul-86 116.2 36.4 1.0175 0.4439 0.7766 Aug-86 116.3 40.1 1.0184 0.4890 0.7961 Sep-86 116.3 46.3 1.0184 0.5646 0.8278 Oct-86 113.0 43.1 0.9895 0.5256 0.7947 Nov-86 112.7 43.5 0.9869 0.5305 0.7952 Dec-86 112.3 45.6 0.9834 0.5561 0.8039 Jan-87 110.3 51.4 0.9658 0.6268 0.8235 Feb-87 109.8 53.1 0.9615 0.6476 0.8296 Mar-87 110.2 49.7 0.9650 0.6061 0.8142 Apr-87 109.9 52.0 0.9623 0.6341 0.8245 May-87 111.8 53.3 0.9790 0.6500 0.8408 Jun-87 113.9 55.1 0.9974 0.6720 0.8607 Jul-87 116.2 56.3 1.0175 0.6866 0.8785 Aug-87 115.7 59.4 1.0131 0.7244. 0.8919 Sep-87 115.5 56.8 1.0114 0.6927 0.8775 Oct-87 111.0 59.3 0.9720 0.7232 0.8675 Nov-87 109.2 61.2 0.9562 0.7463 0.8681 Dec-87 109.6 58.1 0.9597 0.7085 0.8542 Jan-88 108.8 54.8 0.9527 0.6683 0.8333 Feb-88 109.0 51.5 0.9545 0.6280 0;8174 Mar-88 109.0 49.7 0.9545 0.6061 0.8082 Apr-88 109.1 53.3 0.9553 0.6500 0.8271 May-88 108.9 54.3 0.9536 0.6622 0.8312 Jun-88 117.2 50.6 1.0263 0.6171 0.8544 Jul-88 118.2 46.9 1.0350 0.5720 0.8405 Aug-88 118.3 46.8 1.0359 0.5707 0.8405 Sep-88 118.5 45.9 1.0377 0.5598 0.8369 Oct-88 114.2 42.3 1.0000 0.5159 0.7967 Nov-88 109.2 47.2 0.9562 0.5756 0.7964 Dec-88 110.5 50.6 0.9676 0.6171 0.8204 Jan-89 112.0 54.9 0.9807 0.6695 0.8500 Feb-89 112.0 54.0 0.9807 0.6585 0.8454 Mar-89 112.3 57.3 0.9834 0.6988 0.8638 Apr-89 112.4 61.5 0.9842 0.7500 0.8859 May-89 113.6 57.5 0.9947 0.7012 0.8715 Jun-89 119.8 53.3 1.0490 0.6500 0.8814 Jul-89 122.2 52.7 1.0701 0.6427 0.8906 Aug-89 122.4 53.5 1.0718 0.6524 0.8957 Sep-89 122.5 59.3 1.0727 0.7232 0.9259 Oct-89 117.2 64.0 1.0263 0.7805 0.9230 Page 1

Development of E Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Energy Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)

REBASED TO 1986 = 100 PPI for Fuels & PPI for Light PPI for Fuels & PPI for Light Energy Escalation Related Products Fuel Oils Related Products Fuel Oils Factor (E)

(1982 = 100) (1982=100) (1986 = 100) (1986=100) for PWR

- (P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils (Diablo Canyon)

Nov-89 113.5 64.4 0.9939 0.7854 0.9063 Dec-89 114.2 68.1 1.0000 0.8305 0.9288 Jan-90 114.9 85.3 1.0061 1.0402 1.0205 Feb-90 115.0 59.4 1.0070 0.7244 0.8883 Mar-90 115.4 60.4 1.0105 0.7366 0.8955 Apr-90 115.1 61.0 1.0079 0.7439 0.8970 May-90 117.0 58.4 1.0245 0.7122 0.8933 Jun-90 123.9 53.0 1.0849 0.6463 0.9007 Jul-90 124.4 51.6 1.0893 0.6293 0.8961 Aug-90 124.6 72.3 1.0911 0.8817 1.0031 Sep-90 125.0 87.3 1.0946 1.0646 1.0820 Oct-90 121.2 104.8 1.0613 1.2780 1.1523 Nov-90 120.2 98.9 1.0525 1.2061 1.1170 Dec-90 118.9 89.3 1.0412 1.0890 1.0613 Jan-91 124.2 82.9 1.0876 1.0110 1.0554 Feb-91 124.3 74.3 1.0884 0.9061 1.0119 Mar-91 124.3 61.6 1.0884 0.7512 0.9468 Apr-91 124.7 60.0 1.0919 0.7317 0.9406 May-91 128.2 59.6 1.1226 0.7268 0.9564 Jun-91 132.6 57.6 1.1611 0.7024 0.9685 Jul-91 134.5 58.1 1.1778 0.7085 0.9807 Aug-91 133.8 62.1 1.1716 0.7573 0.9976 Sep-91 133.8 65.4 1.1716 0.7976 1.0145 Oct-91 128.3 67.6 1.1235 0.8244 0.9979 Nov-91 123.1 71.0 1.0779 0.8659 0.9889 Dec-91 125.1 62.2 1.0954 0.7585 0.9539 Jan-92 125.9 54.4 1.1025 0.6634 0.9181 Feb-92 125.3 57.3 1.0972 0.6988 0.9299 Mar-92 125.8 56.0 1.1016 0.6829 0.9257 Apr-92 124.8 59.0 1.0928 0.7195 0.9360 May-92 128.5 62.1 1.1252 0.7573 0.9707 Jun-92 134.8 65.4 1.1804 0.7976 1.0196 Jul-92 135.6 64.6 1.1874 0.7878 1.0196 Aug-92 135.1 63.3 1.1830 0.7720 1.0104 Sep-92 135.9 65.6 1.1900 0.8000 1.0262 Oct-92 131.2 68.2 1.1489 0.8317 1.0157 Nov-92 125.5 64.2 1.0989 0.7829 0.9662 Dec-92 126.7 59.4 1.1095 0.7244 0.9477 Jan-93 127.1 59.0 1.1130 0.7195 0.9477 Feb-93 126.4 60.4 1.1068 0.7366 0.9513 Mar-93 126.7 63.2 1.1095 0.7707 0.9672 Apr-93 126.8 62.4 1.1103 0.7610 0.9636 May-93 127.5 62.6 1.1165 0.7634 0.9682 Jun-93 136.9 60.8 1.1988 0.7415 1.0067 Jul-93 137.1 57.0 1.2005 0.6951 0.9883 Aug-93 137.2 54.4 1.2014 0.6634 0.9754 Sep-93 137.6 59.3 1.2049 0.7232 1.0026 Oct-93 131.9 65.4 1.1550 0.7976 1.0049 Page 2

Development of E Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Energy Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)

REBASED TO 1986 = 100 PPI for Fuels & PPI for Light PPI for Fuels & PPI for Light Energy Escalation Related Products Fuel Oils Related Products Fuel Oils Factor (E)

(1982 = 100) (1982=100) (1986 = 100) (1986=100) for PWR (P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils (Diablo Canyon)

Nov-93 126.3 61.6 1.1060 0.7512 0.9570 Dec-93 126.0 51.4 1.1033 0.6268 0.9032 Jan-94 126.2 51.5 1.1051 0.6280 0.9047 Feb-94 125.9 57.5 1.1025 0.7012 0.9339 Mar-94 125.8 56.2 1.1016 0.6854 0.9268 Apr-94 125.4 54.7 1.0981 0.6671 0.9171 May-94 126.0 54.7 1.1033 0.6671 '0.9201 Jun-94 133.5 54.1 1.1690 0.6598 0.9551 Jul-94 134.5 56.3 1.1778 0.6866 0.9715 Aug-94 134.5 57.5 1.1778 0.7012 0.9776 Sep-94 134.9 57.7 1.1813 0.7037 0.9807 Oct-94 129.1 57.7 1.1305 0.7037 0.9512 Nov-94 127.0 58.8 1.1121 0.7171 0.9462 Dec-94 127.4 54.7 1.1156 0.6671 0.9272 Jan-95 127.6 54.7 1.1173 0.6671 0.9282 Feb-95 128.0 53.3 1.1208 0.6500 0.9231 Mar-95 128.3 54.3 1.1235 0.6622 0.9297 Apr-95 126.4 57.1 1.1068 0.6963 0.9344 May-95 130.2 59.1 1.1401 0.7207 0.9640 Jun-95 135.3 55.8 1.1848 0.6805 0.9730 Jul-95 136.6 53.5 1.1961 0.6524 0.9678 Aug-95 136.5 55.6 1.1953 0.6780 0.9780 Sep-95 133.7 58.2 1.1708 0.7098 0.9771 Oct-95 131.4 57.8 1.1506 0.7049 0.9634 Nov-95 127.6 59.5 1.1173 0.7256 0.9528 Dec-95 127.7 60.6 1.1182 0.7390 0.9590 Jan-96 127.9 62.6 1.1200 0.7634 0.9702 Feb-96 127.1 59.7 1.1130 0.7280 0.9513 Mar-96 127.8 63.5 1.1191 0.7744 0.9743 Apr-96 129.-1 74.7 1.1305 0.9110 1.0383 May-96 135.0 72.0 1.1821 0.8780 1.0544 Jun-96 137.5 62.8 1.2040 0.7659 1.0200 Jul-96 136.0 64.3 1.1909 0.7841 1.0201 Aug-96 136.2 66.5 1.1926 0.8110 1.0323 Sep-96 136.2 73.4 1.1926 0.8951 1.0677 Oct-96 131.2 79.7 1.1489 0.9720 1.0746 Nov-96 127.1 76.5 1.1130 0.9329 1.0373 Dec-96 . 127.7 76.1 1.1182 0.9280 1.0383 Jan-97 128.3 73.7 1.1235 0.8988 1.0291 Feb-97 128.1 72.3 1.1217 0.8817 1.0209 Mar-97 128.2 65.2 1.1226 0.7951 0.9851 Apr-97 127.3 65.3 1.1147 0.7963 0.9810 May-97 129.7 64.2 1.1357 0.7829 0.9876 Jun-97 135.1 60.8 1.1830 0.7415 0.9976 Jul-97 135.9 57.8 1.1900 0.7049 0.9863 Aug-97 134.7 61.5 1.1795 0.7500 0.9991 Sep-97 136.0 60.4 1.1909 0.7366 1.0001 Oct-97 130.1 64.8 1.1392 0.7902 0.9927 Page 3

Development of E Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Energy Escalation Factor- REFERENCE NUREG-1307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)

REBASED TO 1986 = 100 PPI for Fuels & PPI for Light PPI for Fuels & PPI for Light Energy Escalation

.Related Products Fuel Oils Related Products Fuel Oils Factor (E)

(1982 = 100) (1982=100) (1986 = 100) (1986=100) for PWR (P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils (Diablo Canyon)

Nov-97 127.9 65.8 1.1200 0.8024 0.9866 Dec-97 128.3 59.4 1.1235 0.7244 0.9559 Jan-98 127.4 54.1 1,1156 0.6598 0.9241 Feb-98 127.2 52.0 1.1138 0.6341 0.9124 Mar-98 126.7 48.3 1.1095 0.5890 0.8909 Apr-98 126.4 50.2 1.1068 0.6122 0.8991 May-98 129.2 50.0 1.1313 0.6098 0.9123 Jun-98 133.8 46.3 1.1716 - 0.5646 0.9167 Jul-98 134.8 45.0 1.1804 0.5488 0.9151 Aug-98 135.2 44.0 1.1839 0.5366 0.9120

.Sep-98 135.2 48.3 1.1839 0.5890 0.9340 Oct-98 130.4 47.4 1.1419 0.5780 0.9051 Nov-98 127.6 46.2 1.1173 0.5634 0.8847 Dec-98 126.6 38.8 1.1086 0.4732 0.8417 Jan-99 126.1 40.9 1.1042 0.4988 0.8499 Feb-99 125.5 38.2 1.0989 0.4659 0.8330 Mar-99 125.5 42.8 1.0989 0.5220 0.8566 Apr-99 125.2 52.5 1.0963 0.6402 0.9048 May-99 127.4 52.6 1.1156 0.6415 0.9165 Jun-99 131.0 52.4 1.1471 0.6390 0.9337 Jul-99 133.9 58.7 1.1725 0.7159 0.9807 Aug-99 133.9 63 1.1725 0.7683 1.0027 Sep-99 134.1 67.6 1.1743 0.8244 1.0273 Oct-99 .129.5 65.5 1.1340 0.7988 0.9932 Nov-99 127.5 71.3 1.1165 0.8695 1.0127 Dec-99 126.5 72.9 1.1077 0.8890 1.0159 Jan-00 126.8 75.3 1.1103 0.9183 1.0297 Feb-00 126.7 87.9 1.1095 1.0720 1.0937 Mar-00 126.7 89.7 1.1095 1.0939 1.1029 Apr-00 126.8 83.1 1.1103 1.0134 1.0696 May-00 128.6 82.9 1.1261, 1.0110 1.0777 Jun-00 133.6 86.2 1.1699 1.0512 1.1200 Jul-00 136.2 88.7 1.1926 1.0817 1.1461 Aug-00 137.4 91.6 1.2032 1.1171 1.1670 Sep-00 137.8 110.1 1.2067 1.3427 1.2638 Oct-00 134.1 108.6, 1.1743 1.3244 1.2373 Nov-00 130.9 108.4 1.1462 1.3220 1.2200 Dec-00 132.7 100.6 1.1620 1.2268 1.1892 Jan-01 136.4 96.1 1.1944 1.1720 1.1850 Feb-01 136.4 91.6 1.1944 1.1171 1.1619 Mar-01 136.5 83.1 1.1953 1.0134 1.1189 Apr-01 135.1 86.2 1.1830 1.0512 1.1277 May-01 136.2 94.2 1.1926 1.1488 1.1742 Jun-01 148.4 90.2 1.2995 1.1000 1.2157 Jul-01 149.5 81.3 1.3091 0.9915 1.1757 Aug-01 148.9 83.2 1.3039 1.0146 1.1824 Sep-01 148.2 93 1.2977 1.1341 1.2290 C, Oct-01 143.8 76.8 1.2592 0.9366 1.1237 Page 4

Development of E Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Energy Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)

REBASED TO 1986 = 100 PPI for Fuels & PPI for Light PPI for Fuels & PPI for Light Energy Escalation Related Products Fuel Oils Related Products Fuel Oils Factor (E)

(1982 = 100) (1982=100) (1986 = 100) (1986=100) for PWR (P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils (Diablo Canyon)

Nov-01 137.3 70.5 1.2023 0.8598 1.0584 Dec-01 136.9 56.6 1.1988 0.6902 0.9852 Jan-02 136.3 58.3 1.1935 0.7110 0.9909 Feb-02 135.4 59.6 1.1856 0.7268 0.9929 Mar-02 135.7 69.1 1.1883 0.8427 1.0431 Apr-02 135.4 . 76.4 1.1856 0.9317 1.0790 May-02 137.9 75 1.2075 0.9146 1.0845 Jun-02 143.6 71.4 1.2574 0.8707 1.0950 Jul-02 144.9 75.5 1.2688 0.9207 1.1226 Aug-02 145.0 77.9 1.2697 0.9500 1.1354 Sep-02 145.8 89.5 1.2767 1.0915 1.1989 Oct-02 140.0 95.1 1.2259 1.1598 1.1981 Nov-02 139.5 82.8 1.2215 1.0098 1.1326 Dec-02 139.6 84.6 1.2224 1.0317 1.1423 Jan-03 140.3 95.7 1.2285 1.1671 1.2027 Feb-03 140.6 120.4 1.2312 1.4683 1.3308 Mar-03 143.3 128.9 1.2548 1.5720 1.3880 Apr-03 144.3 98.3 1.2636 1.1988 1.2364 May-03 145.1 85.5 1.2706 1.0427 1.1749 Jun-03 148.3 87.2 1.2986 1.0634 1.1998 Jul-03 151.6 90.1 1.3275 1.0988 1.2314 Aug-03 151.3 94.1 1.3249 1.1476 1.2504 Sep-03 152.0 88.2 1.3310 1.0756 1.2237 Oct-03 147.4 97.8 1.2907 1.1927 1.2495 Nov-03 142.7 93.0 1.2496 1.1341 1.2011 Dec-03 142.9 95.8 1.2513 1.1683 1.2164 Jan-04 143.1 106.8 1.2531 1.3024 1.2738 Feb-04 143.1 100.8 1.2531 1.2293 1.2431 Mar-04 143.1 107.8 1.2531 1.3146 1.2789 Apr-04 143.1 115.2 1.2531 1.4049 1.3168 May-04 144.2 116 1.2627 1.4146 1.3265 Jun-04 152.4 111.5 1.3345 1.3598 1.3451 Jul-04 152.2 119.3 1.3327 1.4549 1.3840 Aug-04 154.0 131.1 1.3485 1.5988 1.4536 Sep-04 154.0 136.8 1.3485 1.6683 1.4828 Oct-04 145.8 161.7 1.2767 1.9720 1.5687 Nov-04 144.9 153.6 1.2688 1.8732 1.5227 Dec-04 146.2 133.8 1.2802 1.6317 1.4278 Jan-g5 148.9 138.5 1.3039 1.6890 1.4656 Feb-05 148.0 146 1.2960 1.7805 1.4995 Mar-05 148.1 169.4 1.2968 2.0659 1.6198 Apr-05 148.7 170.9 1.3021 2.0841 1.6306 May-05 151.1 165.3 1.3231 2.0159 1.6141 Jun-05 159.7 180.6 1.3984 2.2024 1.7361 Jul-05 162.1 186.2 1.4194 2.2707 1.7770 Aug-05 162.5 194.5 1.4229 2.3720 1.8215 Sep-05 162.8 209.9 1.4256 2.5598 1.9019 Oct-05 159.5 252.0 1.3967 3.0732 2.1008 Page 5

Development of E Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Energy Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)

REBASED TO 1986 = 100 PPI for Fuels & PPI for Light PPI for Fuels & PPI for Light Energy Escalation Related Products Fuel Oils Related Products Fuel Oils Factor (E)

(1982 = 100) (1982=100) (1986 = 100) (1986=100) for PWR (P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils (Diablo Canyon)

Nov-05 161.1 1991 1.4107 2.4280 1.8380 Dec-05 161.4 193.6 1.4133 2.3610 1.8113 Jan-06 167.0 191.8 1.4623 2.3390 1.8306 Feb-06 168.6 190.0 1.4764 2.3171 1.8295 Mar-06 167.4 199.2 1.4658 2.4293 1.8705 Apr-06 169.6 221.9 1.4851 2.7061 1.9979 May-06 170.8 231.4 1.4956 2.8220 2.0527 Jun-06 181.2 238.1 1.5867 2.9037 2.1398 Jul-06 181.9 231.6 1.5928 2.8244 2.1101 Aug-06 180.2 241.4 1.5779 2.9439 2.1516 Sep-06 181.0 203.1 1.5849 2.4768 1.9595 Oct-06 171.2 198.1 1.4991 2.4159 1.8842 Nov-06 167.2 198.2 1.4641 2.4171 1.8643 Dec-06 167.8 200.4 1.4694 2.4439 1.8787 Jan-07 171.9 180.0 1.5053 2.1951 1.7950 Feb-07 175.7 191.5 1.5385 2.3354 1.8732 Mar-07 172.1 215.1 1.5070 2.6232 1.9758 Apr-07 173.1 231.8 1.5158 2.8268 2.0664 May-07 179.2 225.3 1.5692 2.7476 2.0641 Jun-07 186.7 222.4 1.6349 2.7122 2.0873 Jul-07 187.0 237.8 1.6375 2.9000 2.1677 Aug-07 187.6 225.5 1.6427 2.7500 2.1078 Sep-07 188.4 238.9 1.6497 2.9134 2.1805 Oct-07 182.7 243.3 1.5998 2.9671 2.1741 Nov-07 180.3 288.2 1.5788 3.5146 2.3919 Dec-07 180.0 266.7 1.5762 3.2524 2.2802 Jan-08 181.9 273.8 1.5928 3.3390 2.3262 Feb-08 180.0 280.2 1.5762 3.4171 2.3494 Mar-08 183.1 339.6 1.6033 4.1415 2.6693 Apr-08 185.2 352.5 1.6217 4.2988 2.7461 May-08 189.5 384.9 1.6594 4.6939 2.9339 Jun-08 191.9 410.5 1.6804 5.0061 3.0772 Jul-08 196.1 423.8 1.7172 5.1683 3.1666 Aug-08 197.1 343.9 1.7259 4.1939 2.7625 Sep-08 195.9 335.1 1.7154 - 4.0866 2.7113 Oct-08 191.6 282.4 1.6778 3.4439 2.4195 Nov-08 189.4 220.2 1.6585 2.6854 2.0898 Dec-08 190.6 165.5 1.6690 2.0183 1.8157 Jan-09 188.9 161.0 1.6541 1.9634 1.7840 Oct 08 through Jan 09 are Preliminary Values from PPI Indices Page 6

Development of L Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor- REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)

Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)

Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.

Employment Cost Indust West Region Labor Private Industry Escalation (1989=100) Factor Jan-86 89.8 1.00000 Feb-86 Mar-86 Apr-86 90.8 1.01114 May-86 Jun-86 Jul-86 91.2 1.01559 Aug-86 Sep-86 Oct-86 91.6 1.02004 Nov-86 Dec-86 Jan-87 92.5 1.03007 Feb-87 Mar-87 Apr-87 92.6 1.03118 May-87 Jun-87 Jul-87 93.7 1.04343 Aug-87 Sep-87 Oct-87 94.1 1.04788 Nov-87 Dec-87 Jan-88 95.4 1.06236 Feb-88 Mar-88 Apr-88 96.3 1.07238 May-88 Jun-88 Jul-88 97 1.08018 Aug-88 Sep-88 Oct-88 97.7 1.08797 Nov-88 Dec-88 Jan-89 98.8 1.10022 Feb-89 Mar-89 Apr-89 100 1.11359 May-89 Jun-89 Jul-89 101 1.12472 Aug-89 Page 1

Development of L Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CLU20100000002401 (as of 03/06/09)

Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)

Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.

Employment Cost Indust West Region Labor Private Industry Escalation (1989=100) Factor Sep-89 Oct-89 101.8 1.13363 Nov-89 Dec-89 Jan-90 103.3 1.15033 Feb-90 Mar-90 Apr-90 104.5 1.16370 May-90 Jun-90 Jul-90 105.6 1.17595 Aug-90 Sep-90 Oct-90 106.3 1.18374 Nov-90 Dec-90 Jan-91 107.5 1.19710 Feb-91 Mar-91 Apr-91 108.9 1.21269 May-91 Jun-91 Jul-91 110 1.22494.

Aug-91 Sep-91 Oct-91 110.9 1.23497 Nov-91 Dec-91 Jan-92 111.9 1.24610 Feb-92 Mar-92 Apr-92 112.9 1.25724 May-92 Jun-92 Jul-92 114.1 1.27060 Aug-92 Sep-92 Oct-92 114.9 1.27951 Nov-92 Dec-92 Jan-93 116.2 1.29399 Feb-93 Mar-93 Apr-93 116.4 1.29621 Page 2

Development of L Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)

Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)

Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.

Employment Cost Indust West Region Labor Private Industry Escalation (1989=1 00) Factor May-93 Jun-93 Jul-93 117.8 1.31180 Aug-93 Sep-93 Oct-93 118.1 1.31514 Nov-93 Dec-93 Jan-94 119.4 1.32962 Feb-94 Mar-94 Apr-94 120.5 1.34187 May-94 Jun-94 Jul-94 121.3 1.35078 Aug-94 Sep-94 Oct-94 121.7 1.35523 Nov-94 Dec-94 Jan-95 122.6 1.36526 Feb-95 Mar-95 Apr-95 123.4 1.37416 May-95 Jun-95 Jul-95 123:9 1.37973 Aug-95 Sep-95 Oct-95 125 1.39198 Nov-95 Dec-95 Jan-96 125.9 1.40200 Feb-96 Mar-96 Apr-96 127.3 1.41759 May-96 Jun-96 Jul-96 128.3 1.42873 Aug-96 Sep-96 Oct-96 128.9 1.43541 Nov-96 Dec-96 Page 3

Development of L Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor- REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)

Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)

Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.

Employment Cost Indust West Region Labor Private Industry Escalation (1989=100) Factor Jan-97 130.3 1.45100 Feb-97 Mar-97 Apr-97 131.4 1.46325 May-97 Jun-97 Jul-97 132.5 1.47550 Aug-97 Sep-97 Oct-97 133.4 1.48552 Nov-97 Dec-97 Jan-98 135.2 1.50557 Feb-98 Mar-98 Apr-98 136.6 1.52116 May-98 Jun-98 Jul-98 138.5 1.54232 Aug-98 Sep-98 Oct-98 140 1.55902 Nov-98 Dec-98 Jan-99 140.3 1.56236 Feb-99 Mar-99 Apr-99 142.1 1.58241 May-99 Jun-99 Jul-99 143.3 1.59577 Aug-99 Sep-99 Oct-99 144.7 1.61136 Nov-99 Dec-99 Jan-00 147 1.63697 Feb-00 Mar-00 Apr-00 148.8 1.65702 May-00 Jun-00 Jul-00 150.8 1.67929 Aug-00 Page 4

Development of L Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)

Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)

Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.

Employment Cost Indust West Region Labor Private Industry Escalation (1989=100) Factor Sep-00 Oct-00 151.8 1.69042 Nov-00 Dec-00 Jan-01 154.3 1.71826 Feb-01 Mar-01 Apr-01 156 1.73719 May-01 Jun-01 Jul-01 157.6 1.75501 Aug-01 Sep-01 Oct-01 159.4 1.77506 Nov-01 Dec-01 Jan-02 160.4 1.78619 Feb-02 Feb-02 Mar-02 Apr-02 162.9 1.81403 May-02 Jun-02 Jul-02 163.8 1.82405 Aug-02 Sep-02 Oct-02 165 1.83742 Nov-02 Dec-02 Jan-03 167.3 1.86303 Feb-03 Mar-03 Apr-03 169.5 1.88753 May-03 Jun-03 Jul-03 171.4 1.90869 Aug-03 Sep-03 Oct-03 172.2 1.91759 Nov-03 Dec-03 Jan-04 175.3 1.95212 Feb-04 Mar-04 Page 5

Development of L Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)

Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)

Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.

Employment Cost Indust West Region Labor Private Industry Escalation (1989=100) Factor Apr-04 176.8 1.96882 May-04 Jun-04 Jul-04 178.1 1.98330 Aug-04 Sep-04 Oct-04 179.0 1.99332 Nov-04 Dec-04 Jan-05 181.4 2.02004 Feb-05 Mar-05 Apr-05 183.3 2.04120 May-05 Jun-05 Jul-05 184 2.04900 Aug-05 Sep-05 Oct-05 (Note 1) 100 2.06000 Nov-05 Dec-05 Jan-06 100.6 2.07236 Feb-06 Mar-06 Apr-06 101.8 2.09708 May-06 Jun-06 Jul-06 102.5 2.11150 Aug-06 Sep-06 Oct-06 103 2.12180 Nov-06 Dec-06 Jan-07 104.2 2.14652 Feb-07 Mar-07 Apr-07 104.9 2.16094 May-07 Jun-07 Jul-07 105.7 2.17742 Aug-07 Sep-07 Oct-07 106.5 2.19390 Nov-07 Page 6

Development of L Component Enclosure 2 PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor- REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)

Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)

Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.

Employment Cost Indust West Region Labor Private Industry Escalation (1989=100) Factor Dec-07 Jan-08 107.8 2.22068 Feb-08 Mar-08 Apr-08 .108.4 2.23304 May-08 Jun-08 Jul-08 109.3 2.25158 Aug-08 Sep-08 Oct-08 109.4 2.25364 Nov-08 Dec-08 Jan-09 109.5 2.25570 Jan-07 is an estimate based on the difference between Jul-06 and Oct-06 added to Oct-06 Page 7

Development of B Component Enclosure 2 PG&E Letter DCL-09-021 Development of Burial Escalation Developed from NUREG-1307 Revision 13 Table 2.1 "VALUES OF B SUB-X AS A FUNCTION OF LLW BURIAL SITE, WASTE VENDOR, AND YEAR" (Summary for non-Atlantic Compact)

Revised to Bx Values for Generic LLW Disposal Site (Assumed to be same as that provided for the Atlantic Compact for lack of a better alternative at this time.

PWR PWR Burial Costs Restated to (South Carolina) 1986 = 100 1986 1.678 1.0000 1987 1988 2.007 1.1961 1989 1990 1991 2.494 1.4863 1992 1993 11.408 6.7986 1994 11.873 7.0757 1995 12.824 7.6424 1996 12.771 7.6108 1997 15.852 9.4470 1998 15.886 9.4672 1999 0.0000 2000 18.129 10.8039 2001 0.0000 2002 18.732 11.1633 2003 19.034 11.3430 2004 21.937 13.0733 2005 22.477 13.3951 2006 23.030 13.7247 2007 23.597 14.0626 2008 25.231 15.0364 2009 26.332 15.6922 Table 2.1 Note ('c) From 7/1/95 through 6/30/2000 access was allowed for all states except North Carolina. Effective 7/1/2000 rates are based on whether a waste generator is or is not a member of the Atlantic Compact.

2001 has no information in NUREG-1307 Rev 12. 2001 is an estimate that is calculated by applying the average % change between 2000 and 2002 and adding to the 2000 base 2003 has no information in NUREG-1307 Rev 12. 2003 is an estimate that is calculated by applying the average % change between 2002 and 2004 and adding to the 2002 base 2005 has no information in NUREG-1307 Rev 12. 2005 is an estimate that is calculated by applying the average % change between 2004 and 2006 and adding to the 2004 base.

2007 has no information in NUREG-1307 Rev 12. 2007 is an estimate that is calculated by applying the average.% change between 2004 and 2006 and adding to the 2006 base.

2009 has no information in NUREG-1 307 Rev 13. 2009 is an estimate that is calculated by applying the average % change between 2006 and 2008 and adding to the 2008 base.

Page 1

Eýnosure3 NOTE: Toatls oay notsout de torounding PG&E LetterDCL-09m-oo TABLE C-2 TABLEC-2 DIABLOCANYONPOWERPLANTUNIT2 DIABLOCANYONPOWERPLANTUNITI DECONDECOKM0ISSIONING COSTESTIMATE DECONDECO]THISSIONINGCOSTESTIMATE fTlouo.ode of eolff)

D000 (Thooanod. of 20M0 Dt1oa-)

Off-Site LoRjw . -: Off-Site LLRW a Tr...or Prui Disosl Other Cortin~0 Totl -Dte

' CleFnR'oe

" eA P-cteoetoe Tr-aosport Psooceete. I-tspoet] Other- Coonttnoen Torel PEROtD Ela-Shlootootl TrasZle211112't Periodla Siredt Secormlsslonino Aebrto 1o.t.1 Preoar erelimlnary decommsioninocost 1 55 8 63 0 64 22 86 ta.t 2 Notiation of Cessaoonof Operetione le.. 3 Remoefunte rce

... meaerial 1e1.4 N oalion ot Parterranentefuelnin-te.t.5 Deactivate otantsosfer &oroesasott-e w w 98 34 132 tat.l Preoareend u.mittP-OAR 4 2 9e150 225 79 308 la.1.7 Reew olant oos & secs.

Ia.t.8 Performdetailedrd surve

'49 17 66 ta.1.9 Estimate c-oroduct Inventorv 210 3 a2*2 49 17 66 oar1.10 Endorodutdescription 24O2 22 8l 42 6 64 a, Detailed!b-orodoo Inventoro - 55 a 6 367 12m 496 1a.1.12 Definerarorwortoeeoueroo 316 47 343 151 53 204 let112 Perfo- SERandEA eIa.14 PerforrnSite-So*edriCostStudy 27130 210 20 32 t15 242 0:,X3/4 2244 85 329 r

la.1.15 ProJseubItLUcense TemnrutoonPlan 200 70 270 17f 26 1at,1,, Receie NRCaeoeroaloflenetmireo Plan 198 AioilltySNeeifieations 241 84 325 fat.17.t Plant&temeoreno faides 203 71 274 fa,.t17.2 Plantsvesterr 175 26 -02 24 9 33 7.3 NSSSDSaontrnlnaoton

,1.a1, Fluos 21 3 2,742 347 12. 469 ta 1.17.4 Reacorintemaso 99 9t45 317 111. 428 Ia.1.17.5 Rea7to Fi eoss - M7 273 31 41 31m9 '

24 9 33

,e..17.6 liotliooalslield 2,455 re.t.17.7 Steamoeratom ea.f,7.8 Reinforced corcrete 2,142 130 3J7 20 15t -0> 000 m 152 78 53 27 205 1OS o,0 0 - 20 7 27 la.1.17.9 MainToobN - 7 3 091-07 20 7 27 fea1.17.10 MainCondenners 3 07 2D5 151t 152 53 la.1.17.11 Plan'trstreS

" & dldinos es - 13 20 te.1.07.12 Wastemna nrerrt - - 225 79 3044 S 9`1 29 2 - - 44 15 O0 to.t.17.13F1eilit&sRoe closertd 38

- 59l 6 1.849 647 2,496 ta.1.17 Totol 235 l83.705 Plannn o & Site Prewaratoes 117 41 158 Oa.10 Oa.59 to 1O PreoarediSmantlineoserooeno Planterep.

sDIosn

& teme. svcs

-aterclear,-u scostem O

2,14101 15 363 11t -

2.782 0 0 u - 4

~ 0 t 0

-~ 2..811 69 984 24 3.794 93 5" o 2.380 833 3.212 at.121 RiooclnaContCntd Eo.d.osernoleto. - 2,048 3.7 2.35514 lO0 jT(0>0

-6 21 82 toa1. 2 Prure -Wsioolners & otainers 6 52 0 w1 8,7N4 3.078 11.872 fa., SubtotalPeriodfo Amct Costs -7,59 1t135 81705 Pedod toAdditiotoCosts 1:.2.1 1a.2 SoentFuelPooltilation SubtotalPeriodla ActotvCoste

- 5225 5.225 784 704

60. 0 09 WADS~ 0

>> A$g* 6.071

-6.071 2.125 2.125 8,106 8.196 Perod la Pertod-DeeoenetCots

- 0.644 1,779 623 2,401 1::44:1 In -~ac 1.S3t 13 102 36 138 ta,2 Prooeroretes 88 9 970 §*:1tt 333 450 287 - 117 Ia.4o3 Heathohrdsossuolles 445 601 156 a,.44 Heame-io*nent rental 383 6 33 - 48 187 1a.45 DSslosalofDAWoeneartd -5 2 164 - 42 2f54[ W5 1.127 394 1.522 ae4d6 Planteenoubodot 145 - 145 1a.4.7 NRCISFSIFees 125 125 l..4 8 NRCFee 10 I306 416 265 27 m 1.097 110 1,26 - 1.25 446 1.721 la.4.9 Emeroenoo Plaoios Fe 352 W 1.325 1.0t a.4.t0 SenorFoalPoolO&M 12 193 1 145 51 196 la.4.11 f SFS1ODeoanoCosts 1,.4.12 l!5() 37 217 . , 290 102 3m0 ISFSlFxe'dCOT 2.634 922 3.556 la.4.13 Scuoto StaffCosl 2,267 340 2 6D707[ 32,450 24.M37 8. 413 1,.4.14 UtiNity SteffCoot 104 20600 2.268 3.103 4.244 237oo 33.354 es 000 o j 4 778 6 3 130 32.845 11f817 45.578 1a.4 Suioteta 1a.4 Perlod-Seveodent Costs E70 5 2 70 5 2 164 41.063 6.163 48.068 , 35 778 6 3 130 47.711 17.020 65,648 1a.0 TOTAL PERIODta COST Period1bDirectDeoommlssaionb ActSMis DetailedWookProeedUres

- 231 81 312 51.1t.1 Poantvstems 1b.1.I.2 NSSSDecontamination Flush 42 6 Q 49 17 (66 405 16 121 471 165 635 b t.t.3 Reactoriternoals w6 23 89 Ib,1,1,4 Rmonaenis buildinds 57 109 472 6 48f w54 192 740 tbtt.1,S CRDcoooinaasoemlbo lbi ,1,6 CRD)houinqs & ICltubes 49 17 66 tt1.t7 Cncore on ostmmntooaon 42 6 48 42 S Q8 49 17 66 178 62 240 I 1.t.8 Reomoroossol 153 23 76 58 2m 78 1b.1.f9 Fac61ty Oloeout 19 3 22 22 8 30 Sb.1.1.0 Missoe helds 58" 20 78 lb.1.1.11 Bft8o1cal sheld 194 29 2 225 79 304 lb.1.1.12Steameatooo 49 17 -66 1bA.,113 Reinforced conorete 42 0 48 77 27 104 lb.1.1.14 MalnTurbine Si 10 75 1b.1,.115 MainCof'Klrse 66 10 75* 77 27 104

NOTE:Toto mS y notsone dueto rounding Ese 3 P59E Leter DCL.9-Wo TABLEC-2 TABLEC-2 DIABLOCANYON POWERPLANTUNIT2 DIABLOCANYONPOWERPLANTUNIT 2 DECONDECOMMISSIONING COST ESTIMATE DECONDECOMMISSIONING COST ESTIMATE (Th.o.ad. of 2004Doll.a.) (Thoouod. of 2009 Dotter.)

IDRot)ct DOf-Site ILEW . - Off-Sot. bIsw Nootn Atot 0D ito Do Reoone Pocketing T-aosport P*ooe..lg Disposal Other Cotiogency Total A CF BCP CC TCC D-e Reron.e Poklott Tronoport Poroasieg Disposol Ott-r Contilogency Tote) 1b"A.I Auii 132 -ulin *

• 34 47 w8 lbt1.1.1 Autliarobuildino bflOima 1tS t7 132 t . . -. -- --. 134 47 tO 1b.1. Tote)al - - 1 i39i - 2t0 1~ 608 - - ~ -t --- 1.624 565 2.193 101.2 09000orio935tWD 1,339 670 2.0919 t - 556 1.0 545 2.t02 10.1 SutootolPe.o I.btActb Costs 1.339 1.398 879 3,67 1.55- 1.624 1.11t3 42 Pe dodb Additionat Co*l.4 tboi SitCharaotd foern - 936 281 1.216 - -

".---1.088 t 1,468 tO.2.2 Coltetooooain loroi-tortndacTeotdooo 353 - ---- 53 405, - 410-----t454 10,2.3 Htordots WestaManoatnt - 577 87 163 - - - -,-670 235 905 tb.Z4 Mbetd Wase Manaooenent - 577 87 663 - 670 235 166 1b.2 SulbotalPereod lb A1 Costs 353 2.099 W07 2.990 - 410 2427 993 3.130 Period1t ColteraI Cogts 3-1 bb, Deo eaui, en 816 o - 123 M39 . 0 < w - - 532 31.26 10.22 DOCsta relocation e99etos -

- - 1.961 153 174 [ .  : "  :

652 WE 5,890 1.186 415 2618 162 10,097 10b33 Proces liouidwste 59 501 6099 4.103 - 3.452 7.21 - 93 - 0 1005 2 0 1b.3.4 Soall toalowance 4 1<1 .

.- j - 31.112 P.e outino eouIoowt 186 0 430 1.444 3B9 15..o 1b.35 10,3.6 Deco06 1.243 * - 595 1W 10b3 SubtotalPeold 00,ColeatarCosts 2.118 961 561 605 5.103 1.021 2.99 t2.427 - 731 24t 1.117 652 869 7.32 13186 4.764 8:3674 Pasted00 Perod-DeoendentCosts 104.1 Deoen -U01im -- o - - 6 311 291 -O0 10 39 718 77 9441. 0 - 892 .- 312 1.20x 10.4.2 1r61703c0 10.4.3 Proertvtaoes 0150. '18 69 1b.4.4 Heath ohsicssuoples 214 -- - - - 54 2W249 87 336

- 0- 76 301 1b.45 Hea- eauiomente ental 192 29 2212 1b046 Dooosolof DAW oreratod 3 69 8 - 23 110 1. . 3 70 - 26 102 1b.47 Pont energybudoot - - - 972 146 1.119) 1.129 395 1.525 1b.4 a NRCISFSIFee 73 26 99 1b.49 NRCFees 1w 13 141[3 0 155 54 .2(9 1b.4.)0 Errteron PlanninaFees * - - 56 55 1 639 234 2 63 1b.4,t Soent FuelPoolO&M 1b.4.12 ISFSIOoetino C.st 0b.4.13ISFSIFed Cost 125 19 14- 504 73 145 176 6

t 681 99 96 1b.4.14 Se"urty StaffC09 1.136 17 W7 1.320 A4629Th. 1.782 Ib14.15 DOCStafIC09 -- - - 3.157 4704 361331 006680 2 ' 1299 4,952 10.371 1.15 .9270 12.00 42183 16,29 lb.4.16 U06 Sotal Co0t 99 17.916 2.702 21.0401 29 472 3 0 128 20.700 7.467 28.801 0b.4 Subtota Perieod Ib Perod-DeondentCosts 25 406 1b.0 TOTALPERIOD tOCOST 39493. 1.719 564 66 9.192 22.325 6,144 40.033 IO 573T1 4047 1.997 655 870 0 7396 25.939 14.317 55.222 PERIOD 1 TOTALS 3.403 2.389 5W9 6RIS 9.356 63,388 11.307 88.101 563 5.7301 4047 2.776 661 874 7.526 7361 31337 120.872 PERIOD 2a - Larse CeetooauooRennreal Period I DOuect DeOonorssioeieo Actbtaes 25 w9 1.377 - 532 323M 2132925 Nucler Ste-m S-ooI, SvoltMReeo1a 2a.1.11 Rates CoolantPinna 247 222 29 55 0 1.35 0 695 2.W1 4 Z9 S' 322 329 .. 30 V 5 9 183 S9. 342 29.1.12 Pre-ssszerQuenohTank 26 23 2a.1.1.3 ReactorCoolntPuos= &Motos 97 79 43 41 119 4.301 1.172 59W21 5 .(M) 113 92 50 50 171 4.72 0 1.624 7036 2a.1.1.4 Pressurtzer 32 41 423 61 - 567 M2 1353 1902 3W 493 as 0 293 - 33W 13 .3 2a..t.S I, Sitm ooerators 3.36 3.152 3.236 606 2.23 6.495 112 3263 136544 31162 2.598 3.27 4.190 1 5324. 20.536 2e.1.1.6 RebredSteamGeneratonUnts 1.824 659 2.255 6.495 112 2266 13604, 17.342- 2.119 946 3.237 4.307 130 3.759 14.498 2o.1.1.7 CRfIs/CIslSenlole StructureRerooal 74 5a 101 32 267 - 133 6 2. 8 117 49 1.014 0 466 1799 2a.1.1.6 ReactoVassal lnternats 1909 1.917 4.578 636 6.029 194 5640 19 1,502', 845 574 1 127 2.267 5.319 913 0 .221 225 59.91 23994 2a.1.19 Reotot Ve*soo 81 3.631 I 1290 474 - .540 194 7.506 213724 6419 2379 - "9 4,219 1.508 68W - Z0.40 225 5W 23M13 2a.1.1 Totals 1.SO3 9.131 01532 2,613 4.657 34.260 612 20,995 83.9101 55.092 3234 0 574 ,165 .6069 12.237 32751 6.6w 33.252 711 23.944 . .92,356 R oval of MaiorEausoient 2a 1.2 MWnTurbine/Genetetor 420 213 6w 7589 1.1 527 301-1 2443 -498 247 86 1.W W8 0 979M 3777 2a.1.3 MainCondensers 1.199 1905 64 IRI WE - M62 3.4Q21 1.973 1 1.Z33 122 92 869 702 , .- 1.112 4.289 CascadinoCosts born Clean BuildinaDSentoboo 0 yt 1.244 O0 . 0439 IWE8 2o1.4.1 Reacto, 1.071 161 1.2323 6 0 2e.1.4.2 AUoxdltv 60 92 - 244 943 608 S21 82 2351.43 Containteont PenenratoAras 76 2a1.44 RattassteStaseo 65 10 75; 0 26 102 23.1.4.5 FuelHandltno 149 21 1611 0 163 57 20 1,929 299 2.2019[ 784 3,026 2a.1.4 Totals -2.241 Dispees oelPlentSvote 29.1.5.1 Au9*41aStiam 2a.1.5.2 Aoiav Stae- (RCA) 100

,3 12 6

188 as 55 35 3

2161 9 0 0 0 116 3 17 9

N70 126

• 142 82 549 317 S4 . -2 6 231 5.3 Buikdjin Seias (No-Po.r BlOck) 302 741 51 i 2e51.5.4 Coardem.ae SWs-ee -49 22D 3.349 57 316 4.W8 .2,139 .. 252 23515.5 Cotdoeranue sostoe msubted) 303 73 1.199 352 19 105 1.591 723zi 2.789 2511 7 19 - 0 2a.1.5.6 CorntonerotSor* 142 U4 514 9 99 738 336 1.297 2e31.5.7 E StbonmSteam

& H-aDer.rio 3M3 12 55 642 232 1.42 0 0 14 79 1.29 579 2.233 23.1.5.8 FPerdotenSosteot 73 10 45 6W7 129 943 ., 99 12 65 986 402 1.549

Erlosute 3 NOTE:Totalsmaynotsumdueto rouning PG&E LttterDCLt-Sm TABLEC-2 TABLE C-2 DIABLOCANYON POWER PLANTUNIT2 DIABLOCANYONPOWER PLANTUNIT 2 DECONDECOMMISSIONING COST ESTIMATE DECONDECOMMISSIONING COST ESTIMIATE Ilthoooaaada of 2004D.11a) (Thtoosada of 2009Dollal)

ID . .. **Borial site"a "

Off-SlIe LLRW -" - I Off-SlIe LLRW Re-moo P.ekatdng Traspeort - P)oaesiag Dlsposot Othar Cootioeory Totat I Ap C.B (lt "i0 ,CFOýTCCI Dao -umber RIIoo~ Paokhaeoe Tasorat aioe Peooiag ispostl Other Cottingenoy Total Nober At Desotatin De-n 2a,. 5.9 FeeoooaterSystemfrtsutatad) 106 9 41 - - -16 1211 .... 67 M8 147 42 273M. - 84 2 14 211 1096 1 420 2a.t.5.rO FeottosterSstem (RCAlrcaatedl 72 2 10

. I 5 - 2 14 - - 3 6" 22 2a,1.5,11 FeatetoorSostem(RCA) 9 64 se 2M 2a1.5.12 NSSSSamolinSystem 2 3 7 w 46 2 t 115 2 4 55 29 14 2a: 15.13 NSSSSami*io Soste W Insulated) 9 10 491 13 M15 5 20 2a.t.5,14 Nircea &Hodrtoen - / - - .1 2at.5.15 Nitro & HrodentIIlts ed)

"3 2 7 2t.S.56 Nirrooen&Hodroaen(RCAItnulated) 3 2 25 2O 0 10!1/2> 73 S 3 35 39 151 Hoderoten (RCAi 63 2a1.5.17 IrON 3 45 24 92 21 18 - 2 --31 2a.1.5.18 OI,WaterSearator & I Sump 10

- - 15 162 1381 - - 40 100 2a.1.5.19 S aitmater System - 1.116 413 6.288 2,763 10.658 74 2a.1.S.20 TorbinrSteam Suoolo - 020 64 285 4.380 -47 9 6 2642 615 21 111 1.6M3 50 3,279 2a.1.5.21 TutnoneSteam Suotly(RCA) 77 1.172 321 2.1171 62 412, 108 3 23 342 w 167 643 2a.t.5,22 ad Gaerator Turbaine 3 16 238 634 1 4 63 - 3 - .146 2a.1t5,23 Turbineatd aenerart tnosuloated 1 3 44 -1 97 7 2, 04 12,829 87 3.057 20O 0'%tI 4.560 - 223 1.215 18.417 72 5.584 S3t10 2a1.S Totas 102 915 4.6341 76 4.124 19 1t1 I5 27 - 1.519 5.859 2a.1.6 SaffotodfoInsutto.. o. decommissionorr 3.549 16 8 111 34 -

612 118.212[ 059793 1;5 1.165 23.454 12.848 5.157 27.219 34.034 711 36.621 142.410 2a.o SubtotalPeriod2NActrt" Costs 1.003 20116 11.058 3.592 1896) 36.385 2641 274 Period2aCotueralCoas - - 1.572 - 550 2.122 2,2.1 Cure Surchama 944 16 447 1.725 91 1.064 14 645 2 0- 2' '<: 106 144 63 2a22 OldRPV Held 124 44 2a 2 SubtbtoPeriod2S Addiloatal Costs 91 124 44 2.160 14 919 3.351 1 20- 106 144 63 2.529 16 998 3.849 Period a CCollateral 13007 1.182 40 123 619 23.3.1 . Pmoessliku:Aoste 34 05 431 164 7069G-~.-'

295 - 163 398 2.3.2 Smalltool e*ae 254 34 as 431 M22 1.052 123 619 - 410 t.581 94 295 40 2a.3 SubleoaPeriod2a ColateralCosts Period2a Petlod-DOeendent CRots - 31 119

- 19 95!,

2N41 DSeonsuoooe 1.106 387 1,493 N.4.2 Insurance.. 952 65 1.053 156 54 210 2a.43 Proocrtotoots 134 13 147 ,. o i 1.886 660 2546 N.4 4 Healfthehnsas su.oties 1.623 2.996 _ .

• 2449 3,*4 3.401 1.218 4.699 2N.45 HScwesuitmentrentol 74 33 2.241 - 572 2.920 86 47 1.TT7 - 668 2.578 2.4 6 Dlsoosotot DAWaenerled 1.628 070 2.198 2a.4.7 Plt enem budoaet - 1.401 210 1,6111 <

190 - 12w 221 - 221 2a408 2a.4.9 NRCISFSIPes NRCFees ,,

4%8 50 548w 579 203 781 06 13 1.308 2a041 0 EmemeenePlannonFPes 834 83 917.1 1.529 535 2.004 2a.4.11 Stont FuelPoolO&M 1.316 197 1.5141 221 77 290 2a:412 ISFSIOooratta Costs 442 155 596 3WO 57 437 2a.4.13 ISFS1 FxedCoats 4.996 1.74 6.745 2ao 44 Surllv StaffCost 4.30 645 4945 8.983 6,644 25.627 2a.4.15 DOCStaffCoat 10.338 2`151 18.789

.200 275 1100 121 00190 28,94 3710 4.341 21os 33.2113 673 3I~'~50 3.628 11.775 45.397 2..4.16 UtId" StaffCoalt. 74 '32.241 55,474 9.618 72.135 407 47 - 1.T7 25,137 06.007 4.619 88 5,3.7 4.455 2N.4 SubtotolPeriod 2a Peiod-DeaeardertCoats 76

.290 3.755 18.950 41.216 56.100 37.156 194,786 66ý 37 1.348 :20.222 13.118 5.301 27.219 3M.0115 2a.0 TOTAL PERIOD 2a COSTS 1.160 25,150 11 5.183 63.465 244.795 PERIODNb- Site DecSlortstrniot Period2b DireatDecoma nioe ASbrias DOoosalofPnt Systems 258 994 2b.1.1.1 CatltalAdditions i6-202ideal - - - 955 730 M77 24 307 269 1.03 '

2bS1.1.2 CaotalAddoats 85-2002lcortamltatedt 297 - 6 17 214 154 135 773 2- 345 7 65 2-.0r 624 735 3w 63 43`4 7M2 909 3.505 21,.1.3 SVolume Cherr..oto Cotro 537 633 33 44 3(2 894 705 3147 220 282 12 13 42 219 275 1.002 20.1.4 Chemiool S

&Vomo Coa tlr eda t89 243 10 9 20 294 228 9710 5 -

124 --- - 11 014°' so 195 2A.1.15 CortrCoot Waer o5o 1.930 357 415 12 62 942 20.1.1. Com nertaCoolto Water SCAI - 377 31 121 2b.1.1.7 ComersseadAir - 5 2 6

2. l1.8 Corressad At onrItfted 4 - 1 9 1<

20.11.S Conmeotssod AlsrCA Irutataedl S 17 2 tO 1o 156 159 106 1605 26 SI*

1 593 14 228 215 026 2b.1.l.10 Comotessoed AlrlRCA 317 368 30 116 2M.1..111DieselEroi.o-erttor 3 1

2b.1.1.12 DieselEtmian-Geterae tlnsulatedt - 742 200 20 2.056 236 836 3.225 201.1.13 Electrou IClenIt - 30- 2.16 19 261 25 196 755 2bt.114 Elec"l' ICtCooomltat en 216 3 13 182 30 91 31 92 3

581 35919 1 1,521 149 2.258 1 305 5.341 21,.1.15 Elatrial (RCAl 1.309 24 104 1,573 - 2,39 397 1.531 2b.1.1.16 FireProteotion 229 8 37 561 - - 148 983( . - 260 79 3 6 45 61 <1 236 i 11 7 65 50 76 293 20b.1.17 Gaseos Radoaste S 20 28 25 10 39 21,.,1.18 HVACClean _InWlte 2b.,11.9. HVAC (Clen)I 269 U) 309** : 313 010 423 175 16 212 25 151 . 583 2b1.1.20 HVAC (ContamiatedInsolated) 151 3 11 I 8 3w 69 412 3 673 782 19 78 1 N41 736 284 201.1.21 HVACContamlnatedl 16 54 725 223 - U32 2O3>4A 185 1474 1 277 313 22 29 152 398 1.536 201.1.22 LtiuldRadoasta 238 269 10 26 106 402 330 V4 22 29 3 29 113 2MI.1.23 LouldRadoaste Itnsultted) 19 25 S1 1 164 1 1 2 32 - 24 16t 100< 191 24 360 M256 793 2b1.1.24 Ltoo OilDslsbtdbo S& PudurifiatioI 161

. 4 17 250 82 51 187 20A.1.25 Malkt-s Water 24 165 S6 24 2bt,1,.2 MIaI-uoWar ll rtsouatedt 15 2 is7 17 22 1 25 17 67 20t1,I27 MoWt-so Water RCAInsulated) - 471

-1 18 114 10 14'8 96 370 20.t.1.2 Maae-soWar (RCA) 98 .2 7 163-w 41 2511 . 0 2 201.1.2b charioatDelsartero Eot omeS Ma12 I I

NOTE: Totalsmy rWsur due toro1nd0 Ena.otr 3 POE Letter

_OLCLO-TABLEC-2 TABLEC-2 DIABO CANYONPOWERPLANTUNIT2 DLABLOCANYON POWER PLANTUNIT 2 DECONDECOMMISSIONINGCOSTESTIMATE DECONDECOMUOSSION]ENG COST ESTIMATE MT.oussod.of 2004Dolt.1 ) (Thou.ods of12009DO1l1.)

.1D r-e LLW Buriotllt Off-Site LLEW Ntie Avitv De-itiot Dea- Re-o.- Pockagig T r P ssing Distpeal 0th- Cotigeooy T-1 A CP BCP C"IP GTCC* De-.

t Retti .Poa Trst PTting Disipo.l Other Cotingency " Tot-l 25.11.3 48aeal"""u ReatorCoolan t4 78 2 3 22 56 45 221 123~ 18 91 2 4 32 45 - 6 250

-1 j 2b.1.1.31 Nudlee Stea SuoolySamotia 12 1 12 - 12 14 1 210 -0 2b.1.1.32 Nualer SteaboDDool5amotinottonulatedl - 5 - - 1 3 t4 11 -

m S - - 1 4 -4 1 21,.1>33 Retaddutlattoottmo 221 183 22 43 228 1.46 '148 2.218!> 2193W 257 213 28 62 327 87 -1 87 2.381 2b.1.1.34 Stetloeone -nzo 76 3 5 57 55 - 422 238 120 88 3 7 82 44 -79 304 2b.1.1.35 Safevlniation (lns atedl 3 - - 3 2 I1 - - 3 2 3 12 21.1.1.36 SafetvjIniecon(RCAttulatedl I.3 1 2 17 30 1S 89 63 - 27 1 3 24 25 28 108 2b1,1..37 Safetlniection(RCA 194 10 17 152 2S- 142 785 505 225 12 24 2t8 223 246 948 2M.1.1.38ServiceCootinaWater 90 - - 13 103 i - 105 - - 37 141 2b.1.1,3 SermoeCooairWeter(RCA) 22 2 26 10 MO " 26 3 37 23 89 2b1,1.1.0 SewerSW-e E--nso 31 . .. 5 31L, 732 " * *,oi 'o,"144 10536 .. 69 6,22838,413 3 ,3749 2b.1.1 Totals 1217 9,258 195 466 5.595 3.607 4,397 24.733 1 732 1.1 - 8.34 32.37 2M.1.2 Salffl800onsooo4oldenort. oreatotdons 4.436 2m 10 138 43 148 5.792' 96 5.154 23 14 200 34 1.899 7.324 20,1.31 Reactor 1.182 1.313 2*1 304 319 8.742 3.M221 15%312 18464 1.72S 268 436 458 3843 14.822 21,.1.3,2 Auotiar BUS 44 59 48 174 2.161 1.t24 4931 4832 1 574 64 123 250 1,7M9 1,289 4,973 20.1.32 CeodJAddA oa 85-2002 264 140 13 18 22 470 282 t,168 i 1049 307 116 is 25 32 371 Ml03 1170 201,.3 Coarrannt Penetraon Area 284 145 15 24 90 537 291 1,341 1.204 237 1 17 34 129 422 353 1.362 2M.1.3.2 RedwesteStoaoe 5 45 6 9 6 235 75 381 524 -,6 52,7 13 8 186 S8 201,3 Totals 2 481 2.098 324 440 610 12.152 44.83 M2"I8 27403 -28 2. 378 82 878 847 - 884 22=95 21b.1 SubtotalPeriod21ActityColst 3.698 15t.79. 539 818 6,344 15.802 10,634 53.6241 385.128' , 4.297 18.348 628 1.315 9.107 12.524 16.176 62,395 Petod20 ColateralCosts 2b.41 Process liuddwaste 68 - 169 220 1.63X 491 2.579 - 1895' 79 - 196 316 2.34- 1,026 3.957 M04.2 Smafoo toolaalnoo 313 - - - -- . 47 3598 - - 364 - - -- 17 l 491 21,43 Spent FuelCapitalondT-1rte - - - 50(M) 75D 5 7W8 -5 .810 2.032 7.843 2044 Radotote ProceossmEacUhmentoSernoas . -. . .. 394 59 453 2534018 '15B ISO 6 204 SubtotalPeriod2a Coltatel Coate 8 313 169 220 1.630 5.308 1.347 8,142 1 ,85 79 364 184 316 2.W 6,267 3.347 12.909 Pedod 2b Period-De88 rde4 Costs al,8.

21b4I De s....

SUoo es - - 408 2.038 1.894 -663 2.557 2b642 insurance- - - 5.738 573 6.M831 88 - .6"58 6-- 2.330 89588 26423 Prooertvta-e -N 80 5 - - - - - 935 327 1.263 20.44 114810 ohoicssoolien - 4NI DB .0 5.100 4.741 -- -- 1.659 6.40 284.5 Heaw edsumentrental 4,345 - - - - 652 4.996 5,048 - - - 1.767 60815 20 48 0isosalttof4DWoenerated - - 111 49 - 3.365 860 438t4 -8.3.9 128 70 -2.427 -8835455 2b.47 Planteobtbuet

- , - 2269 340 26101 i - ' - 2.636 823 3008

- 1.143 - 1-1328 ,1328 2048 N8CISFSIF-2b 49 68CFe 2.347 236 2582 2727 954 3681 22410 Emoarolt-oPtljo8F- 2.8973 297 32703454 1.209 4.6&3 26411 SpendFuelTransfer-lSFStoaDOE - 61.82D 243 1. 14882 659 28541 2b.412 Seret FuelPoolO&M 7.m23 1.148 98112 - -892M6 322 12428 28.4.13 SponlFueo Stobe*eeC/mtoalEui-onlent 43.631 6.545 508175 - ----- 50695 6 17.743 68.438 20.414 JEFSl Oeorao - 1,143 172 1,315 1.328 46 1783 2b4.15 ISFSI Foed Costs 2.287 343 263,0 r 2,67 86 2b.0416 SecurkvStaffCost 13.625 2044 15E6O9 - - - -"15,831 5.541 21.372 2M.4,17 DOCStaffCost 22.649 3,37 26.046 - - - - - - 268316 9.211 3.5526 2b0418 UOtNta8Cost - 75,49 1124 2358540 8384 - _- - - 87,258 117,748 284 SubtotalPeriod2MPerOedod-DerDenrt Costs 1.630 8.425 111 49 3360 183245 2.61 226448 8348 1.894 9.789 129 70 2427 212912 798527 348749 2b.0 TOTALPERIOD 21COSTS 5,396 24.529 819 1.186 6.3W4 28.786 188,3 41.453 28S92521 42.597 1,895 270 28.50( 952 1.703 9.107 17.530 219.18( 99.134 382376 Period2c - Deneoraaooalbo Fottoodosa WetFuelStolors Period20DirectOeaoroioroniActMtss A

25.1.1 R-e soent fuelrak 365 37 7 28 - 1.048 - 46 2834 2 - - 424 43o 4) 800 - 1.929 Disoasat of PeaalSystems 2c.1.2.1 Eleal (Cltaomonated)-FFHB 66 1 2 34 6 m2 1 3 2 12 -

, 1 T7 1 3 4

'19 47 182 2.1.2.2 Elactnait (Doeontaminated) - FHB 403 5 21 325 153 98 468 7 487 w 1.31 2c.1.2.3 FireProtecton(RCA) 157 3 11' 166 - 66 4031 a - - 182 3 16 238 - 154 E4 594 25.1.24 HVAC(Contaminatedl - FHB 158 3 11 158 31 71 4251 64, . - . . - 174 3 16 228 26 157 6N5 2.1.2c5 S entFueoOPOColin- 56 13 17 89 38 - 131 703 834 - r - 65 15 24 128 338 -. 187 758 2.1.2.6 Sont FuelPaCooina-F11HB 76 14 18 96 427 m144 778 88" - - -88 16 26 138 - 354 218 840 2e.1.2.7 Totals 908 38 80 869 862 O58 3,34u6 14867 - - 1.055 44 115 1.248 715 1.112 4=288 Deaontamniotion oa Ste Buildonas 62 520 21 w 154 47 2c.1.3.1 FuelHandino 2"55,- 1.58- -5 -1 811 810 24 47 221 547 721 2.783 2 4 20.1.3 Totals 52 525 21 33 16 487 - 598 .55 1.547 - -4 611 610 24 47 221 547 721 2,783 2,.1.4 0afloldin8insUoDOd ofdeomissionins - 487 4 2 28 9 -- 228 1.158 '18 - 1.031 5 3 4) 7 380 1,466 2e.1 SubtotalPenod2c A otv Costs 481 2.357 142 144 1,021 2.615 1,882 9,082 0.723 1.035 2738 165 207 1.5(X 2.098 2,713 10,486 Period 2c ColateralCosts 20.3.1 Proaesa Idoudroso. 33 - 16 41 m3 -* -- 82 485, - 269. - - . 38 - 19 59 334 158 B88 20232 Srnl toolaoooetl 8 60 6- - - -- -21 82 2c03.3 ODeaomsiorts o Eouioroeot DOsoosoJn 74 46 513 158 8O6.,;" 66 736 126 - 355 1.370 25.24 3 oRadaste P e Eouiomeot/Seaoaes - - 3 48 260 2c03 SubtotalPeriod2a ColateralCosts 33 52 N0 87 513 3m2 166 165 25 2486 ~ 190 1

Sil 289' a , 38 .. 145 125 736 461 193 601 2.320 Period2c Pedod-DeoendetoCosts 2c.4.1 Deoonsuooies 184 - 46 229 .-.. r 214 75 289

NOTE:Totalsmaynotsatudue torondNVg EnclosureI PI&E LetterDCL9-*

TABLEC-2 TABLEC-2 DIABLOCANYONPOWERPLANTUNIT2 DIABLOCANYONPOWERPLANTUNIT2 DECONDECOMMISSIONINGCOSTESTIMATE DECONDECOMMISSIONING COSTESTIMATE (Thu ..ose. of 2004Dollat) lThoaneeds of 209 Dollt,.)

lEere~let a*tor treetroofl0atd 43ts forLILtWIroe2O4:R~e++d Eoootromrl%: Re+ree SCeasABtmralNa. toS*atd Off-S t. LlwOff-Sites Notritt AoDesetitoo Deon Raroves PsAlnog. 'T-esport Praoe..to Disosal Othte Coetiogeocy Total I A CF RBCI C CP OTCC'I Daes Ratooe Packceito Traosport Preasine Otetrcot lth.r Conitinefly Total 2.4.2 Insrra-ce 261 26 288 -, .o .1 303 106 - 409 40 4 45, - 4616.-

2c4.4 Proealthae -Ilea -h

.068 - - . 371 5.436 912 - 137--

2 c.4.5 H a.e. . .icha en tnrental 2c4.6 DsaosalofDAWaencerted - 26 - 203 1 0371 769 Mý - - ,L - 30 17 631 - 237 916 2c4.7 Pl anrnerbinaoet- 179 Z7 205t64, -- ----- 208 73 281 2c4.8 NSCISFSI Fees- - - 5 - 7 - -. 66 -66 2c 4.1 NREFe1-e s-- 151 15 166 . + \ -- 15 t237 10 i 6173 -C -h -'C -"i' 1-9 61 234 2..4.11 soentFuelTranele-tSFSltt0OE - s 30 19 149 45 -5 -6 3 2o.4.12 lSFSlOoero~atost C -Is- - 57 9 66 6 38 2o.413 ISFSI"o"aCoss - 115 17 132 " 134 47 180 2c.4.14 SeauntoEtallCost - 043 156 1210 1 -1212 424 1636 2c.4.15 DOCStaffre C- m 3235 485'Ce 3720 4--.35 1316 57 2C.4.16 UItii StallCoat - 6174 7T26t06 I -- - 7.174 2.511 9.684 2,.4 SubtotaltPeriod2c Peiod-eDoortoCosts 14 1.254 26 12 m 796 11.593 2.172 16.036 1710 314 1.457 m6 17 -3 13.470 5.W3 21.

200 TOTAL PERIOD 2c0COSTS 1.107 3.664 258 243 1.564 3.83 11.758 4,300 266 745 1286 4,257 310 349 2.245 3.190 t2662 8.851 3.4 PERIOD 2e-*Uc- Terdbodion *+*",*

Period 2eDirectDecnourmsrreace Actiodies 2e1 A 06152confrloutattsrc 119 36 1631 t ---- 31 48 187 2e.1.2 Termiteoto -- - -e - - . - - -

2cr SulbtutalPeriod2aActm Coats, 119 36 110-- 138 48 187 Period2e AddlitoelCoete 1 -

2e.2.1 UenosoTermraito* Sulvo. 9,770 2,931 12.7011 - - ,-,,- .. - -,-,- - 11.352 36973 15.325 2e.2 Subtotal 2e AddionalCoats 9.770 2,931 12,701 - ' - -:-, -o- -11.352 3.973 15.325 Period2c Colaft ree - -n- 1.031 153  ; - < :X: 1.106 415 1.C02 2e1 DOTStaffroalootbr, -5 I=64 1.1744- .18 4 602 2e.3 Subtotal2e CallatralCoats - - - - - - 1,021 153 1.7 1.186 415 1.602 Period2e Period-DeonadeotCoats 2e.4,1 lrnsuroane - -- - - 321 32 3534. > 4 373 131 5)4 2e,42 Prfoarlytaces 66 7 72 77 27 104 2e.43 HcalthohvsimSuoalie - 215 - 541 268 25S 87 337 2e,44 Disol- ofDAWoenerated - 15 4 2123 -1 31 32 273 5 3 698 37 142 2e.45 Plat enerr budaet - - - - - 145 22 1674' 168 59 227 2e.456 NRCISFSIFees 118 108 2e.47 NRCFees - - -- 245 25 270,M IL 2S5 100 36 Dn.A4 EmnemenrPlannca Fees - -- - - - 243 24 2 7 < 282 99 381 2e.4.9 SoernFoalTrensfer- ISFSI to DOE - - - - 137 26 2151 217 76 2m3 2e4l0 ISFSIODetnotCosts - -- - 6 14 1071 106 38 146 2e.4.11 ISF51FIredCosts * - - - 167 26 2151 217 76 m9 2e.4.12 SecurityStaffCost m L40 1.70~ 1,051 378 1.459 2e.4.13 DOCStaffCoat - - - - -- 3.916 587 4.504 4.55() 1.553 6.143 2eA14 Uh Stafl Coat 5716 057 7O6-6.5 6.641 2.324 8.69 2e.4 Subtotal Period2e Pearod-Deoledent Corte 215 4 2 123 12.14 1.849 143361 273 250 5 3 - 98 14.110 5.063 19.526 123 23.054 4,99 28.366 273 250 26.786 9.499 3W.641 2e,0 TOTAL PERIOD 2e COST 3215 4 2 - 5 3 - S0i PERIOD 2 TOTAL 7.663 53,557 12.372 5SAM 26167 65.938 279.551 676967 39.100r 11744 996 574 8.904 62.228 14.375 7.444 38.570 W1.666 324.810 180,949 M07.948 PERIOD 3b ReStoration Perod35DirectDeoanumlasionino Activities Semollion ofRemainirtSoteBuildinoa 3b111 Reactor 7.078 2A47 9.556 3b,1.l,2 Adiflrltration 898 314 1.213 3b1.1.3 AoailaryI 6,0922 914 .7006 9-' o 7 l.388 2.236 8,624 3b11.4 Cait al Additionas 85-2104 773 - - - - - 116 803 4.065 - - 1.423 5.488 3bl.1.5 ChemIcal Stmoae 3 3b1.1.6 Chlornaloan. - 3A499 -5 25 4.024 3 11 3b.1.1.7 Circula"r Waer Tunealt 52498 825 6.323 ° , - - 81 312 1.203 3b11.,8 ColdMachlne Shoo 117 452 3b.1.1.9 Comtrunioatioa -3 I28 7678 -43 1- - - 26.07 331 863 4

1 +;'  ::++:+ ': 0 *:: 3 1 5 3b1,1.1,10CondensatePdoahinofTeohnicka Suvooret - 605 - - - - - 91 696 703 - - 244 094 35,1.1.11 Containment Peretection Area 568 199 767 489 - - 73 463 3b.11.12 DOehaMr SssCturc 790 S 273 1.067 3b.1.1.13 FabrtcatonShoo 35 135 3b.1.1.14 FirePut Hroue 6it 13 7621 to5 2 6

.* 131 4,,,--* , --

35.1.1.15 HaalardosWase Stotre Faity - 1.78D - - 267 2.N71 2.068 724 2.792 3b,.1116 AtakeSIStI""rte - 3.810-S- 563 4.471 4.517 1.581 6.099 35.1.1.17 Maintenanc5, Soo - 266 4Q ,,1iS 309 - 108 417 3b1.118 MisaelaeoosStrutres - . 47 - - 7 55 19 74 1.534 35,1.1,19 NPOPerharrratWrnarelhosee - 978 - - - - - 147 1.

5 1.136 3988 3511.20 Poads 1 0 2 3b.1.1.21 Pale Finre Pumo& FuelCat 0 2 35.11.2 Pretrerrl 3 11 3b.1.1.23 RadoasteStbr-e - t.2611- - 190 14581 1.473 516 1.986 36.11,24 Roadwase StorasoFacfltv(Additional) 38 13 52 3.1.1.25 RoorWareoseso - 557 - 0as 6 761 682 m 923 21 3b,1.1.20 SreuiNb - 240 -w - - 3 2761. 279 98 376 10

4,4"?

NOTE:Totalsmy notsI du toroonding Enslosure3 PG&E LetterDCL-*9-SS TABLEC-2 TABLE C-S DIABLOCANYON POWER PLANTUNIT2 DLSBLOCAN0YON POWER PLA.NT UNIT2 DECONDBCOMRiSSiONINGCOST ESTIMATE DECONDECOMUOSSIONING COST ESTVI[ATE (Thosond. of 2004Dotl1s) (Thoeund. of 0O9Datil-)

-- BooleteAitent nd L -1 at t Off-Site LLRW Off-Site LLRW I ubr c h De iption DRoo Remone Pnckagitg Traneoort Pro*o ste Dispos Other Co-tr tgenno Tetet ACF BCP -CC? GTCC Remoe BeIenn enPnPe Pt o eat Dospo Cohen Coatingeeny Tote1 3b.1.1.27 Seouut 8uldLktais lAddional) 5 t4 42 15 50 3b1 .120 Simnutator 45 341' -2 4 - --- 1t 166 3b.1.1.29 Steam GeneratorStame Fesrltv 65.3 04 751li -~- 750 24 t54 1 M 3b1.1.30 Teltehoee Termina 2 22 t.54 2 -!!1 3 3b.1.1.31 Turbne 4.384 65043 5.04241 4-5 - - -- 1.783 6.877 3b1.1.32 TurbinePedestalVetisleMaintenace 145 113 125 - 394 t.51 3Ml.1.33 VehaotMainteoatce 24 4 24. 20 - -- 10 30 3hA1,1.34Waste WaterHolra & TreatmentFacty 16 2 19It 19 - -- 737. 2 3M.1.135 FuelHandlrm 1.347 982 175 40,19, - t- 4 --- -759- 548 2413 3b.1 Totals M.6 8vl 5.33 4041441.00 3 -,B25 - 14.485 55.009 Site CioooutAscMtes 3b.1.2 RemovoRubbie 21,295 3.1094 448 24 744 28. w4)3 3b.t.3 GrodeS landscae site 1.812 277 20863 21 2.5

' 66 273 1732.0142 3b.1.4 Finalreportto NRC 3b.t1 Dubtotal Period30Ativat Costs 58.72M 10 58023M 23.041 92.114 Period3b AddittooalCost 3,2.1 Concrete a sohino 6.535 961 7525 . - 7.50 9 .2-01 10.263 3W..22 Brelawoter Demolition andRemoval 33.3209 8,332 410641 ,.725 r,-* - - - 1 7 13.554 52,279 3b.2 SubtotalPeriod3bAddflJonad Co*ts 39.864 0.314 49156 46.318 -9..* - 1 5 16.215 63.54 Period3b Codateral Costs 31.3.1 Smolttot aootri a 103 78r . 7 794 270 30.3 Su I3bCostoeralCosts 6S3 Perod 3b Pedod-EeeendetdCosts 3,4.1 1 -surdosa 5755 5' 632 -51 23 9D2 3b.4.2 Prooeýtttaoes 181 it t1991 210 74 9 3.4.3 Heoatn eaurtens rental 5.531 030 5..4'0 - -- - 2.240 t.67R 31.4.4 Plant-e udoelt 6301 22-o* 3

.75 ":  ; - I - -

704L - - - MI 7 27 8---311 S 1 ..312 0731 30.45 NBCISFSIFees 257 31.40 Emeroenso PlaniaroFees 9 257 " " - .--- - - 350 27- 297 67 1.73 775 T`-:- 271 1.0.4 3M.4.7 SpentFutlTransfer- ISFSItoDOE 75 574  : - -- - Mo 5 0 203 703 304.0 ISF51 OeretasoCosts - - - 257 39 2051 - M 0 105 403 3b.4.9 ISFSIFlood Costs - - - 513 77 - - - 596 209 0D0 31,4.10 Securit StaffCost 2.555 303 200 - - - -- 2,969 1t039 4.004 31,4.11 DOEC Staf Cost 1702 13736 - - - 13.079 4.650l 1t.737 30 4.12 UtIVStattCost I.Mo 10,2591 - 10.365 30328 135093 3b.4 SubtotalPeriod30Perrod-Desendent Costs 5.5311 4.705 30005 6.420 6 30.871 130I54 50,35t 104.604 3b.D TOTALPERIOD 3bCOST 26.643 22940 154.3871 121.772. 30,957 53,455 206.103 PERIOD 3c - FoalStonageOenratione/Slhiooioan Period 3, DirectDesommslosilno Costs Period 3c Period-Dependent Costs 3s.4A I--sranue 1,44 14 1551 167 59 226 3s.4.2 Pto erto Ones 4 49 - - 51 . 18 -04 3c.4.3 Plantenesrybuhoet 14*

3s.4.4 NRCISFSIFees 3W.45 Emem t Plsmonac Fees 10 lor -* - 101 07 257 3c.4.6 Soet Fut Transfe - ISFSIto DOE 175 20 6 2013 71 274 3W.47 ISFSICoeroainCosts 9 n 73 20 99 3c.4.8 ISFS Fxood Costs - - - 120 10 1451 - ,--140 51 15 30.49 Seuttv StafD Cost 3C.4.t1 U" Stats Coa0O 3c4 SuDoRal Period3c Petid-Eeoeoodent Costs -

338 1.238 103867 2 07 o' 11 M 137 527 150 l i 1.438 503 1.942 3c,0 TOTALPERIOD 30COST * - - 1.238 PERIOD 3 - GTCCSbitDna Period3d DirectDecommassiornlrr Astlea NusloarSteamDSuopl Sotem Revl 3d.1.1.t Vessel& Internoas GTCC Dtoosal - - 8.447 - 144 11.0481 4.115 18.571 4331 104 13,562 3d.t.1 Totals - 167 167 - - 0.447 - 1.434 5o48*i.> o:* ° 433r 194 4,815 18.571

- 167 1.4 34 1 1 0 40 443 3 ,1 19't 13,562 34.1 SubtotalPertod3dAotiltnCosts 9 447 13,562 4,115 18.571 Period3MPedod-Deoendenl Costs 34.4.1 Insuteanc 12 V 13 4 17 3d.4.2 Poennt taxes ,3 3 1 5 3d 4.3 Plantenemybudoat 3X4.4 NRCISFDIFees 5 - 5*.+ 6 - 6 3M4.5 Emeraeooo Planino Feea. 1 1 14 14 5 19 3 7.4.0 1SFSOterotinaCosts 6 2 0 3A4,S7 SF5i FoodCosts 12 4 18 3M4.4 SoeutivStaDf Cost 10 1 11 i 12 4 10 StaffCold Utility M6 4 29* 30 11 41 3dA.9 34.4 Dubtotes Period3dPeriod-DeeesdentCosts - 01 10 9 33 w4 127 3d.0 TOTALPERIOD 3MCOST 167 9.447 81 1.444 11139 433 194 13562 4 4.848 18.698 PERIOD3 - ISFS0Daontarrlsasiolr 11

NOTE: Totalsmaynotsum dueto ronding Encloure 3 PG&E LetterECL-OS9-s TABLEC-2 - TABLEC-2 DIABLOCANYONPOWERPLANTUNIT2 DIABLOCANYON POWERPLANTUNIT 2 DECONDECOMMISSIONING COSTESTIMATE DECONDECOMMISSIONING COSTESTIMATE

.ffThosnde ea2009Dol1ers)

(Tohooud of 2004D.ollac-Off-Sloe LLRW irri{OO4:i - ff-S ev ont LLWR Nuober AcotivityDoesipton Does RB..oan --

Peckaieo Tranapost Proceise Ditpecet Other Centiee cy Toe I- A P iB uC C C-AJt IPCTs

. TCC GT- it De- - Re.... Psckaegig r rnpre Pceise r~sn O isoaa 0c-te otnec e.

Co oo Period3e Dikedt Dcmmissioning Aotstias Period3e AddlionelCosts 3e.2.1 ISFSILicens Te*iinion 651 6 70 756 7 155 1,742 801 1.220 4707 2.17 7M 837 4518 4.$j 3e.2 SubtotalPeriod3e Additioral Costs 851 3 70 2197 758 837 4.518 488V - 756 7 1w0 1742 N81 1.220 4,707 Penod3S Collateral Costs 3e.3.1 Smalitol alioaance 0 - - 9 3 13 9

3e.3 Subtotal3e Collateral Costs 3 13 Period3e Period-SeendentCosts 3e.4.1 Isrance" 3e4.2 Proeruta1e N S 321 S 34 12 45 3e.4.3 Heaw eouiementrenail 153 - - 54 207 31a44 Pant eners budset 16l 2 tea 19 7 25 7

3e.4.5 NRCISFSIFees - 41 - 41. >1r~ ti 3S46 SecunvStaffCost - 3 12 95~r4r OS -- %o 34 130 So.4.7 U0iit Stet Cost 230 81 311 21.4 SubtotalPenod 3e Period-Debondemt Costs 132 - 368 67 087 - S 153 428 203 784 oeS TOTAL PERIOD3e COST 792 8 70 2.197 1.126 SOS SOS.1095 35 ~ - o 7 too 1742 1308 1.427 5.505 PERIOD 3f - ISFSISee Restoration Penod3f DiredtDecommissionoActivities Penrod 3f AddionalCosts 3St2A SFSIDemoltion andSOeRetmaetion 831 966 3f.2 SubtotalPeriod3fAddMlonl Coets 20 211 .082 M6 23 M 34w .335 Period 3SCollateral Costs 3t.3, S-inat-l a1IO-ance 2 3 2 1 3 3f.3 SubtotalSt Collateral Costs 2 2 Period3f Penod-Secendem Costs 3f.4A i.ua 3U42 Praeervtaoo 15 .. 1 1 .. '17 8 24 3f.43 Hear ecuiementrantal - 4 - - -7 -0 St 1 -- - 18 ON 3f144 A Pnt enery budoet - - - -8 1 - 3 13 3f.45 NRCISFSIFees 218 21 24 -24 3fAN6 Secutv StaffCost - - . - -- 42 16 4 - .- 45 17 ON 3f.47 UtOirtSStaffCoatl -~~8 - - - - - O 13 102 - 03 So 1,10 3f.4 SubtotalPeriod3fPeriod-DecendentCosts - 4 - - 174 M5 24 t 51 202 ON 342 3f.0 TOTAL PERIOD3fCOST -1 o 1.311 1,019 M27 436 1.62 PERIOD 3 TOTALs i06,47a 172 70 - 116 29.M 25.688 173.32 r 123.710 200 100 153N4 34023 600668 234.005 TOTALCOSTh TODECOMeMISSION 11.14" 162.418 13.113 6864 26.867 82.38 372221 125.961 800.529 .1-22. 8 i i 4 12.91 186713 16,236 8a418 38.570 83.498 422AM 272.964 1.052.824

, - mndicatm thatthisa* oemmomed!1wdebommissionina stuff 12