DCL-13-033, Decommissioning Funding Report

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Decommissioning Funding Report
ML13092A195
Person / Time
Site: Diablo Canyon  Pacific Gas & Electric icon.png
Issue date: 04/01/2013
From: Halpin E
Pacific Gas & Electric Co
To:
Office of Nuclear Reactor Regulation, Document Control Desk
References
DCL-13-033
Download: ML13092A195 (213)
v • d • e


Text

Pacific Gas and Electric Company Edward D. Halpin Diablo Canyon Power Plant Senior Vice President Mail Code 104/6 Nuclear Generation & Chief Nuclear Officer P. O. Box 56 Avila Beach, CA 93424 April 1, 2013 805.545.4100 E*Mail: E1H8@pge.com PG&E Letter DCL-13-033 u.s. Nuclear Regulatory Commission 10 CFR 50.75(f)

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:

Pacific Gas and Electric Company (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 Power Plant, Units 1 and 2 At the end of calendar year 2012, the market value of the DCPP Units 1 (3411 MWt) and 2 (3411 MWt) decommissioning trust fund Market value was $920.8 million and $1,221.1 million, respectively. TLG Services, Inc., prepared a site-specific decommissioning cost estimate that PG&E submitted to the California Public Utilities Commission (CPUC) in the 2012 Nuclear Decommissioning Cost Triennial Proceeding (NDCTP) on December 12, 2012. Based on this cost estimate, PG&E currently has more funds in the DCPP, Units 1 and 2, decommissioning trust fund than required to meet the minimum NRC decommissioning amount of $643.0 million (2013 dollars) for each unit that was calculated pursuant to the requirements of 10 CFR 50.75(c).

Supporting Cost Estimates Based on site-specific cost estimates prepared by TLG Services, Inc., PG&E estimates that the decommissioning costs are about $1,062.3 million for DCPP, Unit 1 and $1,100.4 million for Unit 2 in 2013 dollars. These costs do not include site restoration of the facilities ($306.4 million) or spent fuel management costs after shutdown of Units 1 and 2

($477.5 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.

Supporting Enclosures Enclosures 1-5 provide supporting documentation for this report.

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

  • Comanche Peak
  • Diablo Canyon
  • Palo Verde
  • San Onofre
  • Wolf Creek

m I

Document Control Desk April 1,2013

& Page 2 PG&E Letter DCL-13-033 Enclosure 1 provides decommissioning funding status information in a format suggested by the Nuclear Energy Institute (NEI) and the NRC.

Enclosure 2 provides information on the escalation of the required decommissioning funding amounts from 1986 dollars to 2013 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 15, the information includes escalation factors for energy, labor, and waste burial costs.

Enclosure 3 is the 2013 DCPP Appendix C1 and 2013 DCPP Appendix C2 from the TLG Services, Inc. decommissioning cost estimate report prepared in December 2012 for PG&E for DCPP, Units 1 and 2. PG&E then adjusted the TLG Services, Inc. cost estimate to reflect the costs in 2013 dollars per the NDCTP submitted on December 12, 2012, to the CPUC by applying the escalation factors included in the submittal. The report provides cost estimates for decommissioning of both nuclear and non-nuclear facilities, including the DCPP Independent Spent Fuel Storage Installation (ISFSI).

Enclosure 4 is a cash flow for the total decommissioning of DCPP that identifies the monies for NRC scope (removal of radiological contamination), site restoration (including nonradiological work), and the spent fuel management based on the TLG Services, Inc.

2012 Cost Estimate by unit.

Enclosure 5 contains the TLG Services, Inc. decommissioning cost estimate report prepared in December 2012 for PG&E for DCPP, Unit 1 and Unit 2. The report provides cost estimates for the decommissioning of the nuclear, non-nuclear facilities, and spent fuel management, including operation of the ISFSI in 2011 dollars.

PG&E makes no regulatory commitments (as defined by NEI 99-04) in this letter. Should you have any questions, please contact Mr. Bob Kapus at (707) 444-0810.

Sincerely,

~,

Edward D. Halpin Senior Vice President and Chief Nuclear Officer Enclosures cc/enc: John B. Hickman, NRC/FSME/DWMEP Project Manager Arthur T. Howell, III, NRC Region IV Diablo Distribution INPO A member of the STARS (Strategic Teaming and Resource Sharing) Alliance Callaway

  • Comanche Peak
  • Diablo Canyon
  • Palo Verde
  • San Onofre
  • Wolf Creek

Enclosure 1 PG&E Letter DCL-13-033 NRC Decommissioning Funding Status Report Diablo Canyon Power Plant -- Units 1 (3411 MWt) and 2 (3411 MWt)

Enclosure 1 PG&E Letter DCL-13-033 Page 1 of 2 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.

Note that Items 3, 4, and 8 are data included in PG&E's Nuclear Decommissioning Cost Triennial Proceeding (NDCTP) filed with the California Public Utilities Commission (CPUC) on December 12, 2012. PG&E does not anticipate a decision on this filing until late 2013 or early 2014.

1. The minimum decommissioning fund estimate, pursuant to 10 CFR 50. 75 (b) and (C)1

$ in Millions Value in January 2013 dollars Unit 1 $ 643.0 Unit 2 $ 643.0

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 2012 dollars) Unit 1 $ 920.8 Unit 2 $1,221.1

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.)

1

  • 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-13-033 Page 2 of 2 Unit 1 amount remaining $ 551.4

($51.3 million per year beginning 2014 to shutdown)

Unit 2 amount remaining $ 340.0

($30.0 million per year beginning 2014 to shutdown)

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 2024 for Unit 1 and Unit 2), and rates of other factors used in funding projections; Rate of Return on Qualified Trust Unit 1 4.80 percent Until end of commercial operation November 2, 2024 Rate of Return on Qualified Trust Unit 2 4.80 percent Until end of commercial operation August 26, 2025
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 2013 Dollars in Millions Total Unit 1 (Decommission 2024) $ 1,399.9 Scope Excluded from NRC calculations $ 77.4 Spent Fuel Management ~ 260.2 Total NRC Decommissioning Costs $ 1,062.3 Total Unit 2 (Decommission 2025) $ 1,546.7 Scope Excluded from NRC calculations $ 229.0 Spent Fuel Management ~ 217.3 Total NRC Decommissioning Costs $ 1,100.4

Enclosure 2 PG&E Letter DCL-13-033 2013 Decommissioning Estimate Unit 1 (1 page) 2013 Decommissioning Estimate Unit 2 (1 page)

Composite Escalation (1 page)

Development of E Component (7 pages)

Development of L Component (9 pages)

Development of B Component (1 page)

2013 Decommissioning Estimate Unit 1 Enclosure 2 PG&E Letter DCL-13-033 Nuclear Regulatory Commission Estimate of Decommission Costs for Pressurized Water Reactor (PWR) Diablo Canyon Power Plant (DCPP) Unit 2 in 2013 DCPP PWR (millions)

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

Escalated to 2000 (No Submittal Required)

Escalated to 2001 $333.8 ($396.7 in 2001 Submittal)

Escalated to 2002 (No Submittal Required)

Escalated to 2003 $347.5 ($404.8 in 2003 Submittal)

Escalated to 2004 (No Submittal Required)

Escalated to 2005 $404.2 ($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 $540.4 ($679.5 in 2009 Submittal)

Escalated to 2010 (No Submittal Required)

Escalated to 2011 $588.1 ($583.9 in 2011 Submittal)

Escalated to 2012 (No Submittal Required)

Escalated to 2013 $643.0 Based on 10 CFR 50.75 (c), "Table of Minimum Amounts" (January 1986 dollars).

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=1200 MWt $75+0.0088P)

Page 1 of 1

2013 Decommissioning Estimate Unit 2 Enclosure 2 PG&E Letter DCL-13-033 Nuclear Regulatory Commission Estimate of Decommission Costs for Pressurized Water Reactor (PWR) Diablo Canyon Power Plant (DCPP) Unit 2 in 2013 DCPP PWR (millions)

January 1986 Estimate $105 Escalated to 1999 $118.2 (Table 2.1 in NUREG 1307 Revision 10 has no value for 1999 Burial:

Escalated to 2000 (No Submittal Required)

Escalated to 2001 $333.8 ($396.7 in 2001 Submittal)

Escalated to 2002 (No Submittal Required)

Escalated to 2003 $347.5 ($404.8 in 2003 Submittal)

Escalated to 2004 (No Submittal Required)

Escalated to 2005 $404.2 ($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 $540.4 ($720.9 in 2009 Submittal)

Escalated to 2010 (No Submittal Required)

Escalated to 2011 $588.1 ($546.5 in 2011 Submittal)

Escalated to 2012 (No Submittal Required)

Escatlated to 2013 $643.0 Based on 10 CFR 50.75 (c), "Table of Minimum Amounts" (January 1986 dollars).

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=1200 MWt $75+0.0088P)

Page 1 of 1

Composite Escalation Enclosure 2 PG&E letter DCl-13-033 Calculating Overall Escalation Rate PWR Jan-86 Jan-99 Jan-OO Jan-01 Jan-02 Jan-03 Jan-04 Jan-05 Jan-06 Jan-07 Jan-08 Jan-09 Jan-10 Jan-11 Jan-12 Jan-13 Weight (1)

L (Labor) 1.0000 1.5624 1.6370 0.9365 0.9733 1.0122 1.0612 1.0958 2.0724 2.1465 2.2207 2.2639 2.2948 2.3175 2.3711 2.4081 0.65 E (Energy) 1.0000 0.8499 1.0297 1.1850 0.9909 1.2027 1.2164 1.4656 1.8306 1.7950 2.3262 1.7850 2.0766 2.3145 2.6030 2.5637 0.13 B (Burial) 1.0000 0.0000 10.8039 10.9840 11.1633 11.3433 13.0733 13.3951 13.7247 14.0626 15.0364 15.6505 16.2646 17.2446 18.2247 19.2044 0.22 (1) From NUREG 1307, Revision 15, Report on Waste Burial Charges, Section 2 Summary, Page 3, where A, B, and C are the fractions of the total 1986 dollar costs that are attributable to labor (0.65), energy (0.13), and burial (0.22), respectively, and sum to 1.0.

PWR Combined Escalation Rate for:

Jan-05 Jan-06 Jan-07 Jan-08 Jan-09 Jan-10 Jan-11 Jan-12 Jan-13 3.8497 4.6044 4.7224 5.0538 5.1467 5.3398 5.6011 5.8890 6.1235 Page 1 of 1

Development of E Component Enclosure 2 PG&E Letter DCL-13-033 Calculation of Energy Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.2 Using Regional Indices Series ID: WPU0573 Light Fuel Oils (as of 03/02/11) and WPU0543 Industrial Electric Power (as of 03/02/11)

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

PWRwt= 0.58 PWRwt= 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 JUI-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 of 7

Development of E Component Enclosure 2 PG&E Letter DCL-13-033 Calculation of Energy Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.2 Using Regional Indices Series ID: WPU0573 Light Fuel Oils (as of 03/02/11) and WPU0543 Industrial Electric Power (as of 03/02/11)

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) forPWR

=

(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 JUI-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 of 7

Development of E Component Enclosure 2 PG&E Letter DCL-13-033 Calculation of Energy Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.2 Using Regional Indices Series ID: WPU0573 Light Fuel Oils (as of 03/02/11) and WPU0543 Industrial Electric Power (as of 03/02/11)

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) forPWR

=

(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 JUI-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 of?

Development of E Component Enclosure 2 PG&E Letter DCL-13-033 Calculation of Energy Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.2 Using Regional Indices Series ID: WPU0573 Light Fuel Oils (as of 03/02/11) and WPU0543 Industrial Electric Power (as of 03/02/11)

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-OO 126.8 75.3 1.1103 0.9183 1.0297 Feb-OO 126.7 87.9 1.1095 1.0720 1.0937 Mar-OO 126.7 89.7 1.1095 1.0939 1.1029 Apr-OO 126.8 83.1 1.1103 1.0134 1.0696 May-OO 128.6 82.9 1.1261 1.0110 1.0777 Jun-OO 133.6 86.2 1.1699 1.0512 1.1200 Jul-OO 136.2 88.7 1.1926 1.0817 1.1461 Aug-OO 137.4 91.6 1.2032 1.1171 1.1670 Sep-OO 137.8 110.1 1.2067 1.3427 1.2638 Oct-OO 134.1 108.6 1.1743 1.3244 1.2373 Nov-OO 130.9 108.4 1.1462 1.3220 1.2200 Dec-OO 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 Oct-01 143.8 76.8 1.2592 0.9366 1.1237 Page 4 of 7

Development of E Component Enclosure 2 PG&E Letter DCL-13-033 Calculation of Energy Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.2 Using Regional Indices Series ID: WPU0573 Light Fuel Oils (as of 03/02/11) and WPU0543 Industrial Electric Power (as of 03/02/11)

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) forPWR

=

(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-05 148.9 138.5 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 of 7

Development of E Component Enclosure 2 PG&E Letter DCL-13-033 Calculation of Energy Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.2 Using Regional Indices Series ID: WPU0573 Light Fuel Oils (as of 03/02/11) and WPU0543 Industrial Electric Power (as of 03/02/11)

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) forPWR

=

(P) Industrial Energy Power (F) = Light Fuel Oils =

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

Nov-05 161.1 199.1 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-08 193.0 279.0 1.6900 3.4024 2.4092 Nov-08 187.7 218.2 1.6436 2.6610 2.0709 Dec-08 188.3 163.0 1.6489 1.9878 1.7912 Jan-09 190.3 159.8 1.6664 1.9488 1.7850 Feb-09 190.3 145.6 1.6664 1.7756 1.7123 Mar-09 187.6 136.8 1.6427 1.6683 1.6535 Apr-09 186.9 159.9 1.6366 1.9500 1.7682 May-09 190.5 158.6 1.6681 1.9341 1.7799 Jun-09 193.3 183.7 1.6926 2.2402 1.9226 Jul-09 196.2 165.2 1.7180 2.0146 1.8426 Aug-09 194.7 196.1 1.7049 2.3915 1.9933 Sep-09 194.9 186.6 1.7067 2.2756 1.9456 Oct-09 189.9 193.3 1.6629 2.3573 1.9545 Page 6 of?

Development of E Component Enclosure 2 PG&E Letter DCL-13-033 Calculation of Energy Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.2 Using Regional Indices Series ID: WPU0573 Light Fuel Oils (as of 03/02/11) and WPU0543 Industrial Electric Power (as of 03/02/11)

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) forPWR

=

(P) Industrial Energy Power =

(F) Light Fuel Oils =

(P) Industrial Energy Power =

(F) Light Fuel Oils (Diablo Canyon)

Nov-09 186.0 207.8 1.6287 2.5341 2.0090 Dec-09 186.0 197.5 1.6287 2.4085 1.9562 Jan-10 186.3 220.7 1.6313 2.6915 2.0766 Feb-10 186.1 200.2 1.6296 2.4415 1.9706 Mar-10 189.0 217.0 1.6550 2.6463 2.0714 Apr-10 188.8 231.5 1.6532 2.8232 2.1446 May-10 192.0 226.0 1.6813 2.7561 2.1327 Jun-10 197.8 212.4 1.7320 2.5902 2.0925 Jul-10 199.8 209.3 1.7496 2.5524 2.0868 Aug-10 200.8 221.4 1.7583 2.7000 2.1538 Sep-10 200.0 220.0 1.7513 2.6829 2.1426 Oct-10 194.6 235.8 1.7040 2.8756 2.1961 Nov-10 190.9 245.3 1.6716 2.9915 2.2260 Page 7 of 7

Enclosure 2 PG&E Letter DCL-13-033 Development of L Component Calculation of Labor Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.1 Using Regional Indices Series 10: CIU20100000002401 (as of 03/02/11)

January 1986 adjusted to reflect NUREG 1307, Revision 14, Scaling Factor for West Labor (Page 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-85 89.8 1.00000 Jan-86 Feb-86 Mar-86 90.8 1.01114 Apr-86 May-86 Jun-86 91.2 1.01559 JUI-86 Aug-86 Sep-86 91.6 1.02004 Oct-86 Nov-86 Dec-86 92.5 1.03007 Jan-87 Feb-87 Mar-87 92.6 1.03118 Apr-87 May-87 Jun-87 93.7 1.04343 Jul-87 Aug-87 Sep-87 94.1 1.04788 Oct-87 Nov-87 Dec-87 95.4 1.06236 Jan-88 Feb-88 Mar-88 96.3* 1.07238 Apr-88 May-88 Jun-88 97 1.08018 JUI-88 Aug-88 Sep-88 97.7 1.08797 Oct-88 Nov-88 Dec-88 98.8 1.10022 Jan-89 Feb-89 Mar-89 100 1.11359 Apr-89 Page 1 of9

Enclosure 2 PG&E Letter DCL-13-033 Development of L Component Calculation of Labor Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.1 Using Regional Indices Series ID: CIU20100000002401 (as of 03/02/11)

January 1986 adjusted to reflect NUREG 1307, Revision 14, Scaling Factor for West Labor (Page 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-85 89.8 1.00000 May-89 Jun-89 101 1.12472 Jul-89 Aug-89 Sep-89 101.8 1.13363 Oct-89 Nov-89 Dec-89 103.3 1.15033 Jan-90 Feb-90 Mar-90 104.5 1.16370 Apr-90 May-90 Jun-90 105.6 1.17595 Jul-90 Aug-90 Sep-90 106.3 1.18374 Oct-90 Nov-90 Dec-90 107.5 1.19710 Jan-91 Feb-91 Mar-91 108.9 1.21269 Apr-91 May-91 Jun-91 110 1.22494 JUI-91 Aug-91 Sep-91 110.9 1.23497 Oct-91 Nov-91 Dec-91 111.9 1.24610 Jan-92 Feb-92 Mar-92 112.9 1.25724 Apr-92 May-92 Jun-92 114.1 1.27060 JUI-92 Aug-92 Page 2 of 9

Enclosure 2 PG&E Letter DCL-13-033 Development of L Component Calculation of Labor Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.1 Using Regional Indices Series 10: CIU20100000002401 (as of 03/02/11)

January 1986 adjusted to reflect NUREG 1307, Revision 14, Scaling Factor for West Labor (Page 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-85 89.8 1.00000 Sep-92 114.9 1.27951 Oct-92 Nov-92 Dec-92 116.2 1.29399 Jan-93 Feb-93 Mar-93 116.4 1.29621 Apr-93 May-93 Jun-93 117.8 1.31180 JUI-93 Aug-93 Sep-93 118.1 1.31514 Oct-93 Nov-93 Dec-93 119.4 1.32962 Jan-94 Feb-94 Mar-94 120.5 1.34187 Apr-94 May-94 Jun-94 121.3 1.35078 Jul-94 Aug-94 Sep-94 121.7 1.35523 Oct-94 Nov-94 Dec-94 122.6 1.36526 Jan-95 Feb-95 Mar-95 123.4 1.37416 Apr-95 May-95 Jun-95 123.9 1.37973 Jul-95 Aug-95 Sep-95 125 1.39198 Oct-95 Nov-95 Dec-95 125.9 1.40200 Page 3 of 9

Enclosure 2 PG&E Letter DCL-13-033 Development of L Component Calculation of Labor Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.1 Using Regional Indices Series ID: CIU20100000002401 (as of 03/02/11)

January 1986 adjusted to reflect NUREG 1307, Revision 14, Scaling Factor for West Labor (Page 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-85 89.8 1.00000 Jan-96 Feb-96 Mar-96 127.3 1.41759 Apr-96 May-96 Jun-96 128.3 1.42873 Jul-96 Aug-96 Sep-96 128.9 1.43541 Oct-96 Nov-96 Dec-96 130.3 1.45100 Jan-97 Feb-97 Mar-97 131.4 1.46325 Apr-97 May-97 Jun-97 132.5 1.47550 Jul-97 Aug-97 Sep-97 133.4 1.48552 Oct-97 Nov-97 Dec-97 135.2 1.50557 Jan-98 Feb-98 Mar-98 136.6 1.52116 Apr-98 May-98 Jun-98 138.5 1.54232 Jul-98 Aug-98 Sep-98 140 1.55902 Oct-98 Nov-98 Dec-98 140.3 1.56236 Jan-99 Feb-99 Mar-99 142.1 1.58241 Apr-99 Page 4 of 9

Enclosure 2 PG&E Letter DCL-13-033 Development of L Component Calculation of Labor Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.1 Using Regional Indices Series ID: CIU20100000002401 (as of 03/02/11)

January 1986 adjusted to reflect NUREG 1307, Revision 14, Scaling Factor for West Labor (Page 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-85 89.8 1.00000 May-99 Jun-99 143.3 1.59577 Jul-99 Aug-99 Sep-99 144.7 1.61136 Oct-99 Nov-99 Dec-99 147 1.63697 Jan-OO Feb-OO Mar-OO 148.8 1.65702 Apr-OO May-OO Jun-OO 150.8 1.67929 Jul-OO Aug-OO Sep-OO 151.8 1.69042 Oct-OO Nov-OO Dec-OO 84.1 0.93653 Jan-01 Feb-01 Mar-01 85 0.94655 Apr-01 May-01 Jun-01 85.9 0.95657 Jul-01 Aug-01 Sep-01 86.9 0.96771 Oct-01 Nov-01 Dec-01 87.4 0.97327 Jan-02 Feb-02 Feb-02 Mar-02 88.5 0.98552 Apr-02 May-02 Jun-02 89.1 0.99220 Jul-02 Page 5 of 9

Enclosure 2 PG&E Letter DCL-13-033 Development of L Component Calculation of Labor Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.1 Using Regional Indices Series 10: CIU20100000002401 (as of 03/02/11)

January 1986 adjusted to reflect NUREG1307, Revision 14, Scaling Factor for West Labor (Page 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-85 89.8 1.00000 Aug-02 Sep-02 89.8 1.00000 Oct-02 Nov-02 Dec-02 90.9 1.01225 Jan-03 Feb-03 Mar-03 92 1.02450 Apr-03 May-03 Jun-03 93.2 1.03786 Jul-03 Aug-03 Sep-03 93.8 1.04454 Oct-03 Nov-03 Dec-03 95.3 1.06125 Jan-04 Feb-04 Mar-04 96.2 1.07127 Apr-04 May-04 Jun-04 96.9 1.07906 Jul-04 Aug-04 Sep-04 97.4 1.08463 Oct-04 Nov-04 Dec-04 98.4 1.09577 Jan-05 Feb-05 Mar-05 99.3 1.10579 Apr-05 May-05 Jun-05 99.7 1.11024 Jul-05 Aug-05 Sep-05 (Note 1) 100 2.06000 Oct-05 Nov-05 Page 6 of 9

Enclosure 2 PG&E Letter DCL-13-033 Development of L Component Calculation of Labor Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.1 Using Regional Indices Series 10: CIU20100000002401 (as of 03/02/11)

January 1986 adjusted to reflect NUREG 1307, Revision 14, Scaling Factor for West Labor (Page 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-85 89.8 1.00000 Dec-05 100.6 2.07236 Jan-06 Feb-06 Mar-06 101.8 2.09708 Apr-06 May-06 Jun-06 102.5 2.11150 Jul-06 Aug-06 Sep-06 103 2.12180 Oct-06 Nov-06 Dec-06 104.2 2.14652 Jan-07 Feb-07 Mar-07 104.9 2.16094 Apr-07 May-07 Jun-07 105.7 2.17742 Jul-07 Aug-07 Sep-07 106.5 2.19390 Oct-07 Nov-07 Dec-07 107.8 2.22068 Jan-08 Feb-08 Mar-08 108.4 2.23304 Apr-08 May-08 Jun-08 109.3 2.25158 Jul-08 Aug-08 Sep-08 109.4 2.25364 Oct-08 Nov-08 Dec-08 109.9 2.26394 Jan-09 Feb-09 Mar-09 110.0 2.26600 Page 7 of 9

Enclosure 2 PG&E Letter DCL-13-033 Development of L Component Calculation of Labor Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.1 Using Regional Indices Series 10: CIU20100000002401 (as of 03/02/11)

January 1986 adjusted to reflect NUREG 1307, Revision 14, Scaling Factor for West Labor (Page 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-85 89.8 1.00000 Apr-09 May-09 Jun-09 110.3 2.27218 Jul-09 Aug-09 Sep-09 110.6 2.27836 Oct-09 Nov-09 Dec-09 111.4 2.29484 Jan-10 Feb-10 Mar-10 111.7 2.30102 Apr-10 May-10 Jun-10 112.3 2.31338 Jul-10 Aug-10 Sep-10 112.3 2.31338 Oct-10 Nov-10 Dec-10 112.5 2.31750 Jan-11 Feb-11 Mar-11 113.5 2.33810 Apr-11 May-11 Jun-11 114.3 2.35458 Jul-11 Aug-11 Sep-11 114.6 2.36076 Oct-11 Nov-11 Dec-11 115.1 2.37106 Jan-12 Feb-12 Mar-12 115.7 2.38342 Apr-12 May-12 Jun-12 116.3 2.39578 JUI-12 Page 8 of 9

Enclosure 2 PG&E Letter DCL-13-033 Development of L Component Calculation of Labor Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.1 Using Regional Indices Series 10: CIU20100000002401 (as of 03/02/11)

January 1986 adjusted to reflect NUREG 1307, Revision 14, Scaling Factor for West Labor (Page 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-85 89.8 1.00000 Aug-12 Sep-12 116.9 2.40814 Oct-12 Nov-12 Dec-12 116.9 2.40814 Page 9 of9

Enclosure 2 PG&E Letter DCL-13-033 Development of B Component Development of Burial Escalation Developed from NUREG-1307, Revision 14 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 11.3433 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 26.262 15.6505 2010 27.292 16.2646 2011 28.937 17.2446 2012 30.581 18.2247 2013 32.225 19.2044 Table 2.1 Note (e): Bx values for the generic site are assumed to be the same as that provided for the Atlantic Compact for lack of a better alternative at this time.

Note (f): Effective with NUREG-1307, Revision 8 (Reference3) an alternative disposal option was introduced in which the bulk of the LLW is assumed to be dis positioned by waste vendors and/or disposed of at a non-compact disposal facility.

Note (g): Effective with NUREG1307, Revision 15, the nomenclature for the two disposal options, referred to as "Direct Disposal" and "Direct Disposal with Vendors" in previous revisions of NUREG-1307, is changed to "Compact-Affiliated Disposal.

Facility Only" and "Combination of Comapct-Affiliated and Non-Compact Disposal Facilities" to better describe the options.

2013 has no information in NUREG-1307 Revision 15. 2013 is an estimate that is calculated by applying the average percent by applying the average percent change between 2010 and 2012 and adding to the 2012 base.

Page 1 of 1

Enclosure 3 PG&E Letter DCL-13-033 Table C-1 Diablo Canyon Power Plant Unit 1 Decon Decommissioning Cost Estimate (7 pages)

Table C-2 Diablo Canyon Power Plant Unit 2 Decon Decommissioning Cost Estimate (8 pages)

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E letter DCL-13-033 Document P01-1648-001, Rev. 0 Table C-l Table C-1 Appendix C1, Page 1 Of 7 Diablo Canyon Unit 1 Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Site Off-Site LLRW NRC Spent Fuel Site Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Index Activity Descri tion Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs PERIOD 1a - Shutdown through Transition Period 1a Direct Decommissioning Activities 1a.L1 Prepare preliminary decommissioning cost 191 41 232 232 200 43 242 242.275 1a.L2 Notification of Cessation of Operations a 1a.L3 Remove fuel & source material nla 1a.L4 Notification of Permanent Defueling 1a.L5 Deactivate plant systems & process waste a 1a.L6 Prepare and submit PSDAR 294 63 357 357 307 65 373 372.731 1a.L7 Review plant dwgs & specs. 676 144 820 820 707 150 857 857.281 1a.L8 Perform detailed rad survey a 1a.L9 Estimate by*product inventory 147 31 178 178 154 33 186 186.365 1a.L10 End product description 147 31 178 178 154 33 186 186.365 1a.L11 Detailed by*product inventory 191 41 232 232 200 43 242 242.275 1a.L12 Define major work sequence 1,103 235 1,337 1,337 1,152 245 1,398 1,397.741 1a.L13 Perform SER and EA 456 97 553 553 476 101 578 577.733 1a.L14 Perform Site*Specific Cost Study 735 156 891 891 768 164 932 931.827 1a.L15 Prepare/submit License Termination Plan 602 128 730 730 629 134 763 763.353 1a.L16 Receive NRC approval of termination plan a Activity Specifications 1a.L17.1 Plant & temporary facilities 723 154 877 789 88 756 161 917 825.226 91.692 1a.L17.2 Plant systems 613 130 743 669 74 640 136 777 698.876 77.653 1a.L17.3 NSSS Decontamination Flush 74 16 89 89 77 16 93 93.183 1a.L17.4 Reactor internals 1,044 222 1,266 1,266 1,091 232 1,323 1,323.195 1a.L17.5 Reactor vessel 956 203 1,159 1,159 999 213 1,211 1,211.375 1a.L17.6 Biological shield 74 16 89 89 77 16 93 93.183 1a.L17.7 Steam generators 459 98 556 556 479 102 581 581.460 1a.L17.8 Reinforced concrete 235 50 285 143 143 246 52 298 149.092 149.092 1a.L17.9 Main Turbine 59 13 71 71 61 13 75 74.546 1a.L17.1O Main Condensers 59 13 71 71 61 13 75 74.546 1a.1.17.11 Plant structures & buildings 459 98 556 278 278 479 102 581 290.730 290.730 1a.1.17.12 Waste management 676 144 820 820 707 150 857 857.281 1a.1.17.13 Facility & site closeout 132 28 160 80 80 138 29 168 83.864 83.864 la.L17 Total 5,561 1,184 6,744 5,938 806 5,812 1,237 7,050 6,207.466 842.124 Planning & Site Preparations la.l.18 Prepare dismantling sequence 353 75 428 428 369 78 447 447.277 la.l.19 Plant prep. & temp. svces 2,800 596 3,396 3,396 2,927 623 3,550 3,549.818 1a.l.20 Design water clean*up system 206 44 250 250 215 46 261 260.912 la.1.21 Rigging/Cont. Cntrl Envlps/tooling/etc. 2,200 468 2,668 2,668 2,300 489 2,789 2,789.143 la.1.22 Procure caskslliners & containers 181 38 219 219 189 40 229 229.229 la.1 Subtotal Period la Activity Costs 15,842 3,372 19,214 18,408 806 16,559 3,525 20,084 19,241.791 842.124 Period 1a Additional Costs 1a.2.1 Spent Fuel Pool Isolation 19,825 4,220 24,045 24,045 20,723 4,411 25,134 25,134.244 1a.2.2 Disposal of Contaminated Tools & Equipment 234 97 3,145 1,170 4,646 4,646 245 101 3,623 1,223 5,192 5,191.554 1a.2 Subtotal Period 1a Additional Costs 234 97 3,145 19,825 5,389 28,691 28,691 245 101 3,623 20,723 5,633 30,326 30,325.798 Period la Period*Dependent Costs la.4.1 Insurance 1,056 150 1,205 1,205 1,103 157 1,260 1,260.001 la.4.2 Property taxes 165 23 189 189 173 25 198 197.539 la.4.3 Health physics supplies 485 172 657 657 507 180 687 687.091 1a.4.4 Heavy equipment rental 480 102 582 582 501 107 608 607.979 1a.4.5 Disposal ofDAW generated 15 4 49 21 89 89 16 56 21 99 98.604 1a.4.6 Plant energy budget 1,156 246 1,402 1,402 1,209 257 1,466 1,465.973 1a.4.7 NRC Fees 1,177 167 1,344 1,344 1,231 175 1,405 1,405.380 1a.4.8 Emergency Planning Fees 1,001 142 1,143 1,143 1,047 149 1,195 1,195.198 1a.4.9 Spent Fuel Pool O&M 763 162 926 926 798 170 968 967.515 1a.4.10 ISFSI Operating Costs 45 10 54 54 47 10 57 56.705 1a.4.11 Severance Related Costs 35,456 7,547 43,002 43,002 37,062 7,889 44,950 44,950.419 1a.4.12 Spent Fuel Storage Canisters/Overpacks 7)353 1,565 8,919 8,919 7,687 1,636 9,323 9,322.615 1a.4.13 Security Staff Cost 14,837 3,158 17,995 17,995 15,509 3,301 18,810 18,810.143 1a.4.14 Utility Staff Cost 33,000 7,024 40,024 40,024 34,495 7,342 41,837 41,837.165 1a.4 Subtotal Period 1a Period*Dependent Costs 965 15 4 49 96,010 20,489 117,533 106,491 11,042 1,008 16 56 100,359 21,417 122,862 111,320.294 11,542.032 1a.0 TOTAL PERIOD 1a COST 965 249 101 3,194 131,677 29,250 165,437 153,590 11,042 806 1,008 261 106 3,679 137,642 30,575 173,272 160,887.884 11,542.032 842.124 PERIOD 1b - Decommissioning Preparations Period 1b DiI'ect Decommissioning Activities Detailed Work Procedures 1b.1.1.1 Plant syslems 696 148 844 759 84 727 155 882 793.861 88.207 1b.1.1.2 NSSS Decontamination Flush 147 31 178 178 154 33 186 186.365 1b.1.1.3 Reactor internals 368 78 446 446 384 82 466 465.914 1b.1.1.4 Remaining buildings 198 42 241 60 181 207 44 252 62.898 188.695 1b.1.1.5 CRD cooling assembly 147 31 178 178 154 33 186 186.365 lb. 1. 1.6 CRD housings & ICI tubes 147 31 178 178 154 33 186 186.365 1b.1.1.7 Incore instrumentation 147 31 178 178 154 33 186 186.365 1b.1.1.8 Reactor vessel 534 114 647 647 558 119 677 676.507 1b .1.1.9 Facility closeout 176 38 214 107 107 184 39 224 111.819 111.819 TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E Letter DCL-13-033 Document P01-1648-001, Rev. 0 Table C-l Table C-1 Appendix C1, Page 2 Of 7 Diablo Canyon Unit 1 Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Site Off-Site LLRW NRC Spent Fuel Site Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Index Activit Cost Cost Costs Costs Costs Costs Costs Contin enc' Costs Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin ency Costs Costs Costs Costs 1b.Ll.10 Missile shields 66 14 80 80 69 15 84 83.864 1b.Ll.ll Biological shield 176 38 214 214 184 39 224 223.639 Ib.I.Ll2 Steam generators 676 144 820 820 707 150 857 857.281 Ib.I.Ll3 Reinforced concrete 147 31 178 89 89 154 33 186 93.183 93.183 Ib.l.Ll4 Main Turbine 229 49 278 278 240 51 291 290.730 Ib.l.Ll5 Main Condensers 229 49 278 278 240 51 291 290.730 Ib.l.l.16 Auxiliary building 401 85 487 438 49 419 89 509 457.900 50.878 Ib.l.l.17 Reactor building 401 85 487 438 49 419 89 509 457.900 50.878 Ib.Ll Total 4,887 1,040 5,927 4,812 1,115 5,108 1,087 6,195 5,030.227 1,165.120 Ib.1.2 Decon primary loop 750 532 1,283 1,283 784 556 1,341 1,340.806 1b.1 Subtotal Period 1b Activity Costs 750 4,887 1,573 7,210 6,095 1,115 784 5,108 1,644 7,536 6,371.033 1,165.120 Period 1b Additional Costs 1b.2.1 Site Characterization 4,765 2,029 6,794 6,794 4,981 2,120 7,101 7,101.355 1b.2.2 Hazardous Waste Management 204 43 247 247 213 45 259 258.630 1b.2.3 Mixed Waste Management 270 57 327 327 282 60 342 342.304 1b.2 Subtotal Period 1b Additional Costs 5,239 2,129 7,368 7,368 5,476 2,226 7,702 7,702.289 Period 1b Collateral Costs 1b.3.1 Decon equipment 931 198 1,129 1,129 973 207 1,180 1,179.852 1b.3.2 DOC staff relocation expenses 1,415 301 1,716 1,716 1,479 315 1,793 1,793.397 1b.3.3 Process decommissioning water waste 46 21 66 88 81 302 302 48 22 69 101 85 325 325.126 1b.3A Process decommissioning chemical flush waste 63 256 6,210 2,267 8,797 8,797 2 65 267 7,154 2,370 9,858 9,858.305 1b.3.5 Small tool allowance 1 3 3 1 3 30408 1b.3.6 Pipe cutting equipment 1,100 234 1,334 1,33,1 1,150 245 1,395 1,394.571 1b.3.7 Decon rig 1,500 319 1,819 1,819 1,568 334 1,902 1,901.688 1b.3.8 Spent Fuel Transfer - Pool to ISFSI 1,989 423 2,412 2,412 2,079 443 2,522 2,521.691 1b.3 Subtotal Period 1b Collateral Costs 2,479 1,103 84 321 6,298 3,404 3,825 17,513 15,100 2,412 2,591 1,153 88 336 7,255 3,558 3,998 18,978 16,456.348 2,521.691 Period 1b Period-Dependent Costs 1bA.1 Decon supplies 28 10 38 38 29 10 40 39.899 1bA.2 Insurance 523 74 598 598 547 78 625 624.822 1bA.3 Property taxes 82 12 94 94 86 12 98 97.958 1bAA Health physics supplies 269 96 365 365 282 100 381 381.488 1bA.5 Heavy equipment rental 238 51 288 288 249 53 301 301.491 1bA.6 Disposal of DAW generated 9 28 12 52 52 33 12 57 57.303 1bA.7 Plant energy budget 1,147 244 1,391 1,391 1,199 255 1,454 1,453.924 1bA.8 NRC Fees 346 49 395 395 361 51 413 412.710 1bA.9 Emergency Planning Fees 497 70 567 567 519 74 593 592.687 1bA.1O Spent Fuel Pool O&M 378 81 459 459 396 84 480 479.781 1bA.ll ISFSI Operating Costs 22 5 27 27 23 5 28 28.119 1b.4.12 Severance Related Costs 5,351 1,139 6,490 6,490 5,594 1,191 6,784 6,784.275 1bA.13 Spent Fuel Storage Canisters/Overpacks 7,347 1,564 8,911 8,911 7,680 1,635 9,315 9,314.974 IbA.14 Security Staff Cost 7,357 1,566 8,924 8,924 7,691 1,637 9,328 9,327.769 IbA.15 DOC Staff Cost 6,563 1,397 7,960 7,960 6,860 1,460 8,320 8,320.136 1b.4.16 Utility Staff Cost 16,460 3,504 19,963 19,963 17,206 3,662 20,868 20,867.807 1bA Subtotal Period 1b Period-Dependent Costs 28 507 28 46,074 9,872 56,522 46,557 9,964 29 530 33 48,161 10,319 59,085 48,669.583 10,415.561 1b.0 TOTAL PERIOD 1b COST 3,257 1,610 93 324 6,326 59,604 17,399 88,612 75,121 12,377 1,115 3,405 1,683 97 339 7,288 62,304 18,187 93,302 79,199.253 12,937.252 1,165.120 PERIOD 1 TOTALS 3,257 2,575 342 425 9,520 191,280 46,649 254,049 228,711 23,418 1,920 3,405 2,691 358 445 10,967 199,945 48,763 266,574 240,087.136 24,479.284 2,007.244 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.1 Reactor Coolant Piping 370 354 52 40 1,342 880 3,038 3,038 386 370 54 42 1,546 920 3,319 3,318.819 2a.1.1.2 Pressurizer Quench Tank 39 35 8 6 189 110 387 387 41 37 8 6 217 115 424 424.373 2a.1.1.3 Reactor Coolant Pumps & Motors 118 126 103 185 1,443 694 2,669 2,669 123 132 108 193 1,663 726 2,944 2,944.148 2a.1.1A Pressurizer 50 70 448 114 750 414 1,846 1,846 53 73 468 119 864 433 2,010 2,010.016 2a.1.1.5 Steam Generators 477 4,206 3,368 1,922 12,807 7,260 30,039 30,039 498 4,397 3,520 2,009 14,753 7,589 32,766 32,765.969 2a.1.1.6 Retired Steam Generator Units 2,496 1,878 12,597 5,223 22,194 22,194 2,609 1,963 14,512 5,459 24,543 24,543.070 2a.1.1.7 CRDMslICIs/Service Structure Removal 196 112 262 37 444 381 1,433 1,433 205 117 274 39 511 399 1,545 1,544.887 2a.1.1.8 Reactor Vessel Internals 175 3,110 14,996 1,468 10,438 283 16,741 47,212 47,212 183 3,251 15,675 1,535 12,025 296 17,499 50,464 50,464.306 2a.1.1.9 Reactor Vessel 122 5,226 2,439 742 2,651 283 8,718 20,181 20,181 127 5,463 2,549 776 3,054 296 9,113 21,378 21,3780442 2a.1.1 Totals 1,546 13,241 24,170 6,392 42,661 567 40,422 128,998 128,998 1,616 13,840 25,265 6,681 49,146 592 42,253 139,394 139,394.030 Removal of Major Equipment 2a.1.2 Main Turbine/Generator 202 43 245 245 211 45 256 2560499 2a.1.3 Main Condensers 668 142 810 810 698 149 847 847.009 Cascading Costs from Clean Building Demolition 2a.1.4.1 *Reactor 1,194 254 1,448 1,448 1,248 266 1,513 1,513.285 2a.1.4.2 Containment Penetration Area 73 16 89 89 77 16 93 92.930 2a.1.4.3 Fuel Handling 193 41 234 234 202 43 245 244.662 2a.1.4 Totals 1,460 311 1,771 1,771 1,526 325 1,851 1,850.877 Disposal of Plant Systems 2a.1.5.1 Auxiliary Steam 148 31 179 179 154 33 187 187.042 2a.1.5.2 Auxiliary Steam (RCA) 277 61 19 652 342 1,351 1,351 289 64 20 751 358 1,482 1,482.297 2a.1.5.3 Condensate System 679 145 824 824 710 151 861 860.998 2a.1.5A Condensate System (Insulated) 281 60 341 341 294 63 357 356.810 TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E letter DCl-13-033 Document P01-1648-001, Rev. 0 Table C-l Table C-1 Appendix C1, Page 3 Of 7 Diablo Canyon Unit 1 Diablo Canyon Unit 1 DECON Deconunissioning Cost Estimate DECON Deconunissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Site Off-Sitc LLRW NRC Spent 'Fuel Site Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Index Activity Descri tion Cost Cost Costs Costs Costs Costs Costs Contin cncy Costs Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs 2a.1.5.5 Containment Spray 249 167 53 1,786 757 3,011 3,011 261 174 55 2,057 791 3,338 3,338.397 2a.1.5.6 Extraction Steam & Heater Drip 263 56 318 318 274 58 333 332.880 2a.1.5.7 Feedwater System 46 10 56 56 48 10 58 58.022 2a.1.5.8 Feedwater System (Insulated) 168 36 204 204 176 37 214 213.608 2a.1.5.9 Feedwater System (RCA Insulated) 126 43 15 506 234 923 923 132 45 16 583 244 1,019 1,019.130 2a.1.5.10 Feedwater System (RCA) 6 27 12 48 48 6 31 13 53 52.873 2a.1.5.1l Lube Oil Distribution & Purification 115 25 140 140 120 26 146 146.028 2a.1.5.12 Nitrogen & Hydrogen 20 4 24 24 21 4 25 25.054 2a.1.5.13 Nitrogen & Hydrogen (Insulated) o 1 1 1 o 1 1.319 2a.1.5.14 Nitrogen & Hydrogen (RCA Insulated) 4 16 16 6 o 17 17.347 2a.1.5.15 Nitrogen & Hydrogen (RCA) 110 12 102 78 305 305 115 13 3 118 81 330 329.598 2a.1.5.16 Oily Water Separator & TB Sump 37 12 157 72 282 282 39 13 5 180 75 312 311.866 2a.1.5.17 Saltwater System 190 41 231 231 199 42 241 241.356 2a.1.5.18 Turbine Steam Supply 759 161 920 920 793 169 962 961.902 2a.1.5.19 Turbine Steam Supply (RCA) 862 335 112 3,799 1,725 6,833 6,833 901 350 117 4,377 1,803 7,548 7,547.512 2a.1.5.20 Turbine and Generator 80 17 98 98 84 18 102 102.003 2a.1.5.21 Turbine and Generator (Insulated) 26 6 32 32 28 6 34 33.592 2a.1.5 Totals 4,450 633 207 7,034 3,814 16,138 12,770 3,368 4,652 661 217 8,103 3,987 17,620 14,099.021 3,520.615 2a.1.6 Scaffolding in support of decommissioning 2,465 113 917 3,509 3,509 2,577 10 130 958 3,680 3,680.347 2a.1 Subtotal Period 2a Activity Costs 1,546 22,486 24,812 6.604 49,808 567 45,648 151,472 147,048 4,424 1,616 23,505 25,936 6,903 57,379 592 47,716 163,648 159,024.276 4,624.123 Period 2a Additional Costs 2a.2.1 Retired Reactor Head 225 179 1,557 622 2,583 2,583 235 187 1,794 651 2,866 2,866.226 2a.2 Subtotal Period 2a Additional Costs 225 179 1,557 622 2,583 2,583 235 187 1.794 651 2.866 2,866.226 Period 2a Collateral Costs 2a.3.1 Process decommissioning water waste 84 40 122 163 149 558 558 88 41 128 188 156 600 600.230 2a.3.2 Process decommissioning chemical flush waste 2a.3.3 Small tool allowance 287 61 348 313 35 300 64 364 327.556 36.395 2a.3.4 Spent Fuel Transfer - Pool to ISFSI 9,666 2,057 11,723 11,723 10,104 2,151 12,254 12,254.166 2a.3 Subtotal Period 2a Collateral Costs 84 287 40 122 163 9,666 2,267 12,629 871 11,723 35 88 300 41 128 188 10,104 2,370 13,218 927.786 12,254.166 36.395 Period 2a Period-Dependent Costs 2a.4.1 Decon supplies 92 32 124 124 96 34 130 129.618 2a.4.2 Insurance 765 109 873 873 800 113 913 913.055 2a.4.3 Property taxes 267 38 304 274 30 279 40 318 286.405 31.823 2a.4.4 Health physics supplies 1,863 661 2,523 2,523 1,947 691 2,638 2,637.606 2a.4.5 Heavy equipment rental 3,362 716 4,077 4,077 3,514 748 4,262 4,261.904 2a.4.6 Disposal ofDAW generated 96 27 305 127 555 555 101 28 351 133 613 613.046 2a.4.7 Plant energy budget 1,770 377 2,146 2,146 1,850 394 2,244 2,243.542 2a.4.8 NRC Fees 1,022 145 1,167 1,167 1,068 152 1,220 1,220.081 2a.4.9 Emergency Planning Fees 1,152 163 1,315 1,315 1,204 171 1,375 1,374.882 2a.4.10 Spent Fuel Pool O&M 1,229 262 1,491 1,491 1,285 274 1,559 1,558.626 2a.4.1l ISFSI Operating Costs 72 15 87 87 75 16 91 91.349 2a.4.12 Severance Related Costs 3,173 675 3,848 3,848 3,317 706 4,023 4,022.623 2a.4.13 Spent Fuel Storage Canisters/Overpacks 20,381 4,338 24,720 24,720 21,305 4,535 25,839 25,839.340 2a.4.14 Security Staff Cost 23,902 5,087 28,989 28,989 24,984 5,318 30,302 30,302.363 2a.4.15 DOC Staff Cost 26,041 5,543 31,584 31,584 27,221 5,794 33,015 33,015.006 2a.4.16 Utility Staff Cost 36,803 7,834 44,636 44,636 38,470 8,188 46,658 46,658.452 2a.4 Subtotal Period 2a Period-Dependent Costs 92 5,224 96 27 305 116,577 26,122 148,443 120,799 27,613 30 96 5,461 101 28 351 121,858 27,306 155,200 126,303.700 28,864.197 31.823 2a.0 TOTAL PERIOD 2a COST 1,722 27,997 25,173 6,932 51,833 126,809 74,660 315,127 271,302 39,336 4,489 1,800 29,266 26,313 7,246 59,712 132,554 78,043 334,933 289,121.988 41,118.363 4,692.341 PERIOD 2b - Site Decontamination Period 2b Direct Decommissioning Activities Disposal of Plant Systems 2b.1.1.1 Capital Additions 85-2002 (clean) 182 39 220 220 190 40 230 230.400 2b.1.1.2 Capital Additions 85-2002 (contaminated) 485 54 19 635 409 1,603 1.603 507 57 20 732 428 1,743 1,743.017 2b.1.1.3 Chemical & Volume Control 875 1.229 197 67 2,277 1,907 6,551 6.551 914 1,285 205 70 2,623 1.993 7,091 7.091.212 2b.1.1.4 Chemical & Volume Control (Insulated) 324 465 50 14 466 570 1.887 1,887 338 486 52 14 536 595 2.022 2,022.032 2b.1.1.5 Component Cooling Water 196 42 237 237 205 44 248 248.194 2b.1.1.6 Component Cooling Water (RCA) 617 194 67 2,260 1,063 4,201 4,201 645 203 70 2,604 1,111 4,632 4,632.046 2b.1.1.7 Compressed Air 174 37 211 211 182 39 221 220.968 2b.1.1.8 Compressed Air (Insulated) 6 1 7 6 1 8 7.838 2b.1.1.9 Compressed Air (RCA Insulated) 29 1 31 22 87 87 30 4 1 36 23 94 94.082 2b.1.1.10 Compressed Air (RCA) 534 67 18 595 414 1,626 1,626 558 70 18 685 432 1,764 1,763.614 2b.1.1.1l Diesel Engine-Generator 179 38 217 217 187 40 227 227.013 2b.1.1.12 Diesel Engine-Generator (Insulated) 11 2 14 14 12 2 14 14.210 2b.1. 1.13 Electrical (Clean) 2,130 453 2,584 2,584 2,227 474 2,701 2,700.862 2b.1.1.14 Electrical (Contaminated) 633 91 38 1,275 698 2,735 2,735 661 96 39 1,469 730 2,995 2,995.292 2b.1.1.15 Electrical (Decontaminated) 3,324 708 4,032 4,032 3,475 740 4,214 4,214.453 2b.1.1.16 Fire Protection 386 147 54 1,820 815 3,222 3,222 404 154 56 2,097 852 3,562 3,562.131 2b.1.1.17 Gaseous Radwaste 88 10 3 91 66 258 258 92 11 3 105 69 280 279.865 2b.1.1.18 HVAC (Clean Insulated) 29 6 35 35 30 6 36 36.336 2b.1.1.19 HVAC (Clean) 372 79 451 451 388 83 471 471.120 2b.1.1.20 HVAC (Contaminated Insulated) 309 55 22 733 382 1,501 1,501 323 57 23 845 399 1,647 1,646.983 2b.1.1.21 HVAC (Contaminated) 1,372 272 108 3,662 1,848 7,262 7,262 1,434 285 113 4,219 1,931 7,982 7,981.659 2b.1.1.22 Liquid Radwaste 582 785 116 38 1,283 1,171 3,973 3,973 608 820 121 40 1,478 1,224 4,290 4,290.085 2b.1.1.23 Liquid Radwaste (Insulated) 69 86 10 3 91 114 372 372 72 90 10 3 105 119 399 399.053 2b.1.1.24 Make-up Water 360 77 437 437 376 80 457 456.552 TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E Letter DCL-13-033 Document P01-1648-001 , Rev. 0 Table C-l Table C-1 Appendix C1, Page 4 Of 7 Diablo Canyon Unit 1 Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars) o ff-Site LLRW NRC Spent Fuel Site Off-Site LLRW NRC Spent Fucl Site Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term, Management Restoration Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs 2b.1.1.25 Make-up Water (Insulated) 33 40 40 34 41 41.375 2b.1.1.26 Make-up Water (RCA Insulated) 44 8 2 81 46 182 182 46 8 2 93 48 199 198.951 2b.1.1.27 Make-up Water (RCA) 237 46 14 459 256 1,012 1,012 248 48 14 529 268 1,107 1,106.536 2b.1.1.28 Miscellaneous Reactor Coolant 21 137 17 5 155 121 455 455 21 143 17 5 179 127 492 491.708 2b.1.1.29 Nuclear Steam Supply Sampling 182 13 4 141 117 457 457 190 14 4 162 123 493 493.234 2b.1.1.30 Nuclear Steam Supply Sampling (Insulated 55 2 1 19 27 103 103 58 2 1 21 28 110 109.973 2b.1.1.31 Residual Heat Removal 319 336 165 55 1,873 1,045 3,793 3,793 333 351 172 58 2,158 1,092 4,165 4,164.679 2b.1.1.32 Safety Injection 128 22 245 137 538 538 134 23 8 282 143 589 588.967 2b.1.1.33 Safety Injection (Insulated) 6 1 o 11 6 24 24 1 o 12 6 27 26.629 2b.1.l.34 Safety Injection (RCA Insulated) 42 9 3 95 50 198 198 43 9 3 109 53 217 217.469 2b.1.1.35 Safety Injection (RCA) 350 80 25 854 444 1,753 1,753 366 84 26 984 464 1,924 1,923.642 2b.1.1.86 Service Cooling Water 118 25 143 143 123 26 149 149.091 2b.1.1.37 Service Cooling Water (RCA) 30 73 38 149 149 31 2 84 40 164 163.953 2b.1.l Totals 2,188 15,679 1,635 567 19,225 13,278 52,572 43,945 8,628 2,287 16,389 1,710 592 22,147 13,879 57,005 47,986.809 9,018.411 2b.1.2 Scaffolding in support of decommissioning 3,081 12 141 1,146 4,387 4,387 3,221 12 163 1,198 4,600 4,600.434 Decontamination of Site Buildings 2b.1.3.1 "Reactor 958 2,483 1,120 5,645 26,011 12,149 48,366 48,366 1,002 2,596 1,171 5,901 29,964 12,699 53,333 53,332.747 2b.1.3.2 Capital Additions 85-2004 33 27 7 3 96 69 236 236 34 29 8 3 111 72 256 256.462 2b.1.3.3 Containment Penetration Area 327 213 26 28 379 452 1,425 1,425 341 223 27 30 437 472 1,530 1,530.063 2b.1.3 Totals 1,318 2,724 1,153 5,677 26,486 12,669 50,027 50,027 1,378 2,848 1,205 5,934 30,512 13,243 55,119 55,119.273 2b.1 Subtotal Period 2b Activity Costs 3,506 21,484 2,800 6,250 45,852 27,093 106,986 98,358 8,628 3,665 22,458 2,927 6,533 52,822 28,321 116,725 107,312.002 9,412.951 Period 2b Collateral Costs 2b.3.1 Process decommissioning water waste 133 65 199 266 241 904 904 139 68 208 306 252 974 973.623 2b.3.2 Process decommissioning chemical flush waste 3 103 420 782 384 1,692 1,692 3 108 439 901 401 1,853 1,852.615 2b.3.3 Small tool allowance 408 87 495 495 426 91 517 516.961 2b.3.4 Spent Fuel Transfer - Pool to ISFSI 7,355 1,566 8,921 8,921 7,688 1,636 9,325 9,324.785 2b.3 Subtotal Period 2b Collateral Costs 136 408 168 620 1,048 7,355 2,277 12,012 3,091 8,921 143 426 175 648 1,208 7,688 2,380 12,668 3,343.199 9,324.785 Period 2b Period-Dependent Costs 2b.4.1 Decon supplies 796 283 1,079 1,079 832 295 1,128 1,127.827 2b.4.2 Insurance 1,138 162 1,300 1,300 1,190 169 1,359 1,358.713 2b.4.3 Property taxes 397 56 453 453 415 59 474 473.553 2b.4.4 Health physics supplies 2,527 897 3,424 3,424 2,642 937 3,579 3,579.210 2b.4.5 Heavy equipment rental 4,962 1,056 6,018 6,018 5,187 1,104 6,291 6,290.954 2b.4.6 Disposal of DAW generated 104 29 330 138 601 601 109 31 380 144 663 663.328 2b.4.7 Plant energy budget 2,079 443 2,522 2,522 2,173 463 2,636 2,635.740 2b.4.8 NRC Fees 1,521 216 1,737 1,737 1,590 226 1,816 1,815.597 2b.4.9 Emergency Planning Fees 1,714 243 1,957 1,957 1,792 254 2,046 2,045.955 2b.4.10 Spent Fuel Pool O&M 1,829 389 2,219 2,219 1,912 407 2,319 2,319.385 2b.4.11 Liquid Radwaste Processing Equipment/Services 465 99 563 563 486 103 589 588.948 2b.4.12 ISFSI Operating Costs 107 23 130 130 112 24 136 135.936 2b.4.13 Severance Related Costs 7,661 1,631 9,291 9,291 8,008 1,704 9,712 9,711.936 2b.4.14 Spent Fuel Storage Canisters/Overpacks 11,034 2,349 13,383 13,383 11,534 2,455 13,989 13,989.174 2b.4.15 Security Staff Cost 35,568 7,571 43,139 43,139 37,179 7,914 45,093 45,092.805 2b.4.16 DOC Staff Cost 26,233 5,584 31,816 31,816 27,421 5,837 33,257 33,257.357 2b.4.17 Utility Staff Cost 38,925 8,285 47,210 47,210 40,689 8,661 49,349 49,349.125 2b.4 Subtotal Period 2b Period-Dependent Costs 796 7,490 104 29 330 128,671 29,422 166,842 149,153 17,689 832 7,829 109 31 380 134,500 30,755 174,436 155,945.091 18,490.449 2b.0 TOTAL PERIOD 2b COST 4,439 29,382 3,072 6,899 47,230 136,026 58,793 285,840 250,603 26,610 8,628 4,640 30,713 3,211 7,211 54,409 142,188 61,456 303,829 266,600.292 27,815.234 9,412.951 PERIOD 2c - Spent fuel delay prior to SFP decon Period 2c Direct Decommissioning Activities Period 2c Collateral Costs 2c.3.1 Spent Fuel Transfer - Pool to ISFSI 7,990 1,701 9,691 9,691 8,352 1,778 10,130 10,129.745 2c.3 Subtotal Period 2c Collateral Costs 7,990 1,701 9,691 9,691 8,352 1,778 10,130 10,129.745 Period 2c Period-Dependent Costs 2c.4.1 Insurance 3,475 493 3,968 3,968 3,632 515 4,148 4,147.568 2c.4.2 Property taxes 1,211 172 1,383 1,383 1,266 180 1,446 1,445.553 2c.4.3 Health physics supplies 2,437 864 3,301 3,301 2,547 904 3,451 3,450.720 2c.4.4 Disposal ofDAW generated 70 20 220 92 401 401 73 20 253 96 443 442.793 2c.4.5 Plant energy budget 1,692 360 2,053 2,053 1,769 377 2,146 2,145.543 2c.4.6 NRC Fees 2,671 379 3,050 3,050 2,792 396 3,188 3,187.862 2c.4.7 Emergency Planning Fees 5,232 742 5,975 5,975 5,469 776 6,245 6,245.423 2c.4.8 Spent Fuel Transfer - Pool or ISFSI to DOE 12,973 2,761 15,735 15,735 13,561 2,886 16,448 16,447.536 2c.4.9 Spent Fuel Pool O&M 5,585 1,189 6,773 6,773 5,838 1,243 7,080 7,080.088 2c.4.10 Liquid Radwaste Processing Equipment/Services 355 75 430 430 371 79 449 449.460 2c.4.11 ISFSI Operating Costs 327 70 397 397 342 73 415 414.954 2c.4.12 Spent Fuel Storage Canisters/Overpacks 11,985 2,551 14,535 14,535 12,527 2,666 15,194 15,193.905 2c.4.13 Security Staff Cost 108,574 23,110 131,684 131,684 113,492 24,157 137,649 137,649.013 2c.4.14 Utility Staff Cost 8,384 1,785 10,169 10,169 8,764 1,865 10,630 10,629.510 2c.4 Subtotal Period 2c Period-Dependent Costs 2,437 70 20 220 162,464 34,644 199,853 156,438 43,415 2,547 73 20 253 169,823 36,213 208,930 163,548.022 45,381.905 2c.0 TOTAL PERIOD 2c COST 2,437 70 20 220 170,454 36,344 209,544 156,438 53,106 2,547 73 20 253 178,175 37,991 219,060 163,548.022 55,511.650 PERIOD 2d -Decontamination Following Wet Fuel Storage Period 2d Direct Decommissioning Activities TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E Letter DCL-13-033 Document P01-1648-001, Rev. 0 Table C-l Table C-1 Appendix C1, Page 5 Of 7 Diablo Canyon Unit 1 Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Site Off-Site LLRW NRC Spent Fuel Site Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin cnc Costs Costs Costs Costs 2d.1.1 Remove spent fuel racks 585 56 174 36 1,207 896 2,954 2,954 612 59 181 37 1,391 936 3,216 3,216.231 Disposal of Plant Systems 2d.1.2.1 Electrical (Contaminated) - FHB 184 14 6 194 138 536 536 193 15 6 224 144 581 581.018 2d.1.2.2 Electrical (Decontaminated) - FHB 1,165 133 53 1,781 1,075 4,206 4,206 1,218 139 55 2,051 1,124 4,587 4,586.911 2d.1.2.3 Fire Protection (RCA) 250 50 14 471 266 1,052 1,052 261 53 15 543 278 1,150 1,149.807 2d.1.2.4 HVAC (Contaminated)* FHB 326 64 25 838 427 1,680 1,680 341 67 26 965 447 1,845 1,845.423 2d.1.2.5 Spent Fuel Pit Cooling 94 65 21 706 297 1,183 1,183 98 68 22 814 311 1,312 1,311.792 2d.1.2.6 Spent Fuel Pit Cooling - FHB 130 70 23 764 332 1,319 1,319 136 73 24 880 347 1,461 1,460.505 2d.1.2 Totals 2,150 396 140 4,754 2,535 9,976 9,976 2,247 414 147 5,477 2,650 10,935 10,935.457 Decontamination of Site Buildings 2d.1.3.1 Fuel Handling 811 859 63 41 637 1,124 3,534 3,534 848 898 66 43 733 1,174 3,762 3,762.422 2d.1.3 Totals 811 859 63 41 637 1,124 3,534 3,534 848 898 66 43 733 1,174 3,762 3,762.422 2d.1.4 Scaffolding in support of decommissioninr: 616 28 229 877 877 644 33 240 920 920.087 2d.1 Subtotal Period 2d Activity Costs 1,396 3,682 635 218 6,626 4,784 17,342 17,342 1,459 3,849 664 228 7,634 5,001 18,834 18,834.197 Period 2d Additional Costs 2d.2.1 License Termination Survey Planning 800 340 1,140 1,140 836 356 1,192 1,191.806 2d.2 Subtotal Period 2d Additional Costs 800 340 1,140 1,140 836 356 1,192 1,191.806 Period 2d Collateral Costs 2d.3.1 Process decommissioninr: waler waste 34 19 58 77 67 255 255 36 20 61 89 70 275 275.060 2d.3.2 Process decommissioninr: chemical flush waste 2d.3.3 Small tool allowance 84 18 101 101 87 19 106 105.864 2d.3.4 Decommissioninr: Equipment Disposition 155 54 1,828 682 2,718 2,718 162 56 2,105 713 3,036 3,036.144 2d.3 Subtotal Period 2d Collateral Costs 34 84 174 112 1,905 766 3,075 3,075 36 87 181 117 2,195 801 3,417 3,417.068 Period 2d Period-Dependent Costs 2d.4.1 Decon supplies 209 74 283 283 219 78 296 296.076 2d.4.2 Insurance 219 31 250 250 228 32 261 260.873 2d.4.3 Property taxes 76 11 87 87 80 11 91 90.922 2d.4.4 Health physics supplies 443 157 600 600 463 164 627 627.279 2d.4.5 Heavy equipment rental 953 203 1,156 1,156 996 212 1,208 1,207.863 2d.4.6 Disposal ofDAW generated 34 9 106 44 194 194 35 10 122 46 214 213.631 2d.4.7 Plant energy budr:et 213 45 258 258 223 47 270 269.900 2d.4.8 NRC Fees 250 35 285 285 261 37 298 298.233 2d.4.9 Emerr:ency Planninr: Fees 165 23 188 188 172 24 196 196.413 2d.4.10 Spent Fuel Transfer* Pool or ISFSI to DOE 690 147 837 837 722 154 875 875.298 2d.4.11 Liquid Radwaste Processing Equipment/Services 178 38 216 216 186 40 226 226.156 2d.4.12 ISFSI Operating Costs 21 4 25 25 22 5 26 26.100 2d.4.13 Severance Related Costs 9,595 2,042 11,637 11,637 10,030 2,135 12,164 12,164.283 2d.4.14 Security Staff Cost 1,035 220 1,255 1,255 1,082 230 1,312 1,312.072 2d.4.15 DOC Staff Cost 3,363 716 4,Q78 4,078 3,515 748 4,263 4,262.976 2d.4.16 Utility Staff Cost 4,500 958 5,458 5,458 4,704 1,001 5,705 5,705.125 2d.4 Subtotal Period 2d Period-Dependent Costs 209 1,396 34 106 20,304 4,750 26,808 25,757 1,050 219 1,459 35 10 122 21,224 4,965 28,033 26,935.390 1,097.810 2d.0 TOTAL PERIOD 2d COST 1,639 5,161 842 339 8,638 21,103 10,641 48,364 47,314 1,050 1,714 5,395 881 355 9,951 22,059 11,123 51,476 50,378.460 1,097.810 PERIOD 2f - License Termination Period 2fDirect Decommissioning Activities 2£.1.1 ORISE confirmatory survey 178 76 254 254 186 79 265 265.355 2£.1.2 Terminate license a 2£.1 Subtotal Period 2f Activity Costs 178 76 254 254 186 79 265 265.355 Period 2f Additional Costs 2£,2.1 License Termination Survey 9,248 3,937 13,184 13,184 9,666 4,115 13,781 13,781.463 2£.2 Subtotal Period 2f Additional Costs 9,248 3,937 13,184 13,184 9,666 4,115 13,781 13,781.463 Period 2f Collateral Costs 2£.3.1 DOC staffrelocation expenses 1,415 301 1,716 1,716 1,479 315 1,793 1,793.397 2£.3 Subtotal Period 2f Collateral Costs 1,415 301 1,716 1,716 1,479 315 1,793 1,793.397 Period 2fPeriod-Dependent Costs 2£,4.1 Insurance 319 45 365 365 334 47 381 381.132 2£.4.2 Property ta.xes 125 18 142 142 130 18 149 148.831 2£.4.3 Health physics supplies 632 224 856 856 660 234 895 894.553 2£,4.4 Disposal ofDAW generated 27 11 49 49 31 12 54 54.471 2f.4.5 Plant energy budr:et 174 37 211 211 182 39 221 220.900 2f.4.6 NRC Fees 462 66 528 528 483 69 551 551.479 2f.4.7 Emergency Planninr: Fees 269 38 308 308 282 40 322 321.509 2f.4.8 Spent Fuel Transfer - Pool or ISFSI to DOE 1,130 241 1,371 1,371 1,181 251 1,433 1,432.779 2£.4.9 ISFSI Operatinr: Costs 34 7 41 41 35 7 43 42.723 2f.4.10 Security Staff Cost 1,694 361 2,055 2,055 1,771 377 2,148 2,147.737 2f.4.11 DOC Staff Cost 4,689 998 5,687 5,687 4,902 1,043 5,945 5,945.058 2f.4.12 Utility Staff Cost 5,150 1,096 6,246 6,246 5,384 1,146 6,529 6,529.383 2f.4 Subtotal Period 2fPeriod-Dependent Costs 632 27 14,047 3,142 17,859 16,140 1,719 660 31 14,683 3,284 18,671 16,873.544 1,797.010 2£.0 TOTAL PERIOD 2fCOST 632 9 27 24,887 7,456 33,012 31,293 1,719 660 31 26,015 7,793 34,511 32,713.760 1,797.010 PERIOD 2 TOTALS 7,800 65,609 29,166 14,192 107,948 479,280 187,894 891,887 756,949 121,822 13,117 8,153 68,581 30,487 14,835 124,356 500,991 196,405 943,808 802,362.522 127,340.068 14,105.293 TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E letter DC l-13-033 Document P01-1648-001, Rev. 0 Table C-l Table C-1 Appendix C1, Page 6 Of 7 Diablo Canyon Unit 1 Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Site Off-Site LLRW NRC Spent Fuel Site Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Index Activity Descri tion Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Cantin ene Costs Costs Costs Costs PERIOD 3b - Site Restoration Period 3b Direct Decommissioning Activities Demolition of Remaining Site Buildings 3b.LL1 *Reactor 6,798 1,447 8,245 8,245 7,106 1,512 8,618 8,618.390 3b. 1. 1.2 Capital Additions 85-2004 302 64 366 366 316 67 383 382.756 3b. 1. 1.3 Containment Penetration Area 686 146 832 832 717 153 870 869.654 3b.LL4 Miscellaneous 28 6 34 34 30 6 36 35.839 3b.L1.5 Turbine 3,659 779 4,438 4,438 3,825 814 4,639 4,639.371 3b.L1.6 Turbine Pedestal 1,318 281 1,599 1,599 1,378 293 1,672 1,671.526 3b.1.1.7 Fuel Handling 1,858 395 2,253 2,253 1,942 413 2,355 2,355.138 3b.l.l Totals 14,650 3,118 17,768 17,768 15,313 3,259 18,573 18,572.673 Site Closeout Activities 3b.1.2 Grade & landscape site 2,758 587 3,S45 3,345 2,883 614 3,496 3,496.266 3b.L3 Final report to NRC 229 49 278 278 240 51 291 290.730 3b.1 Subtotal Period 3b Activity Costs 17,407 229 3,754 21,391 278 21,113 18,196 240 3,924 22,360 290.730 3,496.266 Period 3b Additional Costs Sb.2.1 Concrete Crushing 476 101 577 577 497 106 603 603.188 Sb.2.2 Cofferdam Construction and Teardown 478 102 580 580 500 106 606 606.381 Sb.2.S Soil/ Sediment Control Plant Area 1,052 224 1,276 1,276 1,100 234 1,334 1,333.697 Sb.2 Subtotal Period Sb Additional Costs 2,006 427 2,433 2,433 2,097 446 2,543 2,543.266 Period Sb Collateral Costs Sb.S.1 Small tool allowance 210 45 254 254 219 47 266 265.680 Sb.S Subtotal Period Sb Collateral Costs 210 45 254 254 219 47 266 265.680 Period Sb Period-Dependent Costs SbA.1 Insurance 525 74 599 599 549 78 626 626.447 SbA.2 Property ta.xes 410 58 468 468 428 61 489 489.247 SbA.S Heavy equipment rental 7,347 1,564 8,911 8,911 7,680 1,635 9,315 9,314.820 SbA.4 Plant energy budget 286 61 347 347 299 64 363 36S.079 SbA.5 NRC ISFSI Fees 348 49 397 397 364 52 415 415.268 SbA.6 Emergency Planning Fees 885 126 1,011 1,011 926 131 1,057 1,056.887 SbA.7 Spent Fuel Transfer - Pool or ISFSI to DOE 3,711 790 4,501 4,501 3,879 826 4,705 4,704.721 SbA.8 ISFSI Operating Costs 111 24 134 134 116 25 140 140.441 SbA.9 Security Staff Cost 5,569 1,185 6,754 o 5,471 1,283 5,821 1,239 7,060 0.000 5,718.761 1,341.438 Sb.4.l0 DOC Staff Cost 14,111 3,003 17,114 17,114 14,750 3,139 17,889 17,889.231 SbA.11 Utility Staff Cost 7,357 1,566 8,923 1,785 7,138 7,690 1,637 9,327 1,865.S66 7,461.465 SbA Subtotal Period Sb Period-Dependent Costs 7,347 33,312 8,501 49,160 o 14,366 34,794 7,680 34,821 8,886 51,387 0.000 15,017.139 36,370.033 Sb.O TOTAL PERIOD 3b COST 26,970 33,542 12,726 73,238 278 14,366 58,594 28,192 35,061 13,303 76,556 290.730 15,017.139 61,247.919 PERIOD 3e - Fuel Storage Operations/Shipping Period Sc Direct Decommissioning Activities Period 3c Period-Dependent Costs 3eA.l Insurance 3,099 440 3,539 3,539 3,239 460 3,699 3,699.088 3eA.2 Property taxes 2,420 343 2,764 2,764 2,530 359 2,889 2,888.940 3c.4.3 Plant energy budget 3c.4.4 NRC ISFSI Fees 2,054 292 2,346 2,346 2,147 305 2,452 2,452.105 3cA.5 Emergency Planning Fees 5,228 742 5,970 5,970 5,465 776 6,241 6,240.778 3cA.6 Spent Fuel Transfer - Pool or ISFSI to DOE 21,995 4,682 26,676 26,676 22,991 4,894 27,885 27,884.503 ScA.7 ISFSI Operating Costs 654 139 793 793 684 146 829 829.286 3cA.8 Security Staff Cost 26,771 5,698 32,469 32,469 27,984 5,956 33,940 33,940.240 3eA.9 Utility Staff Cost 8,802 1,874 10,676 10,676 9,201 1,958 11,160 11,159.565 3eA Subtotal Period 3c Period-Dependent Costs 71,024 14,209 85,233 85,233 74,242 14,853 89,094 89,094.506 3e.0 TOTAL PERIOD Sc COST 71,024 14,209 85,233 85,233 74,242 14,853 89,094 89,094.506 PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d.1.1.1 Vessel & Internals GTCC Disposal 2,500 9,179 2,309 13,988 13,988 2,613 10,574 2,413 15,601 15,600.611 3d.l.l Totals 2,500 9,179 2,309 13,988 13,988 2,613 10,574 2,413 15,601 15,600.611 3d.1 Subtotal Period 3d Activity Costs 2,500 9,179 2,309 13,988 13,988 2,613 10,574 2,413 15,601 15,600.611 Period 3d Collateral Costs 3d.3 Subtotal Period 3d Collateral Costs Period 3d Period-Dependent Costs 3dA.l Insurance 10 11 11 10 12 11.781 3dA.2 Property taxes 8 9 9 8 9 9.200 3d.4.3 Plant energy budget 3dA.4 NRC ISFSI Fees 6 7 8 7.506 Sd.4.5 ISFSI Operating Costs 2 2 3 2.641 3d.4.6 Security Staff Cost 85 18 103 103 89 19 108 108.090 TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E Letter DCL-13-033 Document P01-1648-001, Rev. 0 Table C-l Table C-1 Appendix C1, Page 7 Of 7 Diablo Canyon Unit 1 Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Site Off-Site LLRW NRC Spent Fuel Site Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs 3d.4.7 Utility Staff Cost 28 6 84 34 29 6 36 35.540 3d.4 Subtotal Period 3d Period-Dependent Costs 139 28 167 167 146 29 175 174.758 3d.0 TOTAL PERIOD 3d COST 2,500 9,179 139 2,336 14,155 13,988 167 2,613 10,574 146 2,442 15,775 15,600.611 174.758 PERIOD 3e - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 8e Additional Costs 8e.2.1 ISFSI License Termination 40 6 14 393 622 290 1,365 1,365 42 15 453 650 303 1,469 1,468.953 3e.2 Subtotal Period 8e Additional Costs 40 6 14 393 622 290 1,365 1,365 42 15 453 650 303 1,469 1,468.953 Period 8e Collateral Costs 8e.3.1 Small tool allowance 0.741 8e.3 Subtotal Period 8e Collateral Costs 0.741 Period 3e Period-Dependent Costs 3e.4.1 Insurance 3e.4.2 Property taxes 55 8 63 63 57 8 65 65.486 3e.4.3 Heavy equipment rental 136 29 165 165 142 30 172 172.357 3e.4.4 Plant energy budget 3e.4.5 NRC ISFSI Fees 94 13 107 107 98 14 112 112.217 3e.4.6 Security Staff Cost 61 13 74 74 64 14 77 77.290 3e.4.7 Utility Staff Cost 163 35 198 198 171 36 207 206.940 3e.4 Subtotal Period 3e Period.Dependent Costs 186 373 98 607 607 142 390 102 634 634.290 3e.0 TOTAL PERIOD 3e COST 177 14 393 995 388 1,973 1,973 185 6 15 453 1,040 405 2,104 2,103.984 PERIOD 3f - ISFSI Site Restoration Period 3f Direct Decommissioning Activities Period 3f Additional Costs 3£,2.1 ISFSI Demolition and Site Restoration 1,371 27 297 1,695 1,695 1,433 28 311 1,772 1,771.980 3f.2.2 ISFSI Area Soil! Sediment Control 16 4 20 20 17 4 21 20.884 3£.2 Subtotal Period 3f Additional Costs 1,387 27 301 1,715 1,715 1,450 28 315 1,793 1,792.865 Period 3f Collateral Costs 3f.8.1 Small tool allowance 20 4 24 24 20 25 24.816 3£.8 Subtotal Period 3f Collateral Costs 20 4 24 24 20 25 24.816 Period 3fPeriod.Dependent Costs 3£,4.1 Insurance 3£,4.2 Property taxes 28 4 32 32 29 33 33.013 3f.4.3 Heavy equipment rental 54 11 65 65 56 12 68 67.903 3f.4.4 Plant energy budget 3f.4.5 Security Staff Cost 11 2 14 14 12 2 14 14.169 3£.4.6 Utility Staff Cost 69 15 83 83 72 15 87 87.157 3f.4 Subtotal Period 8fPeriod*Dependent Costs 54 108 32 193 193 56 112 84 202 202.242 3£.0 TOTAL PERIOD 3f COST 1.461 134 338 1,932 1,932 1,527 140 353 2,020 2,019.922 PERIOD 3 TOTALS 28,607 2,506 14 9,572 105,834 29,997 176,531 14,266 103,672 58,594 29,903 2,620 15 11,027 110,629 31,356 185,550 15,891.341 108,410.809 61,247.919 TOTAL COST TO DECOMMISSION 11,057 96,791 32,014 14,632 127,040 776,395 264,540 1,322,468 999,926 248,912 73,630 11,558 101,175 33,465 15,295 146,350 811,565 276,524 1,395,931 1,058,340.999 260,229.661 77,360.455 TOTAL COST TO DECOMMISSION WITH 25.01 % CONTINGENCY: $1,322,468 thousands of 2011 dollars TOTAL NRC LICENSE TERMINATION COST IS 75.61 % OR: $999,926 thousands of 2011 dollars SPENT FUEL MANAGEMENT COST IS 18.82% OR: $248,912 thousands of 2011 dollars NON-NUCLEAR DEMOLITION COST IS 5.57% OR: $73,630 thousands of 2011 dollars TOTAL SCRAP METAL REMOVED: 49,854 Tons I TOTAL CRAFT LABOR REQUIREMENTS: 962 738 Man-hours End Notes:

nJa - indicates that this activity not charged as decommissioning expense.

a - indicates that this activity performed by decommissioning staff.

o - indicates that this value is less than 0.5 but is non-zero.

a cell containing U - " indicates a zero value TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E Letter DCL-13-033 Document P01-1648-001, Rev. 0 Table C-2 Table C-2 Appendix C2, Page 1 of 8 Diablo Canyon Unit 2 Diablo Canyon Unit 2 DEC ON Decommissioning Cost Estimate DEC ON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Off-Site LLRW NRC Spent Fuel Site I Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Index Cost Cost Costs Costs Costs Costs Costs Contin enc' Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs PERIOD la - Shutdown through Transition Period 1a Direct Decommissioning Activities la.1.1 Prepare preliminary decommissioning cost 82 17 99 99 85 18 103 103.446 1a.1.2 Notification of Cessation of Operations a 1a.1.3 Remove fuel & source material nla la.1.4 Notification of Permanent Defueling 1a.1.5 Deactivate plant systems & process waste a la.1.6 Prepare and submit PSDAR 126 26 152 152 131 28 159 159.148 1a.1. 7 Review plant dwgs & specs. 289 61 350 350 302 64 366 366.040 la.1.8 Perform detailed rad survey a 1a.1.9 Estimate by*product inventory 63 13 76 76 66 14 80 79.574 1a.l.10 End product description 63 13 76 76 66 14 80 79.574 1a.1.ll Detailed by*product inventory 82 17 99 99 85 18 103 103.446 la.1.12 Define major work sequence 472 99 57l 571 493 104 597 596.804 1a.l.13 Perform SER and EA 195 41 236 236 204 43 247 246.679 1a.1.14 Perform Site.Specific Cost Study 315 66 381 381 329 69 398 397.869 1a.1.15 Prepare/submit License Termination Plan 258 54 312 312 269 57 326 325.934 1a.1.16 Receive NRC approval of termination plan Activity Specifications 1a.1.17.1 Plant & temporary facilities 310 65 375 337 323 68 392 352.353 39.150 1a.1.17.2 Plant systems 262 55 317 286 274 58 332 298,404 33.156 1a.1.17.3 NSSS Decontamination Flush 31 7 38 38 33 7 40 39.787 1a.1.17,4 Reactor internals 447 94 541 541 467 98 565 564.974 1a.1.17.5 Reactor vessel 409 86 495 495 427 90 517 517.230 1a.1.17.6 Biological shield 31 7 38 38 33 7 40 39.787 1a.1.17.7 Steam generators 196 41 238 238 205 43 248 248.270 1a.1.17.8 Reinforced concrete 101 21 122 61 105 22 127 63.659 63.659 1a.1.17.9 Main Turbine 25 5 30 26 6 32 31.830 1a.1.17.10 Main Condensers 25 30 26 6 32 31.830 1a.1.17.11 Plant structures & buildings 196 41 238 119 205 43 248 124.135 124.135 1a.1.17.12 Waste management 289 61 350 350 302 64 366 366.040 1a.1.17.13 Facility & site closeout 57 12 69 34 59 12 72 35.808 35.808 1a.1.17 Total 2,380 500 2,880 2,536 2,487 523 3,010 2,650.448 359.568 Planning & Site Preparations 1a.1.18 Prepare dismantling sequence 151 32 183 183 158 33 191 190.977 1a.1.19 Plant prep. & temp. svces 2,800 589 3,389 3,389 2,926 615 3,541 3,541.338 1a.1.20 Design water clean*up system 88 19 107 107 92 19 111 111.403 1a.1.21 Rigging/Cont. Cntrl Envlps/tooling/etc. 2,200 463 2,663 2,663 2,299 483 2,782 2,782.480 1a.1.22 Procure caskslliners & containers 77 16 94 94 81 17 98 97.876 1a.1 Subtotal Period 1a Activity Costs 9,640 2,027 11,668 11,323 10,074 2,119 12,193 11,833.036 359.568 Period 1a Additional Costs 1a.2.1 Spent Fuel Pool Isolation 13,217 2,779 15,996 15,996 13,812 2,905 16,716 16,716.127 1a.2.2 Disposal of Contaminated Tools & Equipment 234 97 3,145 1,156 4,632 4,632 245 101 3,623 1,208 5,176 5,176,462 1a.2 Subtotal Period 1a Additional Costs 234 97 3,145 13,217 3,935 20,628 20,628 245 101 3,623 13,812 4,112 21,893 21,892.589 Period 1a Period*Dependent Costs 1a.4.1 Insurance 1,056 148 1,204 1,204 1,103 155 1,258 1,257.764 1a.4.2 Property taxes 165 23 189 189 173 24 197 197.188 1a.4.3 Health physics supplies 457 160 617 617 477 167 644 644.466 1a.4.4 Heavy equipment rental 480 101 580 580 501 105 607 606.527 1a.4.5 Disposal of DAW generated 14 4 45 19 83 83 15 4 52 20 91 91.145 1a.4.6 Plant energy budget 1,156 243 1,399 1,399 1,208 254 1,462 1, 462.47l 1a.4.7 NRC Fees 838 117 955 955 875 123 998 998.141 1a.4.8 Emergency Planning Fees 1,001 140 1,142 1,142 1,046 147 1,193 1,193.076 1a,4.9 Spent Fuel Pool O&M 763 160 924 924 797 168 965 965.203 1a.4.10 ISFSI Operating Costs 45 9 54 54 47 10 57 56.569 1a.4.ll Severance Related Costs 38,503 8,097 46,600 46,600 40,236 8,462 48,697 48,697.139 1a.4.12 Spent Fuel Storage Canisters/Overpacks 5,714 1,202 6,916 6,916 5,971 1,256 7,227 7,226.824 1a.4.13 Security Staff Cost 14,837 3,120 17,957 17,957 15,505 3,261 18,765 18,765.207 1a.4.14 Utility Staff Cost 26,317 5,534 31,851 31,851 27,501 5,783 33,285 33,284.616 1a.4 Subtotal Period la Period* Dependent Costs 936 14 4 45 90,395 19,075 110,470 101,435 9,035 978 15 4 52 94,463 19,934 115,446 106,004.664 9,441.673 la.O TOTAL PERIOD 1a COST 936 248 101 3,190 113,252 25,038 142,766 133,387 9,035 978 260 106 3,675 118,348 26,164 149,532 139,730.289 9,441.673 359.568 PERIOD Ib - Decommissioning Preparations Period 1b Direct Decommissioning Activities Detailed Work Procedures 1b.1.l.1 Plant systems 298 63 360 324 311 65 377 338.961 37.662 lb. 1. 1.2 NSSS Decontamination Flush 63 13 76 76 66 14 80 79.574 lb. 1. 1.3 Reactor internals 157 33 190 190 164 35 199 198.935 1b.1.1.4 Remaining buildings 85 18 103 26 89 19 107 26.856 80.569 lb. 1. 1.5 CRD cooling assembly 63 13 76 76 66 14 80 79.574 lb. 1. 1.6 CRD housings & ICI tubes 63 13 76 76 66 14 80 79.574 1b.1.1. 7 Incore instrumentation 63 13 76 76 66 14 80 79.574 lb. 1. 1.8 Reactor vessel 228 48 276 276 239 50 289 288.853 TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E Letter DCL-13-033 Document P01-1648-001, Rev. 0 Table C-2 Table C-2 Appendix C2, Page 2 of 8 Diablo Canyon Unit 2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Off-Site LLRW NRC Spent Fuel Site Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Decou Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Index Cost Cost Costs Costs Costs Costs Costs Contin enc' Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin 'enc Costs Costs Costs Costs lb. 1. 1.9 Facility closeout 75 16 91 46 79 17 95 47.744 47.744 lb. 1.1.10 Missile shields 28 6 34 34 30 6 36 35.808 lb. 1. 1.11 Biological shield 75 16 91 91 79 17 95 95.489 lb. 1. 1.12 Steam generators 289 61 350 350 302 64 366 366.040 1b.1.1.13 Reinforced concrete 63 13 76 38 66 14 80 39.787 39.787 lb. 1. 1.14 Main Turbine 98 21 119 103 22 124 124.135 lb. 1. 1.15 Main Condensers 98 21 119 103 22 124 124.135 1b.1.1.16 Auxiliary building 172 36 208 187 179 38 217 195.513 21.724 lb. 1. 1.17 Reactor building 172 36 208 187 179 38 217 195.513 21.724 1b.1.1 Total 2,092 440 2,531 2,055 2,186 460 2,645 2,147.794 497.480 lb. 1.2 Decon primary loop 750 526 1,276 1,276 784 550 1,334 1,333.756 1b.1 Subtotal Period 1b Activity Costs 750 2,092 966 3,808 3,332 784 2,186 1,009 3,979 3,481.551 497.480 Period 1b Additional Costs 1b.2.1 Site Characterization 2,038 857 2,895 2,895 2,129 896 3,025 3,024.755 1b.2.2 Hazardous Waste Management 204 43 247 247 213 45 258 258.012 1b.2.3 Mixed Waste Management 270 57 327 327 282 59 341 341.486 1b.2 Subtotal Period 1b Additional Costs 2,512 957 3,468 3,468 2,625 1,000 3,624 3,624.253 Period Ib Collateral Costs Ib.3.1 Decon equipment 931 196 1,126 1,126 973 205 1,177 1,177.034 1b.3.2 DOC staff relocation expenses 1,415 297 1,712 1,712 1,478 311 1,789 1,789.113 Ib.3.3 Process decommissioning water waste 46 21 66 88 80 301 301 48 22 69 101 84 324 324.049 1b.3.4 Process decommissioning chemical flush waste 63 256 6,210 2,240 8,770 8,770 65 267 7,154 2,341 9,829 9,829.140 1b.3.5 Small tool allowance 3 1 3 3 3 1 3 3.400 1b.3.6 Pipe cutting equipment 1.100 231 1,331 1,331 1,150 242 1,391 1,391.240 1b.3.7 Decon rig 1,500 315 1,815 1,815 1,568 330 1,897 1,897.145 1b.3 Subtotal Period 1b Collateral Costs 2,479 1,103 84 321 6,298 1,415 3,361 15,060 15,060 2,590 1,152 88 336 7,255 1,478 3,512 16,411 16,411.122 Period Ib Period.Dependent Costs 1b.4.1 Decon supplies 28 10 38 38 29 10 40 39.763 Ib.4.2 Insurance 523 73 597 597 547 77 624 623.713 1b.4.3 Property taxes 82 12 94 94 86 12 98 97.784 Ib.4.4 Health physics supplies 249 87 336 336 260 91 351 351.035 Ib.4.5 Heavy equipment rental 238 50 288 288 249 52 301 300.771 1b.4.6 Disposal ofDAW generated 8 26 11 47 47 9 30 11 52 51.943 1b.4.7 Plant energy budget 1,147 241 1,388 1,388 1,198 252 1,450 1,450.451 1b.4.8 NRC Fees 237 33 270 270 247 35 282 282.193 1b.4.9 Emergency Planning Fees 497 70 566 566 519 73 592 591.635 1b.4.10 Spent Fuel Pool O&M 378 80 458 458 395 83 479 478.635 1b.4.11 ISFSI Operating Costs 22 5 27 27 23 5 28 28.052 1b.4.12 Severance Related Costs 2.018 424 2,442 2,442 2,109 443 2,552 2,552.042 1b.4.13 Spent Fuel Storage Canisters/Overpacks 3,086 649 3,735 3,735 3,225 678 3,903 3,903.096 1b.4.14 Security Staff Cost 7,357 1,547 8,905 8,905 7,689 1,617 9,305 9,305.486 1b.4.15 DOC Staff Cost 4,664 981 5,645 5,645 4,874 1,025 5,899 5,898.867 1b.4.16 Utility Staff Cost 13,050 2,744 15,795 15,795 13,638 2,868 16,506 16,505.518 1b.4 Subtotal Period Ib Period*Dependent Costs 28 487 8 2 26 33,062 7,017 40,630 35,844 4,786 29 508 9 30 34,550 7,333 42,461 37,459.566 5,001.418 Ib.O TOTAL PERIOD Ib COST 3,257 1,589 92 324 6,323 39,080 12,300 62,965 57,703 4,786 3,404 1,661 96 338 7,285 40,838 12,854 66,475 60,976.491 5,001.418 497.480 PERIOD 1 TOTALS 3,257 2,525 341 425 9,514 152,332 37,338 205,731 191,090 13,821 3,404 2,639 356 444 10,960 159,187 89,018 216,007 200,706.780 14,443.091 857.048 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.1 Reactor Coolant Piping 370 354 52 40 1,342 869 3,027 3,027 386 370 64 42 1,646 909 3,307 3,307.293 2a. 1. 1.2 Pressurizer Quench Tank 39 35 8 6 189 108 385 385 41 37 8 6 217 113 423 422.941 2a. 1. 1.3 Reactor Coolant Pumps & Motors 118 126 103 185 1,4*13 686 2,661 2,661 123 132 108 193 1,663 717 2,935 2,935.089 2a. 1. 1. 4 Pressurizer 50 70 448 114 750 409 1,841 1,841 53 73 468 119 864 428 2,004 2,004.499 2a.1.1.5 Steam Generators 477 4,206 3,368 1,922 12,807 7,173 29,952 29,952 498 4,395 3,519 2,008 14,753 7,496 32,670 32,669.906 2a.1.1.6 Retired Steam Generator Units 2,496 1,878 12,597 5,160 22,131 22,131 2,608 1,962 14,512 5,392 24,475 24,474.805 2a.1.1. 7 CRDlVIsIICIs/Service Structure Removal 196 112 262 37 444 377 1,428 1,428 205 117 274 39 511 394 1,540 1,539.815 2a.1.1.8 Reactor Vessel Internals 163 3,064 14,919 1,413 10,366 278 16,385 46,588 46,588 170 3,202 15,590 1,476 11,942 290 17,123 49,793 49,793.474 2a.1.1.9 Reactor Vessel 122 5,180 2,387 742 2,651 278 8,545 19,905 19,905 127 5,413 .2,494 776 3,054 290 8,930 21,084 21,084.302 2a.1.1 Totals 1,534 13,148 24,042 6,336 42,589 556 39,714 127,919 127,919 1,603 13,740 25,124 6,621 49,063 581 41,501 138,232 138,232.124 Removal of Major Equipment 2a.1.2 Main Turbine/Generator 202 43 245 211 44 256 255.886 2a.1.3 Main Condensers 668 141 809 698 147 845 844.986 Cascading Costs from Clean Building Demolition 2a.1.4.1 *Reactor 1,194 251 1,445 1,445 1,247 262 1,510 1,509.670 2a.1.4.2 Auxiliary 719 151 870 870 751 158 909 909.444 2a.1.4.3 Containment Penetration Area 73 15 89 89 77 16 93 92.735 2a.1.4.4 Radwaste Storage 91 19 110 110 95 20 115 115.117 2a.1.4.5 Fuel Handling 193 41 234 234 202 42 244 244.077 2a.1.4 Totals 2,270 477 2,747 2,747 2,372 499 2,871 2,871.044 Disposal of Plant Systems 2a.1.5.1 Auxiliary Steam 76 16 92 79 17 96 95.728 TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E Letter DCL-13-033 Document P01-1648-001, Rev. 0 Table C-2 Table C-2 Appendix C2, Page 3 of 8 Diablo Canyon Unit 2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Off-Site LLRW NRC Spent Fuel Site Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term_ Management Decon Removal Packaging Transport Processing Disposal Other Total Total Lic_ Term. Management Restoration Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Con tin 'enc Costs Costs Costs Costs 2a.1.5.2 Auxiliary Steam (RCA) 141 32 9 319 168 670 670 148 33 10 368 175 734 734.162 2a.1.5.3 Building Services (Non-Power Block) 7 1 8 7 1 9 8.612 2a.1.5.4 Condensate System 619 130 749 646 136 782 782.362 2a.1.5.5 Condensate System (lnsulated) 274 58 332 287 60 347 346.967 2a.1.5.6 Containment Spray 235 161 51 1,719 718 2,885 2,885 245 169 53 1,981 751 3,199 3,198.533 2a.1.5.7 Extraction Steam & Heater Drip 230 48 279 241 51 291 291.126 2a.1.5.8 Feedwater System 67 14 82 70 15 85 85.180 2a.1.5.9 Feedwater System (lnsulated) 162 34 196 169 36 205 204.543 2a. 1.5. 10 Feedwater System (RCA Insulated) 119 42 15 497 225 897 897 124 43 15 572 235 990 990.254 2a. 1.5. 11 Feedwater System (RCA) 6 2 1 26 12 46 46 6 2 1 30 12 51 51.378 2a.1.5.12 NSSS Sampling 159 9 3 100 93 364 364 166 10 3 115 97 391 390.790 2a.1.5.13 NSSS Sampling (lnsulated) 47 o 10 20 78 78 49 1 o 11 21 83 82.581 2a.1.5.14 Nitrogen & Hydrogen 19 4 23 20 4 25 24.555 2a.1.5.15 Nitrogen & Hydrogen (lnsulatd) 1 o 1 1 o 1 1.250 2a.1.5.16 Nitrogen & Hydrogen (RCA Insulated) 5 o 4 15 15 6 o 6 4 16 15.905 2a.1.5.17 Nitrogen & Hydrogen (RCA) 103 11 3 92 71 280 280 108 12 3 106 74 302 302.189 2a.1.5.18 Oily Water Separator & TB Sump 29 11 3 102 48 192 192 31 11 3 117 50 212 211.920 2a.1.5.19 Saltwater System 181 38 219 189 40 228 228.446 2a,1.5.20 Turbine Steam Supply 762 160 922 796 167 964 963.855 2a.1.5.21 Turbine Steam Supply (RCA) 878 345 117 3,961 1,769 7,070 7,070 918 361 122 4,563 1,849 7,812 7,811.829 2a.1.5.22 Turbine and Generator 81 17 98 85 18 102 102.373 2a.1.5.23 Turbine and Generator (lnsulated) 24 5 29 25 5 30 30.095 2a.1.5 Totals 4,226 614 201 6,830 3,653 15,525 12,496 4,416 642 210 7,869 3,817 16,955 13,789.541 3,165.092 2a.1.6 Scaffolding in support of decommissioning 4,785 21 11 251 1,770 6,838 6,838 5,001 22 12 289 1,850 7,173 7,172.591 2a.1 Subtotal Period 2a Activity Costs 1,534 25,300 24,677 6,548 49,671 556 45,798 154,083 150,001 1,603 26,438 25,787 6,843 57,220 581 47,859 166,331 162,065.300 4,265.964 Period 2a Additional Costs 2a.2.1 Retired Reactor Head 225 179 1,557 615 2,576 2,576 235 187 1,794 643 2,858 2,858.126 2a.2 Subtotal Period 2a Additional Costs 225 179 1,557 615 2,576 2,576 235 187 1,794 643 2,858 2,858.126 Period 2a Collateral Costs 2a.3.1 Process decommissioning water waste 85 40 123 165 149 562 562 89 42 129 190 155 605 604.671 2a.3.2 Process decommissioning chemical flush waste 2a.3.3 Small tool allowance 315 66 381 343 329 69 398 358.486 39.832 2a.3.4 Spent Fuel Transfer - Pool to ISFSI 2,279 479 2,758 2,758 2,381 501 2,882 2,882.002 2a.3 Subtotal Period 2a Collateral Costs 85 315 40 123 165 2,279 694 3,701 905 2,758 89 329 42 129 190 2,381 725 3,885 963.157 2,882.002 39.832 Period 2a Period-Dependent Costs 2a.4.1 Decon supplies 92 32 124 124 96 34 130 129.614 2a.4.2 Insurance 768 108 875 875 802 112 915 914.534 2a.4.3 Property taxes 268 38 305 275 280 39 319 286.869 31.874 2a.4.4 Health physics supplies 1,968 690 2,658 2,658 2,057 721 2,778 2,777.736 2a.4.5 Heavy equipment rental 3,373 709 4,082 4,082 3,525 741 4,266 4,266.185 2a.4.6 Disposal ofDAW generated 110 31 349 144 635 635 115 32 402 151 700 700.397 2a.4.7 Plant energy budget 1,776 373 2,149 2,149 1,856 390 2,246 2,245.795 2a.4.8 NRC Fees 724 102 826 826 757 106 863 863.096 2a.4.9 Emergency Planning Fees 1,156 162 1,318 1,318 1,208 169 1,377 1,377.109 2a.4.10 Spent Fuel Pool O&M 1,234 259 1,493 1,493 1,289 271 1,560 1,560.192 2a.4.11 ISFSI Operating Costs 72 15 88 88 76 16 91 91.441 2a.4.12 Severance Related Costs 494 104 598 598 516 109 625 624.989 2a.4.13 Spent Fuel Storage Canisters/Overpacks 3,418 719 4,137 4,137 3,572 751 4,323 4,323.006 2a.4.14 Security Staff Cost 23,983 5,044 29,027 29,027 25,062 5,271 30,333 30,332.798 2a.4. 15 DOC Staff Cost 26,130 5,495 31,625 31,625 27,306 5,742 33,048 33,048_169 2a.4.16 Utility Staff Cost 37,794 7,948 45,742 45,742 39,494 8,306 47,800 47,800.003 2a.4 Subtotal Period 2a Period-Dependent Costs 92 5,341 110 31 349 97,815 21,942 125,681 118,615 7,035 96 5,582 115 32 402 102,217 22,929 131,374 123,990.184 7,351.748 31.874 2a.0 TOTAL PERIOD 2a COST 1,711 30,956 25,052 6,881 51,741 100,650 69,049 286,040 272,096 9,793 1,788 32,349 26,180 7,191 59,606 105,179 72,156 304,448 289,876.768 10,233.749 4,337.670 PERIOD 2b - Site Decontamination Period 2b Direct Decommissioning Activities Disposal of Plant Systems 2b. 1. 1.1 Capital Additions 85-2002 (Clean) 450 95 544 470 99 569 568.794 2b. 1. 1.2 Capital Additions 85-2002 (contaminated) 483 61 24 797 462 1,827 1,827 505 64 25 919 483 1,995 1,994.510 2b.1.1.3 Chemical & Volume Control 809 1,066 172 58 1,966 1,666 5,736 5,736 845 1,114 180 61 2,264 1,741 6,205 6,201.744 2b. 1. 1.4 Chemical & Volume Control (lnsulated) 294 432 47 13 438 520 1,744 1,744 307 452 49 13 505 544 1,870 1,869.843 2b. 1. 1.5 Component Cooling Water 190 40 230 198 42 240 240.173 2b. 1. 1.6 Component Cooling Water (RCA) 595 191 66 2,245 1,036 4,133 4,133 622 200 69 2,586 1,083 4,559 4,559.272 2b. 1. 1.7 Compressed Air 118 25 143 124 26 150 149.818 2b. 1. 1.8 Compressed Air (lnsulated) 6 1 8 6 1 8 7.859 2b.l.L9 Compressed Air (RCA Insulated) 29 4 1 33 23 89 89 30 4 1 38 24 97 96.948 2b. 1. 1.10 Compressed Air (RCA) 531 69 19 629 420 1,667 1,667 555 72 19 725 439 1,809 1,808.866 2b.1.1.11 Diesel Engine-Generator 137 29 165 143 30 173 172.901 2b.1.1.12 Diesel Engine-Generator (lnsulated) 3 1 4 3 1 4 3.776 2b. 1. 1.13 Electrical (Clean) 3,115 655 3,770 3,255 685 3,940 3,940.024 2b.1.1.14 Electrical (Contaminated) 360 44 18 613 351 1,386 1,386 376 46 19 706 367 1,514 1,514.326 2b.L1.15 Electrical (RCA) 1,875 394 2,269 1,959 412 2,371 2,371.163 2b.1.1.16 Fire Protection 364 148 53 1,792 788 3,145 3,145 381 155 55 2,064 823 3,478 3,477.701 2b. 1. 1.17 Gaseous Radwaste 133 20 6 217 127 502 502 139 20 7 250 132 548 548.019 2b.1.1.18 HVAC (Clean Insulated) 40 8 48 42 9 50 50.445 TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E Letter DCL ..13 ..033 Document P01-1648 ..001, Rev. 0 Table C-2 Table C-2 Diablo Canyon Unit 2 Appendix C2, Page 4 of 8 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Off-Site LLRW NRC Spent Fuel Site Activity Decon; Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Terrn. Management Restoration Index Activity Descri tion Cost Cost Costs Costs Costs Costs Costs Contin ency Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs 2b.1.1.19 HVAC (Clean) 428 90 518 448 94 542 541.824 2b.1.1.20 HVAC (Contaminated Insulated) 232 37 15 506 267 1,057 1,057 242 38 16 583 279 1,158 1,158.404 2b.1.1.21 HVAC (Contaminated) 1,033 185 76 2,563 1,302 5,159 5,159 1,080 194 79 2,952 1,361 5,665 5,665.097 2b.1.1.22 Liquid Radwaste 362 447 74 25 862 728 2,498 2,498 378 468 77 27 992 761 2,703 2,702.883 2b.l.1.23 Liquid Radwaste (Insulated) 29 44 5 1 45 53 177 177 31 46 5 52 55 190 190.303 2b.1.1.24 Lube Oil Distribution & Purification 126 26 152 132 28 159 159.247 2b.1.1.25 Make*up Water 244 51 296 255 54 309 309.107 2b.1.1.26 Make*up Water (Insulated) 24 5 29 25 30 29.991 2b.1.1.27 Make*up Water (RCA Insulated) 32 7 67 36 144 144 34 7 2 77 38 158 157.563 2b.1.1.28 Make*up Water (RCA) 164 39 11 378 198 790 790 171 40 12 436 207 866 865.951 2b.1.1.29 Mechanical Department Equipment 1 o 1 1 o 2 1.532 2b.1.1.30 Miscellaneous Reactor Coolant 21 141 17 5 158 123 464 464 21 148 18 5 182 128 502 501.626 2b.l.1.31 Nuclear Steam Supply Sampling 21 1 21 15 61 61 22 3 1 24 16 66 65.771 2b.1.1.32 Nuclear Steam Supply Sampling (Insulated 9 o 9 26 26 10 1 o 10 7 28 28.188 2b.1.1.33 Residual Heat Removal 307 305 162 54 1,845 1,003 3,675 3,675 321 319 169 57 2,125 1,048 4,038 4,038.242 2b.1.1.34 Safety Injection 124 21 7 242 133 527 527 129 22 7 279 139 577 576.505 Disposal of Plant Systems (continued) 2b.1.1.35 Safety Injection (Insulated) 5 1 o 10 23 23 6 1 o 12 6 25 24.759 2b.1.1.36 Safety Injection (RCA Insulated) 38 8 3 92 48 189 189 40 9 3 106 50 208 207.851 2b.1.1.37 Safety Injection (RCA) 322 76 24 830 420 1,672 1,672 336 80 26 957 439 1,837 1,836.529 2b.1.1.38 Service Cooling Water 138 29 167 145 30 175 174.960 2b.1.1.39 Service Cooling Water (RCA) 37 9 3 96 49 195 195 39 10 111 51 214 213.669 2b.l.1.40 Sewer System Expansion 47 10 57 50 10 60 59.997 2b.1.1 Totals 1,821 13,893 1,400 485 16,454 11,238 45,291 36,887 1,903 14,519 1,463 507 18,955 11,744 49,089 40,307.570 8,781.612 2b.1.2 Scaffolding in support of decommissioning 5,982 26 14 313 2,213 8,548 8,548 6,251 27 14 361 2,312 8,966 8,965.737 Decontamination of Site Buildings 2b.1.3.1 *Reactor 959 2,483 1,120 5,645 26,011 12,003 48,221 48,221 1,002 2,595 1,170 5,899 29,964 12,543 53,174 53,174.030 2b.1.3.2 Auxiliary 1,325 739 65 98 927 1,542 4,695 4,695 1,384 772 68 102 1,067 1,611 5,005 5,005.272 2b.1.3.3 Capital Additions 85*2004 423 168 10 20 151 414 1,187 1,187 442 176 10 21 174 433 1,257 1,256.658 2b.1.3.4 Containment Penetration Area 327 213 26 28 379 446 1,420 1,420 341 223 27 30 437 466 1,524 1,524.095 2b.1.3.5 Radwaste Storage 8 62 4 9 59 51 194 194 9 65 4 10 67 53 209 208.644 2b.1.3 Totals 3,042 3,666 1,224 5,801 27,526 14,457 55,716 55,716 3,179 3,831 1,279 6,062 31,710 15,107 61,169 61,168.698 2b.1 Subtotal Period 2b Activity Costs 4,863 23,541 2,650 6,300 44,293 27,908 109,554 101,151 5,082 24,600 2,769 6,583 51,026 29,163 119,224 110,442.006 8,781.612 Period 2b Collateral Costs 2b.3.1 Process decommissioning water waste 143 69 213 284 254 964 964 149 72 223 328 266 1,038 1,037.629 2b.3.2 Process decommissioning chemical flush waste 3 90 369 687 333 1,482 1,482 3 94 386 791 348 1,622 1,622.024 2b.3.3 Small tool allowance 445 94 539 539 465 98 563 563.189 2b.3.4 Spent Fuel Transfer* Pool to ISFSI 7,172 1,508 8,681 8,681 7,495 1,576 9,071 9,071.313 2b.3 Subtotal Period 2b Collateral Costs 145 445 160 582 971 7,172 2,189 11,665 2,985 8,681 152 465 167 609 1,119 7,495 2,288 12,294 3,222.843 9,071.313 Period 2b Period*Dependent Costs 2b.4.1 Decon supplies 1,456 510 1,966 1,966 1,521 533 2,054 2,054.127 2b.4.2 Insurance 1,136 159 1,295 1,295 1,187 166 1,353 1,353.200 2b.4.3 Property taxes 396 55 451 451 414 58 472 471.631 2b.4.4 Health physics supplies 2,764 969 3,733 3,733 2,888 1,012 3,901 3,900.908 2b.4.5 Heavy equipment rental 4,951 1,041 5,992 5,992 5,174 1,088 6,262 6,261.581 2b.4.6 Disposal ofDAW generated 127 36 401 166 730 730 133 37 463 174 806 806.048 2b.4.7 Plant energy budget 2,074 436 2,510 2,510 2,168 456 2,623 2,623.433 2b.4.8 NRC Fees 1,072 150 1,222 1,222 1,120 157 1,277 1,277.090 2b.4.9 Emergency Planning Fees 1,710 240 1,950 1,950 1,787 251 2,038 2,037.654 2b.4.10 Spent Fuel Pool O&M 1,825 384 2,209 2,209 1,907 401 2,309 2,308.555 2b.4.11 Liquid Radwaste Processing Equipment/Services 463 97 561 561 484 102 586 586.198 2b.4.12 ISFSI Operating Costs 107 22 129 129 112 24 135 135.301 2b.4.13 Severance Related Costs 7,908 1,663 9,571 9,571 8,263 1,738 10,001 10,001.276 2b.4.14 Spent Fuel Storage Canisters/Overpacks 10,760 2,263 13,023 13,023 11,244 2,365 13,609 13,608.918 2b.4.15 Security Staff Cost 35,487 7,463 42,950 42,950 37,084 7,799 44,882 44,882.259 2b.4.16 DOC Staff Cost 37,206 7,824 45,030 45,030 38,880 8,176 47,056 47,056.183 2b.4.17 Utility Staff Cost 53,628 11,278 64,905 64,905 56,041 11,785 67,826 67,826.133 2b.4 Subtotal Period 2b Period* Dependent Costs 1,456 7,715 127 36 401 153,771 34,722 198,227 180,916 17,311 1,521 8,062 133 37 463 160,691 36,284 207,190 189,100.068 18,090.429 2b.0 TOTAL PERIOD 2b COST 6,464 31,701 2,936 6,918 45,666 160,943 64,819 319,447 285,051 25,992 6,755 33,128 3,069 7,229 52,607 168,186 67,735 338,708 302,764.917 27,161.741 8,781.612 PERIOD 2c - Spent fuel delay prior to SFP decon Period 2c Direct Decommissioning Activities Period 2c Collateral Costs 2c.3.1 Spent Fuel Transfer* Pool to ISFSI 7,549 1,588 9,137 9,137 7,889 1,659 9,548 9,547.665 2c.3 Subtotal Period 2c Collateral Costs 7,549 1,588 9,137 9,137 7,889 1,659 9,548 9,547.665 Period 2c Period*Dependent Costs 2c.4.1 Insurance 3,088 433 3,521 3,521 3,227 452 3,680 3,679.837 2c.4.2 Property taxes 1,076 151 1,227 1,227 1,125 158 1,283 1,282.534 2c.4.3 Health physics supplies 2,326 815 3,142 3,142 2,431 852 3,283 3,283.064 2c.4.4 Disposal of DAW generated 68 19 216 89 392 392 71 20 248 93 433 432.930 2c.4.5 Plant energy budget 1,504 316 1,820 1,820 1,572 331 1,902 1,902.414 2c.4.6 NRC Fees 2,000 280 2,281 2,281 2,090 293 2,383 2,383.386 2c.4.7 Emergency Planning Fees 4,651 652 5,303 5,303 4,860 681 5,541 5,541.113 2c.4.8 Spent Fuel Transfer* Pool or ISFSI to DOE 13,947 2,933 16,880 16,880 14,575 3,065 17,640 17,639.909 TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E letter DCl-13-033 Document P01-1648-001, Rev. 0 Table C-2 Table C-2 Appendix C2, Page 5 of 8 Diablo Canyon Unit 2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Off-Site LLRW NRC Spent Fuel Site I Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic_ Term_ Management Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Index Cost Cost Costs Costs Costs Costs Costs Cantin enc Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Cantin enc Costs Costs Costs Costs Period 2c Period-Dependent Costs (continued) 2c.4.9 Spent Fuel Pool O&M 4,964 1,044 6,007 6,007 5,187 1,091 6,278 6,277.789 2c.4.10 Liquid Radwaste Processing Equipment/Services 315 66 381 381 329 69 399 398.528 2c.4.11 ISFSI Operating Costs 291 61 352 352 304 64 368 367.932 2c.4.12 Spent Fuel Storage Canisters/Overpacks 11,323 2,381 13,704 13,704 11,832 2,488 14,321 14,320.741 2c.4.13 Security Staff Cost 96,501 20,294 116,795 116,795 100,844 21,207 122,051 122,050.963 2c.4.14 Utility Staff Cost 42,556 8,950 51,506 51,506 44,471 9,352 53,824 53,823.681 2c.4 Subtotal Period 2c Period-Dependent Costs 2,326 68 19 216 182,217 38,467 223,313 181,066 42,246 2,431 71 20 248 190,417 40,198 233,385 189,237.339 44,147.484 2c.O TOTAL PERIOD 2c COST 2,326 68 19 216 189,766 40,054 232,449 181,066 51,383 2,431 71 20 248 198,305 41,857 242,933 189,237.339 53,695.150 PERIOD 2d - Decontamination Following Wet Fuel Storage Period 2d Direct Decommissioning Activilies 2d.1.1 Remove spent fuel racks 585 56 174 36 1,207 885 2,943 2,943 612 59 181 37 1,391 925 3,204 3,204.494 Disposal of Plant Systems 2d.1.2.1 Electrical (Contaminated) - FHB 111 8 3 115 81 317 317 116 9 4 132 84 344 344.044 2d.1.2.2 Electrical (RCA)-FHB 690 78 31 1,042 624 2,464 2,464 721 81 32 1,200 652 2,687 2,686.685 2d.1.2.3 Fire Protection (RCA) 264 67 18 613 321 1,283 1,283 276 70 19 706 335 1,407 1,406.541 2d.1.2.4 HVAC (Contaminated) - FHB 231 39 16 542 280 1,107 1,107 241 41 17 624 292 1,215 1,215.201 2d.1.2.5 Spent Fuel Pit Cooling 94 65 21 712 296 1,189 1,189 99 68 22 821 310 1,319 1,318.983 2d.1.2.6 Spent Fuel Pit Cooling - FHB 130 71 23 772 331 1,327 1,327 136 74 24 889 346 1,469 1,468.832 2d.1.2 Totals 1,520 328 112 3,795 1,933 7,688 7,688 1,588 343 117 4,372 2,020 8,440 8,440.286 Decontamination of Site Buildings 2d.1.3.1 Fuel Handling 811 859 63 41 637 1,110 3,521 3,521 847 898 66 43 733 1,160 3,747 3,747.485 2d.1.3 Totals 811 859 63 41 637 1,110 3,521 3,521 847 898 66 43 733 1,160 3,747 3,747.485 2d.1.4 Scaffolding in support of decommissioning 1,196 63 443 1,710 1,710 1,250 72 462 1,793 1,793.147 2d.l Subtotal Period 2d Activity Costs 1,396 3,632 570 191 5,702 4,370 15,862 15,862 1,459 3,795 596 200 6,568 4,567 17,185 17,185.411 Period 2d Additional Costs 2d.2.1 License Termination Survey Planning 800 336 1,136 1,136 836 351 1,187 1,187.202 2d.2 Subtotal Period 2d Additional Costs 800 336 1,136 1,136 836 351 1,187 1,187.202 Period 2d Collateral Costs 2d.3.1 Process decommissioning water waste 37 20 62 82 70 271 271 38 21 64 95 73 292 291.605 2d.3.2 Process decommissioning chemical flush waste 2d.3.3 Small tool allowance 79 17 96 96 83 17 100 99.853 2d.3.4 Decommissioning Equipment Disposition 155 54 1,828 674 2,710 2,710 162 56 2,105 704 3,027 3,027.341 2d.3 Subtotal Period 2d Collateral Costs 37 79 175 115 1,910 760 3,076 3,076 38 83 183 121 2.200 795 3,419 3,418.799 Period 2d Period-Dependent Costs 2d.4.1 Decon supplies 209 73 282 282 218 77 295 295.062 2d.4.2 Insurance 219 31 249 249 228 32 260 260.410 2d.4.3 Property taxes 76 11 87 87 80 11 91 90.761 2d.4.4 Health physics supplies 445 156 601 601 465 163 628 627.742 2d.4.5 Heavy equipment rental 953 200 1,153 1,153 996 209 1,205 1,204.978 2d.4.6 Disposal ofDAW generated 45 13 143 59 260 260 47 13 165 62 287 287.402 2d.4.7 Plant energy budget 213 45 258 258 222 47 269 269.255 2d.4.8 NRC Fees 175 24 199 199 182 26 208 208.060 2d.4.9 Emergency Planning Fees 165 23 188 188 172 24 196 196.064 2d.4.10 Spent Fuel Transfer - Pool or ISFSI to DOE 1,216 256 1,472 1,472 1,271 267 1,539 1,538.506 2d.4.11 Liquid Radwaste Processing Equipment/Services 178 38 216 216 186 39 226 225.616 2d.4.12 ISFSI Operating Costs 21 4 25 25 22 5 26 26.037 2d.4.13 Severance Related Costs 12,313 2,589 14,902 14,902 12,867 2,706 15,573 15,572.666 2d.4.14 Security Staff Cost 1,035 218 1,253 1,253 1,081 227 1,309 1,308.938 2d.4.15 DOC Staff Cost 4,884 1,027 5,911 5,911 5,104 1,073 6,177 6,177.439 2d.4.16 Utility Staff Cost 7,532 1,584 9,117 9,117 7,871 1,655 9,527 9,526.765 2d.4 Subtotal Period 2d Period-Dependent Costs 209 1,398 45 13 143 28,027 6,338 36,173 34,488 1,685 218 1,460 47 13 165 29,288 6,624 37,816 36,055.096 1,760.607 2d.O TOTAL PERIOD 2d COST 1,642 5,108 790 319 7,755 28,826 11,805 56,246 54,561 1,685 1,716 5,338 826 334 8,933 30,123 12,337 59,607 57,846.507 1,760.607 PERIOD 2f - License Termination Period 2fDirect Decommissioning Activities 2f. 1. 1 ORISE confirmatory survey 178 75 253 253 186 78 264 264.330 2f.1.2 Terminate license a 2f.1 Subtotal Period 2f Activity Costs 178 75 253 253 186 78 264 264.330 Period 2f Additional Costs 2f.2.1 License Termination Survey 14,399 6,056 20,456 20,456 15,047 6,329 21,376 21,376.388 2f.2 Subtotal Period 2f Additional Costs 14,399 6,056 20,456 20,456 15,047 6,329 21,376 21,376.388 Period 2f Collateral Costs 2f.3.1 DOC staff relocation expenses 1,415 297 1,712 1,712 1,478 311 1,789 1,789.113 2f.3 Subtotal Period 2f Collateral Costs 1,415 297 1,712 1,712 1,478 311 1,789 1,789.113 Period 2fPeriod-Dependent Costs 2f.4.1 Insurance 319 45 364 364 334 47 380 380.455 2f.4.2 Property taxes 125 17 142 142 130 18 149 148.567 TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E Letter DCL-13-033 Document P01-1648-001, Rev. 0 Table C-2 Table C-2 Appendix C2, Page 6 of 8 Diablo Canyon Unit 2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate DEC ON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

Off-Site LLRW NRC Spent Fuel Off-Site LLRW NRC Spent Fuel Site I Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Decon Removal Packaging Transport Processing Disposal Other Total Total Lic_ Term_ Management Restoration Index Cost Cost Costs Costs Costs Costs Costs Contin encv Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs 2f.4.3 Health physics supplies 834 292 1,127 1,127 872 306 1,177 1,177.386 2f.4.4 Disposal ofDAW generated 27 11 49 49 9 3 31 12 54 54.322 2f.4.5 Plant energy budget 174 37 211 211 182 38 220 220.372 2f.4.6 NRC Fees 312 44 356 356 326 46 372 372.172 2f.4.7 Emergency Planning Fees 269 38 307 307 281 39 321 320.938 2f.4.8 Spent Fuel Transfer - Pool or ISFSI to DOE 1,130 238 1,368 1,368 1,181 248 1,429 1,429.356 2f.4.9 ISFSI Operating Costs 34 7 41 41 35 7 43 42.621 2f.4.10 Security Staff Cost 1,694 356 2,050 2,050 1,770 372 2,143 2,142.607 2f.4.11 DOC Staff Cost 4,689 986 5,675 5,675 4,900 1,031 5,931 5,930.855 2f.4.12 Utility Staff Cost 5,150 1,083 6,233 6,233 5,382 1,132 6,514 6,513.785 2£.4 Subtotal Period 2£ Period-Dependent Costs 834 27 13,897 3,154 17,924 16,208 1,716 872 9 31 14,523 3,296 18,733 16,940.522 1,792.915 2£.0 TOTAL PERIOD 2£ COST 834 27 29,889 9,583 40,345 38,629 1,716 872 9 31 31,234 10,014 42,163 40,370.353 1,792.915 PERIOD 2 TOTALS 9,816 70,926 28,855 14,141 105,405 510,074 195,310 934,527 831,404 90,569 10,258 74,118 30,154 14,777 121,426 533,028 204,099 987,859 880,095.884 94,644.162 13,119.282 PERIOD 3b - Site Restoration Period 3b Direct Decommissioning Activities Demolition of Remaining Site Buildings 3b.1.1.1 *Reactor 6,798 1,430 8,228 7,104 1,494 8,598 8,597.801 3b.1.1.2 Administration 1,067 224 1,291 1,115 234 1,349 1,349.170 3b.1.1.3 Auxiliary 6,587 1,385 7,972 6,883 1,447 8,330 8,330.418 3b. 1. 1.4 Capital Additions 85-2004 4,359 917 5,276 4,556 958 5,514 5,513.700 3b. 1. 1.5 Chemical Storage 4 5 5 1 6 5.637 3b. 1. 1.6 Chlorination 9 2 11 10 2 12 12.014 3b.1.1.7 Circulating Water Tunnels 1,153 243 1,396 1,205 253 1,459 1,458.827 3b.1.1.8 Cold Machine Shop 396 83 479 414 87 501 500.859 3b. 1. 1.9 Communication 4 1 5 4 5 5.395 3b.1.1.l0 Condensate PolishinglTechnical Support 870 183 1,053 909 191 1,100 1,100.449 3b.1.1.11 Containment Penetration Area 686 144 830 717 151 868 867.817 3b.1.1.12 Discharge Structure 937 197 1,134 979 206 1,185 1,185.470 3b.1.1.13 Fabrication Shop 120 25 145 125 26 152 151.827 3b.1.1.14 Fire Pump House 5 1 6 5 1 6 6.423 3b.1.1.15 Hazardous Waste Storage Facility 39 8 48 41 9 50 49.824 3b.1.1.16 Intake Structure 5,309 1,116 6,425 5,547 1,167 6,714 6,714.119 3b.1.1.17 Maintenance Shop 365 77 442 381 80 462 461.522 3b.1.1.18 Miscellaneous Structures 64 13 77 66 14 80 80.319 3b.1.1.19 NPO Permanent Warehouse 1,367 287 1,654 1,428 300 1,729 1,728.795 3b.1.1.20 Ponds 2 o 2 o 3 2.564 3b.1.1.21 Portable Fire Pump & Fuel Cart 1 o 2 o 1.632 3b.1.1.22 Pretreatment 10 2 12 10 2 12 12.446 3b.1.1.23 Radwaste Storage 1,777 374 2,150 1,857 390 2,247 2,247.115 3b.1.1.24 Radwaste Storage Facility (Additional) 49 10 60 51 11 62 62.209 3b.1.1.25 Rotor Warehouse 847 178 1,025 885 186 1,072 1,071.610 3b.1.1.26 Security 344 72 417 360 76 435 435.443 3b.1.1.27 Security Buildings (additional) 53 11 65 56 12 68 67.549 Demolition of Remaining Site Buildings (continued) 3b.1.1.28 Simulator 413 87 500 432 91 523 522.676 3b.1.1.29 Steam Generator Storage Facility 909 191 1,100 950 200 1,150 1,149.992 3b.1.1.30 Telephone Terminal 3 1 3 3 1 3 3.386 3b.1.1.31 Turbine 5,538 1,165 6,703 5,788 1,217 7,005 7,004.849 3b.1.1.32 Turbine Pedestal 1,318 277 1,596 1,378 290 1,668 1,667.533 3b.1.1.33 Vehicle Maintenance 34 7 41 36 8 43 43.172 3b.1.1.34 Waste Water Holding & Treatment Facility 23 5 27 24 5 29 28.625 3b.1.1.35 Fuel Handling 1,858 391 2,248 1,941 408 2,350 2,349.512 3b.1.1 Totals 43,321 9,110 52,431 45,270 9,520 54,791 54,790.700 Site Closeout Activities 3b.1.2 Grade & landscape site 2,758 580 3,338 2,882 606 3,488 3,487.914 3b.1. 3 Final report to NRC 98 21 119 119 103 22 124 124.135 3b.1 Subtotal Period 3b Activity Costs 46,079 98 9,711 55,888 119 48,152 103 10,148 58,403 124.135 58,278.614 Period 3b Additional Costs 3b.2.1 Backfill Structures & Remove Concrete Rubble 35,142 7,390 42,532 36,723 7,723 44,446 44,446.319 3b.2.2 Breakwater Demolition and Removal 41,893 14,684 56,577 43,778 15,344 59,122 59,122.443 3b.2.3 Cofferdam Construction and Teardown 478 101 579 500 105 605 604.933 3b.2.4 Concrete Crushing 9,113 5 1,917 11,035 9,523 2,004 11,532 11,531.911 3b.2.5 Disposal of Galbestos Siding 317 67 383 331 70 400 400.377 3b.2.6 Disposition of Mobile Barriers 1,318 277 1,595 1,377 290 1,667 1,666.958 3b.2.7 Soil 1 Sediment Control Plant Area 1,052 221 1,273 1,099 231 1,331 1,330.531 3b.2 Subtotal Period 3b Additional Costs 88,996 321 24,657 113,975 93,001 336 25,766 119,103 119,103.473 Period 3b Collateral Costs 3b.3.1 Small tool allowance 1,107 233 1,340 1,157 243 1,400 1,399.967 3b.3 Subtotal Period 3b Collateral Costs 1,107 233 1,340 1,157 243 1,400 1,399.967 Period 3b Period-Dependent Costs 3b.4.1 Insurance 525 74 598 598 548 77 625 625.335 3b.4.2 Property taxes 410 57 467 467 428 60 488 488.379 3b.4.3 Heavy equipment rental 7,347 1,545 8,892 7,678 1,615 9,293 9,292.567 TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E Letter DCL-13-033 Document P01-1S48-001, Rev. 0 Table C-2 Table C-2 Appendix C2, Page 7 of 8 Diablo Canyon Unit 2 Diablo Canyon Unit 2 DEC ON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars) (Thousands of 2013 Dollars)

O££-Site LLRW NRC Spent Fuel Off-Site LLRW NRC Spent Fuel Site Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Managemen Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Index Activit Descri tion Cost Cost Costs Costs Costs Costs Costs 'Contin Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs 3b.4.4 Plant energy budget 286 60 347 299 63 362 362.212 3b.45 NRC ISFSI Fees 348 49 397 397 364 51 415 414.531 3b.4.6 Emergency Planning Fees 885 124 1,010 1,010 925 130 1,055 1,055.011 3b.47 Spent Fuel Transfer - Pool or ISFSI to DOE 3,711 780 4,491 4,491 3,878 816 4,693 4,693.482 3b.4.8 ISFSI Operating Costs 111 23 134 134 116 24 140 140.106 3b.4.9 Security Staff Cost 5,569 1,171 6,740 5,459 5,819 1,224 7,043 5,705.099 1,338.233 3b.4.10 DOC Staff Cost 14,111 2,967 17,078 14,746 3,101 17,846 17,846.495 3b.411 Utility Staff Cost 7,357 1,547 8,904 1,781 7,688 1,617 9,305 1,860.910 7,443.642 3b.4 Subtotal Period 3b Period-Dependent Costs 7,347 33,312 8,399 49,058 14,338 7,678 34,811 8,777 51,266 14,982.852 36,283.150 3b.0 TOTAL PERIOD 3b COST 143,529 33,732 42,999 220,261 119 14,338 149,988 35,250 44,934 230,172 124.135 14,982.852 215,065.203 PERIOD 3c - Fuel Storage Operations/Shipping Period 3c Direct Decommissioning Activities Period 3c Period-Dependent Costs 3c.4.1 Insurance 3,099 434 3,534 3,534 3,238 454 3,693 3,692.521 3c.4.2 Property taxes 2,420 339 2,760 2,760 2,529 355 2,884 2,883.812 3c.4.3 Plant energy budget 3c.4.4 NRC ISFSI Fees 2,054 288 2,342 2,342 2,147 301 2,448 2,447.752 3c.4.5 Emergency Planning Fees 5,228 733 5,961 5,961 5,464 766 6,230 6,229.699 3c.4.6 Spent Fuel Transfer - Pool or ISFSI to DOE 21,995 4,625 26,620 26,620 22,984 4,834 27,818 27,817.891 3c.4.7 ISFSI Operating Costs 654 138 792 792 684 144 827 827.305 3c.4.8 Security Staff Cost 26,771 5,630 32,401 32,401 27,976 5,883 33,859 33,859.160 3c.4.9 Utility Staff Cost 8,802 1,851 10,654 10,654 9,198 1,934 11,133 11,132.906 3c.4 Subtotal Period 3c Period-Dependent Costs 71,024 14,039 85,063 85,063 74,220 14,671 88,891 88,891.045 3c.0 TOTAL PERIOD 3c COST 71,024 14,039 85,063 85,063 74,220 14,671 88,891 88,891.045 PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d.!'!'1 Vessel & Internals GTCC Disposal 2,500 9,179 2,281 13,960 13,960 2,613 10,574 2,383 15,570 15,570.267 3d.l.l Totals 2,500 9,179 2,281 13,960 13,960 2,613 10,574 2,383 15,570 15,570.267 3d. 1 Subtotal Period 3d Activity Costs 2,500 9,179 2,281 13,960 13,960 2,613 10,574 2,383 15,570 15,570.267 Period 3d Collateral Costs 3d.3 Subtotal Period 3d Collateral Costs Period 3d Period-Dependent Costs 3dA.1 Insurance 10 11 11 10 12 11.760 3d.4.2 Property taxes 8 9 9 8 9 9.184 3d.4.3 Plant energy budget 3d.4.4 NRC ISFSI Fees 1 7 7 7 7.493 3d.4.5 ISFSI Operating Costs 2 o 3 3 2 3 2.635 3d.4.6 Security Staff Cost 85 18 103 103 89 19 108 107.832 3d.4.7 Utility Staff Cost 28 6 34 34 29 6 35 35.455 3d.4 Subtotal Period 3d Period-Dependent Costs 139 28 167 167 146 29 174 174.358 3d.0 TOTAL PERIOD 3d COST 2,500 9,179 139 2,308 14,127 13,960 167 2,613 10,574 146 2,412 15,745 15,570.267 174.358 PERIOD 3e - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 3e Additional Costs 3e.2.1 ISFSI License Termination 40 6 14 393 622 286 1,362 1,362 42 15 453 650 299 1,465 1,465.032 3e.2 Subtotal Period 3e Additional Costs 40 6 14 393 622 286 1,362 1,362 42 15 453 650 299 1,465 1,465.032 Period 3e Collateral Costs 3e.3.1 Small tool allowance o o 0.739 3e.3 Subtotal Period 3e Collateral Costs o o 0.739 Period 3e Period-Dependent Costs 3e.41 Insurance 3e.4.2 Property taxes 55 8 63 63 57 8 65 65.369 3e.4.3 Heavy equipment rental 136 29 165 165 142 30 172 171.945 3e.4.4 Plant energy budget 3e.4.5 NRC ISFSI Fees 94 13 107 107 98 14 112 112.018 3e.4.6 Security Staff Cost 61 13 74 74 64 13 77 77.106 3e.4.7 Utility Staff Cost 163 34 198 198 171 36 206 206.446 3e.4 Subtotal Period 3e Period-Dependent Costs 136 373 97 606 606 142 390 101 633 632.884 3e.0 TOTAL PERIOD 3e COST 177 14 393 995 383 1,968 1,968 185 6 15 453 1,040 400 2,099 2,098.655 PERIOD 3£ - ISFSI Site Restoration Period 3£ Direct Decommissioning Activities Period 3f Additional Costs TLG Services, Inc.

Diablo Canyon Power Plant Enclosure 3 Decommissioning Cost Analysis PG&E Letter DCL-13-033 Document P01-1S48-001, Rev. 0 Table C-2 Table C-2 Appendix C2, Page 8 of 8 Diablo Canyon Unit 2 Diablo Canyon Unit 2 DEC ON Decommissioning Cost Estimate DECON Decommissioning Cost Estimate Activity Decon Removal (Thousands of 2011 Dollars)

Packaging Transport Off-Site Processing LLRW Disposal Other Total Total NRC Lie. Term.

Spent Fuel Management Decon Removal Packaging Transport Off-Site Processing (Thousands of 2013 Dollars)

LLRW Disposal Other Total Total NRC Lie. Term.

Spent Fuel Site Management Restoration Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs 3£.2.1 ISFSI Demolition and Site Restoration 1,371 27 294 1,692 1,692 1,433 28 307 1,768 1,767.747 3£.2.2 ISFSI Area Soil / Sediment Control 16 3 20 20 17 4 21 20.834 3£.2 Subtotal Period 3£ Additional Costs 1,387 27 297 1,712 1,712 1,450 28 311 1,789 1,788.582 Period 3£ Collateral Costs 3f.3.1 Small tool allowance 20 4 24 24 20 4 25 24.757 3f.3 Subtotal Period 3f Collateral Costs 20 4 24 24 20 4 25 24.757 Period 3£ Period-Dependent Costs 3£.4.1 Insurance 3£,4.2 Property taxes 28 4 32 32 29 4 33 32.955 3£.4.3 Heavy equipment rental 54 11 65 65 56 12 68 67.741 3£A.4 Plant energy budget 3£A.5 Security Staff Cost 11 2 14 14 12 2 14 14.135 3£A.6 Utility Staff Cost 69 14 83 83 72 15 87 86.949 3£A Subtotal Period 3f Period-Dependent Costs 54 108 32 193 193 56 112 33 202 201.779 3£.0 TOTAL PERIOD 3f COST 1,461 134 333 1,928 1,928 1,526 140 348 2,015 2,015.117 PERIOD 3 TOTALS 145,167 2,506 14 9,572 106,024 60,063 323,347 14,079 103,464 151,699 2,619 15 11,027 110,795 62,766 338,922 15,694.402 108,162.027 215,065.203 TOTAL COST TO DECOMMISSION 13,073 218,618 31,702 14,580 124,490 768,430 292,711 1,463,605 1,036,573 207,854 13,662 228,456 33,129 15,236 143,413 803,010 305,883 1,542,788 1,096,497.067 217,249.280 229,041.533 TOTAL COST TO DECOMMISSION WITH 25% CONTINGENCY: $1,463,605 thousands of 2011 dollars TOTAL NRC LICENSE TERMINATION COST IS 70.82% OR: $1,036,573 thousands of 2011 dollars SPENT FUEL MANAGEMENT COST IS 14.2% OR: $207,854 thousands of 2011 dollars NON-NUCLEAR DEMOLITION COST IS 14.98% OR: $219,178 thousands of 2011 dollars TOTAL SCRAP METAL REMOVED: 77,728 Tons TOTAL CRAFT LABOR REQUIREMENTS: 1,686,102 Man-hours End Notes:

nJa - indicates that this activity not charged as decommissioning expense.

a - indicates that this activity performed by decommissioning staff.

a - indicates that this value is less than a.5 but is non-zero.

a cell containing" - " indicates a zero value TLG Services, Inc.

Enclosure 4 PG&E Letter DCL-13-033 Decommissioning Cash Flow 2013 Dollars Diablo Canyon Power Plant Unit 1 (1 page)

Decommissioning Cash Flow 2013 Dollars Diablo Canyon Power Plant Unit 2 (1 page)

Enclosure 4 PG&E Letter DCL-13-033 Diablo Canyon Power Plant - Unit 1 Decommissioning Cash Flow (Note 1)

Estimated in 2013 Dollars Cummulative NRC Scope Non-NRC Scope Spent Fuel Decommissioning Trust Account Year (Radiological) (Non-Radiological) Management Total Estimate Funding 2024 $26A79A98 $136,124 $1,865,698 $28A81,320 $28A81,320 2025 $158,025,627 $1,314,337 $16A31,182 $175,771,146 $204)52A65 2026 $176,658,846 $2A95,965 $23,175,197 $202,330,008 $406,582A73 2027 $176,748,743 $2,968,558 $24J62,074 $204A79,375 $611,061,848 2028 $112,326,527 $3,931,038 $11,616,202 $127,873,767 $738,935,615 2029 $111,975,770 $3,931,038 $11,616,202 $127,523,010 $866A58,626 $831,654A85 2030 $52,615A95 $1,335A76 $8,958,805 $62,909,776 $929,368A01 $920,843,822 2031 $22A77,699 $7,591,515 $30,069,214 $959A37,615 2032 $22,560,633 $7,591,515 $30,152,148 $989,589,763 2033 $22A77,699 $7,591,515 $30,069,214 $1,019,658,977 2034 $22A77,699 $7,591,515 $30,069,214 $1,049,728,191 2035 $22A77,699 $7,591,515 $30,069,214 $1,079,797A04 2036 $22,560,633 $7,591,515 $30,152,148 $1,109,949,552 2037 $53,098,748 $5,779,975 $58,878,723 $1,168,828,275 2038 $44,721A37 $3AOO,545 $2,879,812 $51,001,794 $1,219,830,069 2039 $2,576 $24,749,777 $6,070,050 $30,822A03 $1,250,652A72 2040 $80,903 $24,756,911 $6,070,050 $30,907,864 $1,281,560,336 2041 $2,576 $8,340,686 $6,086,854 $14A30,116 $1,295,990A52 2042 $2,576 $6,095,500 $6,098,076 $1,302,088,528 2043 $2,576 $6,095,500 $6,098,076 $1,308,186,603 2044 $19,313 $6,095,502 $6,114,815 $1,314,301A18 2045 $2,576 $6,095,500 $6,098,076 $1,320,399A94 2046 $2,576 $6,095,500 $6,098,076 $1,326A97,569 2047 $2,576 $6,095,500 $6,098,076 $1,332,595,645 2048 $19,313 $6,095,502 $6,114,815 $1,338,710A60 2049 $2,576 $6,095,500 $6,098,076 $1,344,808,535 2050 $2,576 $6,095,500 $6,098,076 $1,350,906,611 2051 $2,576 $6,095,500 $6,098,076 $1,357,004,686 2052 $19,313 $6,095,502 $6,114,815 $1,363,119,501 2053 $2,576 $6,095,500 $6,098,076 $1,369,217,577 2054 $2,576 $6,095,500 $6,098,076 $1,375,315,652 2055 $14A84,673 $5,992,778 $20A77A51 $1,395,793,103 2056 -$13A59 $4,134,185 $4,120,726 $1,399,913,830 TOTAL $1,062,323,715 $77,360A55 $260,229,660 $1,399,913,830 NOTES:

1) Cash Flow is based on construction of Independent Spent Fuel Storage Installation (ISFSI) and assumes Department of Energy (DOE) Used Fuel Repository opens in 2024.
2) Trust Account Value of $920.8 million Market Value as of 12/31/12.

Trust Account Value of $831.7 million Liquidation Value as of 12/31/12.

Page 1 of 1

Enclosure 4 PG&E Letter DCL-13-033 Diablo Canyon Power Plant - Unit 2 Decommissioning Cash Flow (Note 1)

Estimated in 2013 Dollars Cummulative NRC Scope Non-NRC Scope Spent Fuel Decommissioning Trust Account Year Radiological) (Non-Radiological) Management Total Estimate Funding 2025 $49,029,734 $125,110 $3,285,185 $52,440,029 $52,440,029 2026 $134,075,307 $583,475 $9,665,770 $144,324,552 $196,764,581 2027 $172,483,925 $2,434,868 $6,886,536 $181,805,329 $378,569,909 2028 $168,475,912 $2,917,279 $7,518,145 $178,911,336 $557,481,245 2029 $127,400,028 $3,675,789 $11,369,307 $142,445,124 $699,926,369 2030 $127,400,028 $3,675,789 $11,369,307 $142,445,124 $842,371,493 2031 $44,063,757 $563,957 $8,739,189 $53,366,903 $895,738,396 2032 $29,403,421 $8,262,534 $37,665,955 $933,404,350 2033 $29,300,432 $8,262,534 $37,562,966 $970,967,317 2034 $29,300,432 $8,262,534 $37,562,966 $1,008,530,283 2035 $29,300,432 $8,262,534 $37,562,966 $1,046,093,249 2036 $29,403,421 $8,262,534 $37,665,955 $1,083,759,203 2037 $63,201,408 $6,718,560 $69,919,968 $1,153,679,171 2038 $52,859,967 $13,106,933 $3,035,610 $69,002,510 $1,222,681,682 2039 $53,851 $86,307,846 $6,056,192 $92,417,889 $1,315,099,571 2040 $29,870 $86,585,403 $6,056,192 $92,671,465 $1,407,771,036 2041 $40,414 $29,065,020 $6,072,955 $35,178,389 $1,442,949,425 2042 $3,941 $6,081,580 $6,085,521 $1,449,034,946 2043 $3,941 $6,081,580 $6,085,521 $1,455,120,467 2044 $20,680 $6,081,580 $6,102,260 $1,461,222,727 2045 $3,941 $6,081,580 $6,085,521 $1,467,308,248 2046 $3,941 $6,081,580 $6,085,521 $1,473,393,769 2047 $3,941 $6,081,580 $6,085,521 $1,479,479,290 2048 $20,680 $6,081,580 $6,102,260 $1,485,581,550 2049 $3,941 $6,081,580 $6,085,521 $1,491,667,071 2050 $3,941 $6,081,580 $6,085,521 $1,497,752,592 2051 $3,941 $6,081,580 $6,085,521 $1,503,838,113 2052 $20,680 $6,081,580 $6,102,260 $1,509,940,374 2053 $3,941 $6,081,580 $6,085,521 $1,516,025,895 2054 $3,941 $6,081,580 $6,085,521 $1,522,111,416 2055 $14,458,874 $5,979,092 $20,437,966 $1,542,549,382 2056 -$12,776 $4,124,028 $4,111,252 $1,546,660,634 TOTAL $1,100,369,887 $229,041,469 $217,249,278 $1,546,660,634 NOTES:

1) Cash Flow is based on construction of ISFSI and assumes DOE Used Fuel Repository opens in 2024.
2) Trust Account Value of $1,221.1 million Market Value as of 12/31/12.

Trust Account Value of $1,101.5 million Liquidation Value as of 12/31/12.

Page 1 of 1

Enclosure 5 PG&E Letter DCL-13-033 Decommissioning Cost Analysis for the Diablo Canyon Power Plant (TLG Services, Inc.)

(138 pages)

Document POl-1648-001, Rev. 0 DECOMMISSIONING COST ANALYSIS for the DIABLO CANYON POWER PLANT prepared for Pacific Gas and Electric Company prepared by TLG Services, Inc.

Bridgewater, Connecticut December 2012

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Page ii of xix APPROVALS Project Manager Geoffr Date Proj ect Engineer 'wk~g2v William J. Di z 1?5 :De~

Date Loll.-

Technical Manager TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Page iii of xix TABLE OF CONTENTS SECTION PAGE EXECUTIVE

SUMMARY

................................................................................. vii-xix

1. INTRODUCTION ................................................................................................... 1-1 1.1 Objectives of Study ......................................................................................... 1-1 1.2 Site Description .............................................................................................. 1-2 1.3 Regulatory Guidance ...................................................................................... 1-3 1.3.1 Nuclear Waste Policy Act .................................................................... 1-5 1.3.2 Low-Level Radioactive Waste Acts ..................................................... 1-6 1.3.3 Radiological Criteria for License Termination .................................. 1-7
2. DECOMMISSIONING ALTERNATIVES ............................................................. 2-1 2.1 DECON ........................................................................................................... 2-2 2.1.1 Period 1 - Preparations ........................................................................ 2-3 2.1.2 Period 2 - Decommissioning Operations ............................................ 2-5 2.1.3 Period 3 - Site Restoration .................................................................. 2-8 2.1.4 ISFSI Operations and Decommissioning ........................................... 2-9 2.2 SAFSTOR ........................................................................................................ 2-9 2.2.1 Period 1 - Preparations ...................................................................... 2-10 2.2.2 Period 2 - Dormancy .......................................................................... 2-11 2.2.3 Periods 3 and 4 - Delayed Decommissioning ................................... 2-12 2.2.4 Period 5 - Site Restoration ................................................................ 2-13
3. COST ESTIMATES ................................................................................................ 3-1 3.1 Basis of Estimates .......................................................................................... 3-1 3.2 Methodology .................................................................................................... 3-1 3.3 Impact of Decommissioning Multiple Reactor Units .................................... 3-3 3.4 Financial Components of the Cost Model. ..................................................... 3-4 3.4.1 Contingency ......................................................................................... 3-5 3.4.2 Financial Risk ...................................................................................... 3-6 3.5 Site-Specific Considerations ........................................................................... 3-7 3.5.1 Spent Fuel Management ..................................................................... 3-8

-3.5.2 Reactor Vessel and Internal Components ........................................ 3-10 3.5.3 Primary System Components ........................................................... 3-11 3.5.4 Main Turbine and Condenser ........................................................... 3-13 3.5.5 Retired Components .......................................................................... 3-13 3.5.6 Transportation Methods ................................................................... 3-13 TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1 648-00 1, Rev. 0 Decommissioning Cost Analysis Page iv of xix TABLE OF CONTENTS (continued)

SECTION PAGE 3.5.7 Low-Level Radioactive Waste Disposal. ........................................... 3-14 3.5.8 Site Restoration Following License Termination ............................ 3-15 3.6 Assumptions .................................................................................................. 3-16 3.6.1 Estimating Basis ............................................................................... 3-16 3.6.2 Labor Costs ........................................................................................ 3-16 3.6.3 Design Conditions .............................................................................. 3-17 3.6.4 General ............................................................................................... 3-18 3.7 Cost Estimate Summary ............................................................................. 3-20

4. SCHEDULE ESTIMATE ...................................................................................... 4-1 4.1 Schedule Estimate Assumptions ................................................................... 4-1 4.2 Project Schedule .............................................................................................. 4-2
5. RADIOACTIVE WASTES ...................................................................................... 5-1
6. RESULTS .............................................................................................................. 6-1
7. REFERENCES ........................................................................................................ 7-1 TABLES DECON Cost Summary Decommissioning Cost Elements ............................ xvii SAFSTOR Cost Summary Decommissioning Cost Elements ...................... xviii DECON Cost Summary Yr License Renewal Decommissioning Cost Elements ........................................................................................................... xix 3.1 DECON Alternative, Schedule of Total Annual Expenditures, Unit 1 ........ 3-22 3.2 DECON Alternative, Schedule of Total Annual Expenditures, Unit 2 ........ 3-24 3.3 SAFSTOR Alternative, Schedule of Total Annual Expenditures, Unit 1 .... 3-26 3.4 SAFSTOR Alternative, Schedule of Total Annual Expenditures, Unit 2 .... 3-28 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Page v of xix TABLE OF CONTENTS (continued)

SECTION PAGE TABLES (continued) 5.1 DECON Alternative, Decommissioning Waste Summary, Unit 1 ................ 5-4 5.2 DECON Alternative, Decommissioning Waste Summary, Unit 2 ................ 5-5 5.3 SAFSTOR Alternative, Decommissioning Waste Summary, Unit 1 ............. 5-6 5.4 SAFSTOR Alternative, Decommissioning Waste Summary, Unit 2 ............. 5-7 6.1 DECON Alternative Decommissioning Cost Elements, Unit 1 ..................... 6-4 6.2 DECON Alternative Decommissioning Cost Elements, Unit 2 ..................... 6-5 6.3 SAFSTOR Alternative Decommissioning Cost Elements, Unit 1 ................. 6-6 6.4 SAFSTOR Alternative Decommissioning Cost Elements, Unit 2 ................. 6-7 FIGURES 1.1 Diablo Canyon Power Plant General Plan ..................................................... 1-9 1.2 Diablo Canyon Power Plant Aerial View ....................................................... 1-10

1. 3 Diablo Canyon Power Plant Reactor Building Section ................................. 1-11 4.1 Activity Schedule - DECON ............................................................................ 4-3 4.2 DECON Alternative Decommissioning Timeline ........................................... 4-5 4.3 SAFSTOR Alternative Decommissioning Timeline ....................................... 4-6 APPENDICES A. Unit Cost Factor Development ............................................................................ A-1 B. Unit Cost Factor Listing ..................................................................................... B-1 C. Detailed Cost Analysis, DECON ......................................................................... C-1 D. Detailed Cost Analysis, SAFSTOR .................................................................... D-1 E. Detailed Cost Analysis, DECON Year License Renewal. .......................... E-1 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Page vi of xix REVISION LOG No. Date Item Revised I Reason for Revision I

0 12/18/2012 Original Issue TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Page vii of xix EXECUTIVE

SUMMARY

This report presents estimates of the cost to decommission the Diablo Canyon Power Plant (Diablo Canyon) for the selected decommissioning scenarios following the scheduled cessation of plant operations. The estimates are designed to provide the Pacific Gas and Electric Company (PG&E) with the information to assess its current decommissioning liability, as it relates to Diablo Canyon.

The analysis relies upon site-specific, technical information from an evaluation prepared in 2009,[1] updated to reflect current assumptions pertaining to the disposition of the nuclear plant and relevant industry experience in undertaking such projects. The costs are based on several key assumptions in areas of regulation, component characterization, high-level radioactive waste management, low-level radioactive waste disposal, performance uncertainties (contingency) and site restoration requirements. The plant inventory, the basis for the decontamination and dismantling requirements and cost, and the decommissioning waste streams, were reviewed for this analysis. Significant "physical" changes reflected in the estimates include:

  • Reclassifying all concrete located within the containment liner as likely low-level waste. This eliminates decontamination of concrete in containment and reduces final status survey costs.
  • Reclassifying the turbine, condenser, and associated systems from potentially contaminated to likely clean.
  • Removing all demolished concrete from the station and disposing of it off-site in lieu of using the demolished concrete as on site filL
  • Updating material inventories associated with updated security barriers.

The analysis is not a detailed engineering evaluation, but an estimate prepared in advance of the detailed engineering required to carry out the decommissioning of the nuclear unit. It may also not reflect the actual plan to decommission Diablo Canyon; the plan may differ from the assumptions made in this analysis based on facts that exist at the time of decommissioning.

The costs to decommission Diablo Canyon for the scenarios evaluated are tabulated at the end of this section. Costs are reported in 2011 dollars and include monies anticipated to be spent for radiological remediation and operating license termination, spent fuel management, and site restoration activities.

"Decommissioning Cost Analysis for the Diablo Canyon Power Plant," Document POl-1604-003, Rev. 0, TLG Services, Inc., March 2009.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Page viii of xix A complete discussion of the assumptions relied upon in this analysis is provided in Section 3, along with schedules of annual expenditures for each scenario. A sequence of significant project activities is provided in Section 4 with a time line for each scenario. Detailed cost reports used to generate the summary tables contained within this document are provided in Appendices C through E.

Consistent with the 2009 analysis, the current cost estimates assume that the shutdown of the nuclear unit is a scheduled and pre-planned event (e.g., there is no delay in transitioning the plant and workforce from operations or in obtaining regulatory relief from operating requirements, etc.). The estimates include the continued operation of the fuel handling areas as an interim wet fuel storage facility for approximately twelve years after operations cease. [2] During this time period, it is assumed that the spent fuel residing in the pools will be transferred to an independent spent fuel storage installation (ISFSI) located on the site. The ISFSI will remain operational until the Department of Energy (DOE) is able to complete the transfer of the fuel to a federal facility. The estimates also include the dismantling of site structures and non-essential facilities and the limited restoration of the site.

Alternatives and Regulations The Nuclear Regulatory Commission (NRC) provided general decommissioning requirements in a rule adopted on June 27, 1988. [3] In this rule, the NRC set forth technical and financial criteria for decommissioning licensed nuclear facilities. The regulations addressed planning needs, timing, funding methods, and environmental review requirements for decommissioning. The rule also defined three decommissioning alternatives as being acceptable to the NRC: DECON, SAFSTOR, and ENTOMB.

DECON is defined as "the alternative in which the equipment, structures, and portions of a facility and site containing radioactive contaminants are removed or decontaminated to a level that permits the property to be released for unrestricted use shortly after cessation of operations. "[4]

2 The current Part 72 ISFSI license does not allow dry cask storage of spent fuel with burnups above 45,000 MWD/metric ton. It is assumed that PG&E can amend the Part 72 license to store the higher burnup fuel, but that as a condition of the amendment it will require longer decay times (12 years) before storing the spent fuel in the casks.

3 U.S. Code of Federal Regulations, Title 10, Parts 30, 40, 50, 51, 70 and 72 "General Requirements for Decommissioning Nuclear Facilities," Nuclear Regulatory Commission, Federal Register Volume 53, Number 123 (p 24018 et seq.), June 27, 1988 4 Ibid. Page FR24022, Column 3 TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Page ix of xix SAFSTOR is defined as "the alternative in which the nuclear facility is placed and maintained in a condition that allows the nuclear facility to be safely stored and subsequently decontaminated (deferred decontamination) to levels that permit release for unrestricted use. "[5]

Decommissioning is required to be completed within 60 years, although longer time periods will be considered when necessary to protect public health and saf~ty.

ENTOMB is defined as "the alternative In which radioactive contaminants are encased in a structurally long-lived material, such as concrete; the entombed structure is appropriately maintained and continued surveillance is carried out until the radioactive material decays to a level permitting unrestricted release of the property."[6] As with the SAFSTOR alternative, decommissioning is currently required to be completed within 60 years, although longer time periods will also be considered when necessary to protect public health and safety.

The 60-year restriction has limited the practicality for the ENTOMB alternative at commercial reactors that generate significant amounts of long-lived radioactive material. In 1997, the Commission directed its staff to re-evaluate this alternative and identify the technical requirements and regulatory actions that would be necessary for entombment to become a viable option. The resulting evaluation provided several recommendations, however, rulemaking has been deferred pending the completion of additional research studies (e.g., on engineered barriers).

In 1996, the NRC published revisions to its general requirements for decommissioning nuclear power plants to clarify ambiguities and codify procedures and terminology as a means of enhancing efficiency and uniformity in the decommissioning processJ7] The amendments allow for greater public participation and better define the transition process from operations to decommissioning. Regulatory Guide 1.184, issued in July 2000, further described the methods and procedures that are acceptable to the NRC staff for implementing the requirements of the 1996 revised rule that relate to the initial activities and the major phases of the decommissioning process. The costs and schedules presented in this analysis follow the general guidance and sequence in 5 Ibid.

6 Ibid. Page FR24023, Column 2 7 U.S. Code of Federal Regulations, Title 10, Parts 2, 50, and 51, "Decommissioning of Nuclear Power Reactors," Nuclear Regulatory Commission, Federal Register Volume 61, (p 39278 et seq.), July 29, 1996 TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Page x of xix the amended regulations. The format and content of the estimates is also consistent with the recommendations of Regulatory Guide 1.202, issued February 2005. [8]

Decommissioning Scenarios Two basic decommissioning scenarios are evaluated for the two nuclear units. The scenarios selected are representative of alternatives available to the owner and are defined as follows:

DECON: The operating licenses for Units 1 and 2 currently expire in November 2024 and August 2025, respectively. The first scenario assumes that decommissioning activities at the two units are sequenced and integrated so as to minimize the total duration of the physical dismantling processes. Any residual spent fuel is transferred to the ISFSI to facilitate decontamination and dismantling activities within the fuel handling building. Spent fuel storage operations continue at the site until the transfer of the fuel to the DOE is complete in year 2055.

SAFSTOR: The units are placed into safe-storage in the second scenario. Spent fuel remaining in the spent fuel storage pools after a minimum cooling period of 12 years is transferred to the ISFSI for interim storage. The length of SAFSTO R dormancy is based on spent fuel storage operations. Physical dismantling of the station is assumed to commence after all spent fuel has been removed from the station in 2055. As with the DECON scenario, decommissioning activities at the two units are sequenced and integrated so as to minimize the total duration of the physical dismantling processes.

An alternative decommissioning scenario was also evaluated for the units; decommissioning after renewing the license for 20 years. A summary of the two basic and an alternate scenario are shown below.

Unit 1/2 Scenario Name Type Basis 1 Results Shutdown Dates DECON Basic 2024/2025 Body of Report SAFSTOR Basic 2024/2025 Body of Report DECON (20-Year Alternative 2044/2045 Appendix E License Renewal) 8 "Standard Format and Content of Decommissioning Cost Estimates for Nuclear Power Reactors,"

Regulatory Guide 1.202, Nuclear Regulatory Commission, February 2005 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Page xi of xix Methodology The methodology used to develop the estimates follows the basic approach originally presented in the cost estimating guidelines [9] developed by the Atomic Industrial Forum (now Nuclear Energy Institute). This reference describes a unit cost factor method for estimating decommissioning activity costs. The unit cost factors used in this analysis incorporate site-specific costs and the latest available information about worker productivity in decommissioning.

An activity duration critical path is used to determine the total decommissioning program schedule. This is required for calculating the carrying costs, which include program management, administration, field engineering, equipment rental, quality assurance, and security. This systematic approach for assembling decommissioning estimates ensures a high degree of confidence in the reliability of the resulting costs.

The estimates also reflect lessons learned from previously completed decommissioning projects, including TLG's involvement in the Shippingport Station decommissioning, completed in 1989, and the decommissioning of the Cintichem reactor, hot cells and associated facilities, completed in 1997. In addition, the planning and engineering for the Pathfinder, Shoreham, Rancho Seco, Trojan, Yankee Rowe, Big Rock Point, Maine Yankee, Humboldt Bay-3, Connecticut Yankee and San Onofre-1 nuclear units have provided additional insight into the process, the regulatory aspects, and technical challenges of decommissioning commercial nuclear units.

Contingency Consistent with cost estimating practice, contingencies are applied to the decontamination and dismantling costs developed as "specific provision for unforeseeable elements of cost within the defined project scope, particularly important where previous experience relating estimates and actual costs has shown that unforeseeable events which will increase costs are likely to occur." [10] The cost elements in the estimates are based on ideal conditions; therefore, the types of unforeseeable events that are almost certain to occur in decommissioning, based on industry experience, are addressed through a percentage contingency applied on a line-item basis. This contingency factor is a nearly universal element in all large-scale construction and demolition projects. It should be noted that contingency, as used in this analysis, is based on a preliminary technical position [11] to reflect the California 9 T.S. LaGuardia et aI., "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates," AIF/NESP-036, May. 1986 10 Project and Cost Engineers' Handbook, Second Edition, American Association of Cost Engineers, Marcel Dekker, Inc., New York, New York, p. 239.

11 "Technical Position Paper for Establishing an Appropriate Contingency Factor for Inclusion in the TLG Services, Inc.

Diablo Canyon Power Plant Document P01-1 648-00 1, Rev. 0 Decommissioning Cost Analysis Page xii of xix Public Utilities Commission's desire for owners to conservatively establish an appropriate contingency factor for inclusion in the decommissioning revenue requirements.

Contingency funds are expected to be fully expended throughout the program. As such, inclusion of contingency is necessary to provide assurance that sufficient funding will be available to accomplish the intended tasks.

Low -Level Radioactive Waste Disposal The contaminated and activated material generated in the decontamination and dismantling of a commercial nuclear reactor is generally classified as low-level radioactive waste, although not all of the material is suitable for shallow-land disposal. With the passage of the "Low-Level Radioactive Waste Disposal Act" in 1980 and its Amendments of 1985, [12] the states became ultimately responsible for the disposition of low-level radioactive waste generated within their own borders.

For the purpose of this analysis, the EnergySolutions' facility is used as the disposal site for the majority of the radioactive waste (Class A). The disposal costs for Class A low-level radioactive waste are based on a study' sponsored by PG&E and Southern California Edison Company, "Establishing an Appropriate Disposal Rate for Low Level Radioactive Waste During Decommissioning", [13] escalated to year 2011 dollars.

For the purpose of this analysis, the Waste Control Specialists (WCS) facility in Andrews County, TX is used as the disposal site for the higher radioactivity Class B and C waste. In the prior 2008 decommissioning analysis the disposal rate for these waste classes were based on the previously cited study which was based on published Barnwell rates. A change in location was designated with the current analysis since Barnwell is not open to California generators, and with the exception of Texas, where WCS recently declared the site operational in November 2011; no new compact facilities have been successfully sited, licensed, and constructed. WCS will be able to accept limited quantities of non-Compact waste, although at this time the cost for non-Compact generators is being negotiated on an individual basis. The cost used in this estimate is a blended combination of preliminary information for the two WCS Class Band C rates. It should be noted that PG&E has a contract with Decommissioning Revenue Requirements", Study Number: DECON-POS-H002, Revision A, Status:

Preliminary (provided by PG&E).

12 "Low-Level Radioactive Waste Policy Amendments Act of 1985," Public Law 99-240, January 15, 1986 13 "Establishing an Appropriate Disposal Rate for Low Level Radioactive Waste During Decommissioning", Robert A Snyder NEWEX, Revision 0, July 2008 (provided by PG&E).

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Page xiii of xix WCS to dispose of Class Band C waste originating from Humboldt Bay 3. This contract requires waste delivery by April 2013.

The dismantling of the components residing closest to the reactor core generates radioactive waste that may be considered unsuitable for shallow-land disposal (i.e.,

low-level radioactive waste with concentrations of radionuclides that exceed the limits established by the NRC for Class C radioactive waste (GTCC>>. The Low-Level Radioactive Waste Policy Amendments Act of 1985 assigned the federal government the responsibility for the disposal of this materiaL The Act also stated that the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste. However, to date, the federal government has not identified a cost for disposing of GTCC or a schedule for acceptance.

For purposes of this analysis, the GTCC radioactive waste is assumed to be packaged and disposed of in a similar manner as high-level waste and at a cost equivalent to that envisioned for the spent fueL The GTCC is packaged in the same canisters used for spent fuel and either stored on site or shipped directly to a DOE facility as it is generated (depending upon the timing of the decommissioning and whether the spent fuel has been removed from the site prior to the start of decommissioning) .

High-Level Radioactive Waste Management Congress passed the "Nuclear Waste Policy Act"[14] (NWPA) in 1982, assigning the federal government's long-standing responsibility for disposal of the spent nuclear fuel created by the commercial nuclear generating plants to the DOE. The NWPA provided that DOE would enter into contracts with utilities in which DOE would promise to take the utilities' spent fuel and high-level radioactive waste and utilities would pay the cost of the disposition services for that material. The NWPA, along with the individual contracts with the utilities, specified that the DOE was to begin accepting spent fuel by January 31, 1998.

Since the original legislation, the DOE has announced several delays in the program schedule. By January 1998, the DOE had failed to accept any spent fuel or high level waste, as required by the NWPA and utility contracts. To date no progress in the removal of spent fuel from commercial generating sites has been made. Delays continue and, as a result, generators have initiated legal action against the DOE in an attempt to obtain compensation for DOE's breach of contract.

14 "Nuclear Waste Policy Act of 1982 and Amendments," DOE's Office of Civilian Radioactive Management, 1982 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Page xiv of xix It is necessary that spent fuel be cooled and stored for a minimum period at the generating site prior to transfer. As such, the NRC requires that licensees establish a program to manage and provide funding for the management of all irradiated fuel at the reactor site until title of the fuel is transferred to the Secretary of Energy, pursuant to 10 CFR Part 50.54(bb)J15] This funding requirement is fulfilled through inclusion of certain cost elements in the decommissioning estimates, for example, associated with the isolation and continued operation of the spent fuel pools and the ISFSI.

PG&E's current spent fuel management plan for the Diablo Canyon spent fuel is based upon the DOE accepting spent fuel from commercial generators starting in year 2024, and accepting it at a rate which removes all spent fuel from the station by year 2055.

The DOE's generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. For purposes of this analysis, the first assemblies removed from the Diablo Canyon site are assumed to be in 2033. With an estimated average rate of transfer of 6 canisters (192 spent fuel assemblies) per year, completion of the removal of fuel from the site is projected to be in the year 2055.

Consequently, costs are included within the estimates for the long-term caretaking of the spent fuel at the Diablo Canyon site until the year 2055.

An ISFSI, which is independently licensed and operated, will remain operational after the cessation of plant operations. For the DECON and SAFSTOR scenarios, the facility is project to have the capacity to accommodate the inventory of spent fuel residing in the plant's storage pools at the conclusion of the required cooling period. Once emptied, the spent fuel pool facilities can be either decontaminated and dismantled or prepared for long-term storage.

Site Restoration The efficient removal of the contaminated materials at the site may result in damage to many of the site structures. Blasting, coring, drilling, and the other decontamination activities can substantially damage power block structures, potentially weakening the footings and structural supports. It is unreasonable to anticipate that these structures would be repaired and preserved after the radiological contamination is removed. The cost to dismantle site structures with a work force already mobilized is more efficient and less costly than if the process is deferred. Consequently, this study assumes that non-essential site structures addressed by this analysis are removed to a nominal depth of three feet below the 15 U.S. Code of Federal Regulations, Title 10, Part 50, "Domestic Licensing of Production and Utilization Facilities," Subpart 54 (bb), "Conditions of Licenses."

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Page xv of xix local grade level wherever possible. The site is then graded and stabilized. As previously noted an additional site restoration alternative has been evaluated in this analysis, where all below grade concrete is demolished and removed off site.

Summary The estimates to decommission Diablo Canyon assume the removal of all contaminated and activated plant components and structural materials such that the owner may then have unrestricted use of the site with no further requirements for an operating license. Low-level radioactive waste, other than GTCC waste, is sent to a commercial processor for treatment/conditioning or to a controlled disposal facility.

Decommissioning is accomplished within the 60-year period required by current NRC regulations. In the interim, the spent fuel remains in storage at the site until such time that the transfer to a DOE facility is complete. Once emptied, the storage facility can also be decommissioned.

Both the DECON and SAFSTOR scenarIOS are described in Section 2. The assumptions are presented in Section 3, along with schedules of annual expenditures.

The major cost contributors are identified in Section 6, with detailed activity costs, waste volumes, and associated manpower requirements delineated in Appendices C and D. The alternative scenario is contained in Appendix E DECON scenario 20-year license renewal. The major cost components for all scenarios are also identified in the cost summary provided at the end of this section.

The cost elements in the estimates for all the decommissioning alternatives are assigned to one of three subcategories: NRC License Termination (radiological remediation), Spent Fuel Management, and Site Restoration. The subcategory "NRC License Termination" is used to accumulate costs that are consistent with "decommissioning" as defined by the NRC in its financial assurance regulations (i.e., 10 CFR §50.75). The cost reported for this subcategory is generally sufficient to terminate the unit's operating license, recognizing that there may be some additional cost impact from spent fuel management.

The "Spent Fuel Management" subcategory contains costs associated with the containerization and transfer of spent fuel from the wet storage pool to a DOE transport cask or to the ISFSI for interim storage, as well as the transfer of the spent fuel in storage at the ISFSI to the DOE. Costs are included for the operation of the storage pool and the management of the ISFSI until such time that the transfer is complete. It does not include any spent fuel management expenses incurred prior to the cessation of plant operations, nor does it include any costs related to the final disposal of the spent fueL TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Page xvi of xix "Site Restoration" is used to capture costs associated with the dismantling and demolition of buildings and facilities demonstrated to be free from contamination.

This includes structures never exposed to radioactive materials, as well as those facilities that have been decontaminated to appropriate levels. Structures are removed to a depth of three feet and backfilled to conform to local grade.

It should be noted that the costs assigned to these subcategories are allocations.

Delegation of cost elements is for the purposes of comparison (e.g., with NRC financial guidelines) or to permit specific financial treatment (e.g., Asset Retirement Obligation determinations). In reality, there can be considerable interaction between the activities in the three subcategories. For example, an owner may decide to remove non-contaminated structures early in the project to improve access to highly contaminated facilities or plant components. In these instances, the non-contaminated removal costs could be reassigned from Site Restoration to an NRC License Termination support activity. However, in general, the allocations represent a reasonable accounting of those costs that can be expected to be incurred for the specific subcomponents of the total estimated program cost, if executed as described.

As noted within this document, the estimates were developed and costs are presented in 2011 dollars. As such, the estimates do not reflect the escalation of costs (due to inflationary and market forces) over the remaining operating life of the plant or during the decommissioning period.

TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Page xvii of xix DECON COST

SUMMARY

DECOMMISSIONING COST ELEMENTS (thousands of 2011 dollars)

Cost Element Unit 1 Unit 2 Total l Decontamination 17,296 I 20,420 37,715 Removal

.--.---.----.-.--------.--.------......-------.-----.----..- .....- ....--..- - - - -..- - - -..- - f - - - - - - - - - - - - .--..---.------.-.-.-.--

129,569 I 283,111 412,680 Packaging 40,268 I 39,786 80,054 Transportation __ 18,060 I 17,954 36,014

-_Waste

.._..._-_.----_._._.-..Disposal _-- _._---------_._----_..__.__._--_..- 175,448 I ..._171,400

+_ 346,848 Program Management [1] 315,3341 368,348 683,682 Security 273,454 I 258,268 531,722 Spent Fuel Pool Isolation 24,045 I 15,996 40,041 Spent Fuel Management [2] 187,973 I 147,039 335,012 Insurance and Regulatory Fees 21,214 I 18,358 39,571 E*~;~gy**-*****-***--*-**--**----***-*--******-*--*-*---- . . -.. --.-.-. --.._.---.-.-.. ._-..--..-.. .-._-..--.. .----..--.. . -..-.--. -*-****--*---1~3*3il*-***--*-**-*-*-*-io:-o83**-* '-"-'-"--"'--'-2o~~i13-Characterization and Licensing Surveys 21,372 I 24,739 46,111 Property Taxes 5,987 I 5,825 11,812

Severance 74,2691 74,113 148,382 LMis.c:ill~~_l!.~q~ _________ ~~_~~ ____ ~_
  • Total [3] 1,322,468 I 1,463,605 2,786,073

! Cost Element License

-........~---

Termination 999,926 ._._. ___. . . .!?_Q?_2?_~_7_~._. _. __. . . . _gLQ~~L1~~. .

Spent Fuel Management 248,912 207,854 456,766 Site Restoration 73,630 219,178 292,809

, Total [3] 1,322,468 1,463,605 2,786,073

[1] Includes engineering costs

[2] Excludes program management costs (staffing) but includes costs for spent fuel loading/transfer/spent fuel pool O&M and EP fees

[3] Columns may not add due to rounding TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Page xviii of xix SAFSTOR COST

SUMMARY

DECOMMISSIONING COST ELEMENTS (thousands of 2011 dollars)

Cost Element Unit 1 Unit 2 Total Decontamination 13,853 20,517 34,370 Removal

-.-----.----------~------- ..- ..--.----.--....---...-.-------------_._. ---_.--_.._---

128,358 .__._______280, 4~ ._.__._iQ§1-7§_I?_

Packaging 30,285 29,795 60,081 nsportation 15,714 15,641 31,355 i.l~~_ D~~E2~~__._.___________._._.__.____. -.~-.

_._- 162,651 -_._----_._._----- 157,468 ___. 32Q1_J19 Program Management [1] 449,004 323,748 772, Security 214,618 205,101 419, Spent Fuel Pool Isolation 24,155 16,006 40,161 Spent Fuel Management [2] 186,420 144,752 331,173 Insurance and__Regulatory Fees

...__......._....__.__.__.._---..__._._---........ -_.._._......_. __....35,759 __._---_.-..-.- _._______._. ._?~zJ§~. -_..__._...._...__68,911 Energy 15,066 14,907 29,973 Characterization and Licensing Surveys 23,406 26,614 50,020

~

Property Taxes 7,750 7,564 15,314 Severance 74,608 74,158 148,765

._..Miscellaneous .._.._.........._._.......__.-------_.__..._...._..._............-_._........._...-._--_._-_._---- .-----..-.. -..!.~-~.~-? . . _

_.._. __..._._.._. __.._-_._---_..._.._._Equipment ._________I_!d:_7.JL..__.__._._._.._._._. . ~~1.!~_

Total 3] 1,395,643 1,364,305 .2,759,947 Cost Element

__._-_ __ f-***-*-**---....736,693 . _14J.l.~_?_?__.____1!.~.712~Q~

... License.._--_ _-_..Termination Spent Fuel Management 584,671 403,424 988,095 Site Restoration 74,279 219,617 293,896 Total [3] 1,395,643 1,364,305 2,759,947

[1] Includes engineering costs

[2] Excludes program management costs (staffing) but includes costs for spent fuel loading/transfer/spent fuel pool O&M and EP fees

[3] Columns may not add due to rounding TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Page xix of xix DECON COST

SUMMARY

YEAR LICENSE RENEWAL DECOMMISSIONING COST ELEMENTS (thousands of 2011 dollars)

Cost Element Unit 1 Unit 2 Total Decontamination 17,212 20,362 37,574

_._.._-_._-_..._--_._..__.__..__...-_-_.._.._---_.._---_._----------_.._-_.....__... 1----_.._-..129,130 Removal - - _.._ - - ..__......_._--"-

282,605 ________~1_J, 73~

Packaging 40,158 39,723 79,880 Transportation 18,014 17,927 35,942 W asj;~_R~~.P_<?~~.L. __._. . ._. . .____. ____._____. . __.__._._. .___. _. . _.___.___. f--....- - - -174,779 - - - - - - - f----.-----.-..--.--- --_.._...-_.__._-

171,032 345,81C am Management [1] 311,678 364,934 676,61~

Security 263,946 249,060 513,006 Spent Fuel Pool Isolation 23,989 15,974 39,963 Spent Fuel Management [2]

.............,. 103,865 101,694 205,559

_!~_ ~. ~!:.~!!~~_.~!!~:LR~gu!~.!Q!y._. ~~.~. ~. . __._. ._. . _. . . ._.__. . . . . ___. . . . _. . __. . _. . . . . .__. . _. . ?gt~!?. ._-_.....__..--..._..--.....17,374 ... ..__..__..

37,585 Energy 10,306 10,069 20,375 Characterization and Licensing Surveys 21,286 24,682 45,968 Property Taxes 5,222 5,065 10,287 Severance 74,095 74,012 148,107 Miscellaneous

._..... Equipment

. .7J..§_~.Q.. . .__._. _.____. . .§.?IQ§_. __. . .___. _. J_Q.L~. ~}_.

. . Total [3] 1,221,721 1,402,667 2,624,388 Cost Element

. n~~__!~~!!?:~!iQ.!?:. .__. _. . . _._. . ._._. . . . _._. . . __. _. ._._._. _. . _. . . . . . . ._. _. . ._. . . _. . . . . ___.~~~!9.1 . . _.__J1.Q.Q.=h~§Q. . ._. .__. ._~.?..Q..~. !J..Q.§I nt Fuel Mana ement 151,162 148,940 300,102 73,457 218,842 292,299 1,221,721 1,402,667 2,624,388

[1] Includes engineering costs

[2] Excludes program management costs (staffing) but includes costs for spent fuel loading/transfer/spent fuel pool O&M and EP fees

[3] Columns may not add due to rounding TLG Services, Inc.

Diablo Canyon Power Plant Document POI-1648-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 1 of 11

1. INTRODUCTION This report presents estimates of the cost to decommission the Diablo Canyon Power Plant (Diablo Canyon) for the selected decommissioning scenarios following the scheduled cessation of plant operations. The estimates are designed to provide Pacific Gas and Electric Company (pG&E) with the information to assess its current decommissioning liability, as it relates to Diablo Canyon.

The analysis relies upon site-specific, technical information compiled by TLG from information provided by Pacific Gas and Electric Company (pG&E). The analysis reflects current assumptions pertaining to the disposition of nuclear power plants and relevant industry experience in undertaking such projects. The costs are based on several key assumptions in areas of regulation, component characterization, high-level radioactive waste management, low -level radioactive waste disposal, performance uncertainties (contingency) and site restoration requirements.

The analysis is not a detailed engineering evaluation, but estimates prepared in advance of the detailed engineering required to carry out the decommissioning of the nuclear units. It may also not reflect the actual plan to decommission Diablo Canyon; the plan may differ from the assumptions made in this analysis based on facts that exist at the time of decommissioning.

1.1 OBJECTIVES OF STUDY The objectives of this study are to prepare comprehensive estimates of the costs to decommission Diablo Canyon based on the DECON and SAFSTOR scenarios, to provide a sequence or schedule for the associated activities, and to develop waste stream projections from the decontamination and dismantling activities. For the purposes of this study, the shutdown dates are based on the expiration of the current operating licenses, or 2 November 2024 for Unit 1, and 26 August 2025 for Unit 2.

It is possible that an application to renew the license for an additional 20 years will be submitted prior to expiration of the current operating licenses.

Therefore, for the purposes of analysis, DECON scenario estimates were developed based on shutdown dates 20 years beyond the current license, or 2 November 2044 for Unit 1, and 26 August 2045 for Unit 2. The estimates for the alternate shutdown dates are provided in an appendix to this analysis, and will be referred to as "DECON - 20 Year License Renewal".

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 2 of 11 1.2 SITE DESCRIPTION Diablo Canyon is located on the central California coast in San Luis Obispo County, approximately 12 miles west southwest of the City of San Luis Obispo.

The plant, comprised of two nuclear units, is located on a 750-acre site adjacent to the Pacific Ocean, roughly equidistant from San Francisco and Los Angeles.

The Nuclear Steam Supply System (NSSS) consists of a pressurized water reactor and a four-loop Reactor Coolant System. The systems were supplied by the Westinghouse Electric Corporation. V nits 1 and 2 each have a license rating of 3411 MWt, with corresponding net electrical outputs 1131 and 1156 megawatts (electric), respectively, with the reactors at rated power.

The Reactor Coolant System is comprised of the reactor vessel and four heat transfer loops, each containing a vertical V-tube type steam generator, and a single-stage centrifugal reactor coolant pump. In addition, the system includes an electrically heated pressurizer, a pressurizer relief tank, and interconnected piping. The system is housed within a "containment structure," a seismic Category I reinforced-concrete dry structure. It consists of an upright cylinder topped with a hemispherical dome, supported on a reinforced concrete foundation mat, which is keyed into the bedrock. A welded steel liner plate anchored to the inside face of the containment serves as a leak-tight membrane. The liner on top of the foundation mat is protected by a two-foot thick concrete fill mat, which supports the containment internals and forms the floor of the containment. The lower portion of the containment cylindrical wall has additional embedded wide flange steel beams between elevations 88 ft. 2 in. and 108 ft. 2 in. (mean sea level).

Heat produced in the reactor is converted to electrical energy by the Steam and Power Conversion Systems. A turbine-generator system converts the thermal energy of steam produced in the steam generator:s into mechanical shaft power and then into electrical energy. The plant's' turbine-generators are each tandem compound, four element units. They consist of one high-pressure double-flow and three low-pressure double-flow elements driving a direct-coupled generator at 1800 rpm. The turbines are operated in a closed feedwater cycle that condenses the steam; the heated feedwater is returned to the steam generators. Heat rejected in the main condensers is removed by the Circulating Water System (CWS).

The circulating water system provides the heat sink required for removal of waste heat in the power plant's thermal cycle. The system has the principal function of removing heat by absorbing this energy in the main condenser.

TLG Services, Inc.

Diablo Canyon Power Plant Document POI-1648-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 3 of 11 Condenser circulating water is water from the Pacific Ocean. Each unit is served by two circulating water pumps at the intake structure. From this structure seawater is pumped through two circulating water conduits to the condenser inlet water boxes. The water is returned to the ocean at Diablo Cove through an outfall at the water's edge.

1.3 REGULATORY GUIDANCE The Nuclear Regulatory Commission (NRC or Commission) provided initial decommissioning requirements in its rule "General Requirements for Decommissioning Nuclear Facilities," issued in June 1988Jl] This rule set forth financial criteria for decommissioning licensed nuclear power facilities. The regulation addressed decommissioning planning needs, timing, funding methods, and environmental review requirements. The intent of the rule was to ensure that decommissioning would be accomplished in a safe and timely manner and that adequate funds would be available for this purpose.

Subsequent to the rule, the NRC issued Regulatory Guide 1.159, "Assuring the Availability of Funds for Decommissioning Nuclear Reactors," [2] which provided additional guidance to the licensees of nuclear facilities on the financial methods acceptable to the NRC staff for complying with the requirements of the rule. The regulatory guide addressed the funding requirements and provided guidance on the content and form of the financial assurance mechanisms indicated in the rule.

The rule defined three decommissioning alternatives as being acceptable to the NRC: DECON, SAFSTOR, and ENTOMB. The DECON alternative assumes that any contaminated or activated portion of the plant's systems, structures and facilities are removed or decontaminated to levels that permit the site to be released for unrestricted use shortly after the cessation of plant operations, while the SAFSTOR and ENTOMB alternatives defer the process.

The rule also placed limits on the time allowed to complete the decommissioning process. For all alternatives, the process is restricted in overall duration to 60 years, unless it can be shown that a longer duration is necessary to protect public health and safety. At the conclusion of a 60-year dormancy period (or longer if the NRC approves such a case), the site would still require significant remediation to meet the unrestricted release limits for license termination.

The ENTOMB alternative has not been viewed as a viable option for power reactors due to the significant time required to isolate the long-lived radionuclides for decay to permissible levels. However, with rulemaking permitting the controlled release of a site,[3] the NRC did re-evaluate the TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 4 of 11 alternative. The resulting feasibility study, based upon an assessment by Pacific Northwest National Laboratory, concluded that the method did have conditional merit for some, if not most reactors. The staff also found that additional rulemaking would be needed before this option could be treated as a generic alternative.

The NRC had considered rule making to alter the 60-year time for completing decommissioning and to clarify the use of engineered barriers for reactor entombmentsJ4] However, the NRC's staff has subsequently recommended that rule making be deferred, based upon several factors (e.g., no licensee has committed to pursuing the entombment option, the unresolved issues associated with the disposition of greater-than-Class C material (GTCC), and the NRC's current priorities), at least until after the additional research studies are complete. The Commission concurred with the staffs recommendation.

In 1996, the NRC, published reVISIons to the general requirements for decommissioning nuclear power plantsJ5] When the decommissioning regulations were adopted in 1988, it was assumed that the majority of licensees would decommission at the end of the facility's operating licensed life.

Since that time, several licensees permanently and prematurely ceased operations. Exemptions from certain operating requirements were required once the reactor was defueled to facilitate the decommissioning. Each case was handled individually, without clearly defined generic requirements. The NRC amended the decommissioning regulations in 1996 to clarify ambiguities and codify procedures and terminology as a means of enhancing efficiency and uniformity in the decommissioning process. The amendments allow for greater public participation and better define the transition process from operations to decommissioning.

Under the revised regulations, lice~sees will submit written certification to the NRC within 30 days after the decision to cease operations. Certification will also be required once the fuel is permanently removed from the reactor vessel.

Submittal of these notices entitle the licensee to a fee reduction and eliminate the obligation to follow certain requirements needed only during operation of the reactor. Within two years of submitting notice of permanent cessation of operations, the licensee is required to submit a Post-Shutdown Decommissioning Activities Report (PSDAR) to the NRC. The PSDAR describes the planned decommissioning activities, the associated sequence and schedule, and an estimate of expected costs. Prior to completing decommissioning, the licensee is required to submit an application to the NRC to terminate the license, which includes a license termination plan (LTP).

TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 5 of 11 1.3.1 Nuclear Waste Policy Act Congress passed the "Nuclear Waste Policy Act" [6] (NWPA) in 1982, assigning the federal government's long-standing responsibility for disposal of the spent nuclear fuel created by the commercial nuclear generating plants to the DOE. The NWPA provided that DOE would enter into contracts with utilities in which DOE would promise to take the utilities' spent fuel and high-level radioactive waste and utilities would pay the cost of the disposition services for that material. The NWPA, along with the individual contracts with the utilities, specified that the DOE was to begin accepting spent fuel by January 31, 1998.

Since the original legislation, the DOE has announced several delays in the program schedule. By January 1998, the DOE had failed to accept any spent fuel or high level waste, as required by the NWPA and utility contracts. To date no progress in the removal of spent fuel from commercial generating sites has been made. Delays continue and, as a result, generators have initiated legal action against the DOE In an attempt to obtain compensation for DOE's breach of contract.

It is necessary that spent fuel be cooled and stored for a minimum period at the generating site prior to transfer. As such, the NRC requires that licensees establish a program to manage and provide funding for the management of all irradiated fuel at the reactor site until title of the fuel is transferred to the Secretary of Energy, pursuant to 10 CFR Part

50. 54(bb)J7] This funding requirement is fulfilled through inclusion of certain cost elements in the decommissioning estimates, for example, associated with the isolation and continued operation of the spent fuel pools and the ISFSI.

PG&E's current spent fuel management plan for the Diablo Canyon spent fuel is based upon the DOE accepting spent fuel from commercial generators starting in year 2024. The DOE's generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority.

For purposes of this analysis, the first assemblies removed from the Diablo Canyon site are assumed to be in 2033. With an estimated, maximum rate of transfer of 3,000 metric tons of uranium (MTU) per year (commercial generators to the DOE), which corresponds to an average rate of transfer of 6 canisters (192 spent fuel assemblies) per year (Diablo Canyon to DOE), completion of the removal of spent fuel from the site is projected to be in the year 2055. Consequently, costs are included within the estimates for the long-term caretaking of the spent fuel at the Diablo Canyon site until the year 2055.

TLG Services, Inc.

Diablo Canyon Power Plant Document POI-1648-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 6 of 11 An ISFSI, which is independently licensed and operated, will remain operational after the cessation of plant operations. For the DECON and SAFSTOR scenarios, the facility is projected to have the capacity to accommodate the inventory of spent fuel residing in the plant's storage pools at the conclusion of the required cooling period. Once emptied, the spent fuel pool facilities can be either decontaminated and dismantled or prepared for long-term storage.

1.3.2 Low-Level Radioactive Waste Acts The contaminated and activated material generated in the decontamination and dismantling of a commercial nuclear reactor is classified as low-level (radioactive) waste, although not all of the material is suitable for "shallow-land" disposal. With the passage of the "Low-Level Radioactive Waste Policy Act" in 1980,[8] and its Amendments of 1985, [9] the states became ultimately responsible for the disposition of low -level radioactive waste generated within their own borders.

For the purpose of this analysis, the EnergySolutions' facility is used as the disposal site for the majority of the radioactive waste (Class A). [10]

The disposal costs for Class A low-level radioactive waste are based on a study sponsored by PG&E and Southern California Edison Company, "Establishing an Appropriate Disposal Rate for Low Level Radioactive Waste During Decommissioning", [11] escalated to year 2011 dollars.

For the purpose of this analysis, the Waste Control Specialists (WCS) facility in Andrews County, TX is used as the disposal site for the higher radioactivity Class Band C waste. In the prior 2008 decommissioning analysis the disposal rate for these waste classes were based on the previously cited study which was based on published Barnwell rates. A change in location was designated since Barnwell is not open to California generators, and with the exception of Texas, where WCS recently declared the site operational in November 2011; no new compact facilities have been successfully sited, licensed, and constructed. WCS will be able to accept limited quantities of non-Compact waste, although at this time the cost for non-Compact generators is being negotiated on an individual basis. The cost used in this estimate is a blended combination of preliminary information for the two WCS Class Band C rates. It should be noted that PG&E has a contract with WCS to dispose of Class Band C waste originating from Humboldt Bay 3. This contract requires waste delivery by April 2013.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 7 of 11 The dismantling of the components residing closest to the reactor core generates radioactive waste that may be considered unsuitable for shallow-land disposal (i.e., low-level radioactive waste with concentrations of radionuclides that exceed the limits established by the NRC for Class C radioactive waste (GTCC>>. The Low-Level Radioactive Waste Policy Amendments Act of 1985 assigned the federal government the responsibility for the disposal of this material. The Act also stated that the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste.

However, to date, the federal government has not identified a cost for disposing of GTCC or a schedule for acceptance.

For purposes of this analysis, the GTCC radioactive waste is assumed to be packaged and disposed of in a similar manner as high-level waste and at a cost equivalent to that envisioned for the spent fuel. The GTCC is packaged in the same canisters used for spent fuel and either stored on site or shipped directly to a DOE facility as it is generated (depending upon the timing of the decommissioning and whether the spent fuel has been removed from the site prior to the start of decommissioning).

1.3.3 Radiological Criteria for License Termination In 1997, the NRC published Subpart E, "Radiological Criteria for License Termination," [12] amending 10 CFR Part 20. This subpart provides radiological criteria for releasing a facility for unrestricted use.

The regulation states that the site can be released for unrestricted use if radioactivity levels are such that the average member of a critical group would not receive a Total Effective Dose Equivalent (TEDE) in excess of 25 millirem per year, and provided that residual radioactivity has been reduced to levels that are As Low As Reasonably Achievable (ALARA).

The decommissioning estimates assume that the Diablo Canyon site will be remediated to a residual level consistent with the NRC-prescribed level.

It should be noted that the NRC and the Environmental Protection Agency (EPA) differ on the amount of residual radioactivity considered acceptable in site remediation. The EPA has two limits that apply to radioactive materials. An EPA limit of 15 millirem per year is derived from criteria established by the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA or Superfund). [13]

An additional and separate limit of 4 millirem per year, as defined in 40 CFR §141.16, is applied to drinking water. [14]

TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 8 of 11 On October 9, 2002, the NRC signed an agreement with the EPA on the radiological decommissioning and decontamination of NRC-licensed sites. The Memorandum of Understanding (MOU)[15] provides that EPA will defer exercise of authority under CERCLA for the majority of facilities decommissioned under NRC authority. The MOU also includes provisions for NRC and EPA consultation for certain sites when, at the time of license termination, (1) groundwater contamination exceeds EPA-permitted levels; (2) NRC contemplates restricted release of the site; and/or (3) residual radioactive soil concentrations exceed levels defined in the MOU.

The MOU does not impose any new requirements on NRC licensees and should reduce the involvement of the EPA with NRC licensees who are decommissioning. Most sites are expected to meet the NRC criteria for unrestricted use, and the NRC believes that only a few sites will have groundwater or soil contamination in excess of the levels specified in the MOU that trigger consultation with the EPA. However, if there are other hazardous materials on the site, the EPA may be involved in the cleanup. As such, the possibility of dual regulation remains for certain licensees. The present study does not include any costs for this occurrence.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 9 of 11 FIGURE 1.1 DIABLO CANYON POWER PLANT GENERAL PLAN ltiii($ _ _ _ _~

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Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 10 of 11 FIGURE 1.2 DIABLO CANYON POWER PLANT AERIAL VIEW TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 11 of 11 FIGURE 1.3 DIABLO CANYON POWER PLANT REACTOR BUILDING SECTION TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 1 of 13

2. DECOMMISSIONING ALTERNATIVES Detailed cost estimates were developed to decommission Diablo Canyon based upon the approved decommissioning alternatives: DECON and SAFSTOR. Although the alternatives differ with respect to technique, process, cost, and schedule, they attain the same result: the ultimate release of the site for unrestricted use.

Multiple decommissioning scenarios were evaluated for the two nuclear units. The scenarios selected are representative of alternatives available to the owner and are defined as follows:

DECON: Units 1 and 2 are currently expected to cease operations in November 2024 and August 2025, respectively. Spent fuel remaining in the spent fuel storage pools after a minimum cooling period of 12 years is transferred to the ISFSI for interim storage. This scenario assumes that decommissioning activities at the two units are sequenced and integrated so as to minimize the total duration of the physical dismantling processes. Any residual spent fuel is transferred to the ISFSI so as to facilitate decontamination and dismantling activities within the fuel handing building. Spent fuel storage operations continue at the site until the transfer of the fuel to the DOE is complete, assumed to be in the year 2055.

SAFSTOR: The units are placed into safe-storage in this scenario. The start of field decommissioning is deferred to the end of the fuel storage period. Spent fuel remaining in the spent fuel storage pools after a minimum cooling period of 12 years is transferred to the ISFSI for interim storage. As with the DECON scenario, decommissioning activities at the two units are sequenced and integrated so as to minimize the total duration of the physical dismantling processes. Spent fuel storage operations continue at the site until the transfer of the fuel to the DOE is complete, assumed to be in the year 2055.

DECON (20-YEAR LICENSE RENEWAL): The results provided in the main body of this analysis are based on Units 1 and 2 operating until the expiration of their current operating licenses (base case). An estimate based on the DECON scenario was also prepared assuming a 20 year license renewal for each of the units. This estimate relies on essentially all of the same principles used in the base case estimate, but incorporates the following significant changes in the analysis:

., Units shut down 20 years later than the current operating license (impacts the timing of decommissioning expenditures) .

., Incorporates changes associated with post-shutdown spent fuel management.

An additional 20 years of operations will result in more spent fuel assemblies TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 2 of 13 being generated than the base case, but will reflect that many assemblies will be accepted by the DOE prior to unit shut down. As a result there are changes to spent fuel schedules and cost, and ISFSI capacity requirements.

Spent fuel storage operations continue at the site until the transfer of the fuel to the DOE is complete, assumed to be in 2071 for the 20 year license renewal case.

  • Incorporates changes associated with higher activation of the reactor and internals (longer period of operation affects the concentrations of long-lived activated radioactive materials remaining in the reactor after shut down).

The results of the license renewal estimates are provided in an appendix in this analysis.

The following sections describe the basic activities associated with each base case alternative (DECON and SAFSTOR). Although detailed procedures for each activity identified are not provided, and the actual sequence of work may vary, the activity descriptions provide a basis not only for estimating but also for the expected scope of work, i.e., engineering and planning at the time of decommissioning. A descriptions of the changes associated with the alternate license renewal scenario is provided in the appendices to this report.

The conceptual approach that the NRC has described in its regulations divides decommissioning into three phases. The initial phase commences with the effective date of permanent cessation of operations and involves the transition of both plant and licensee from reactor operations (i.e., power production) to facility de-activation and closure.

During the first phase, notification is to be provided to the NRC certifying the permanent cessation of operations and the removal of fuel from the reactor vessel.

The licensee is then prohibited from reactor operation.

The second phase encompasses activities during the storage period or during major decommissioning activities, or a combination of the two. The third phase pertains to the activities involved in license termination. The decommissioning estimates developed for Diablo Canyon are also divided into phases or periods; however, demarcation of the phases is based upon major milestones within the project or significant changes in the projected expenditures.

2.1 DECON The DECON alternative, as defined by the NRC, is "the alternative in which the equipment, structures, and portions of a facility and site containing TLG Services, Inc.

Diablo Canyon Power Plant Document P01-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 3 of 13 radioactive contaminants are removed or decontaminated to a level that permits the property to be released for unrestricted use shortly after cessation of operations." This study does not address the cost to dispose of the spent fuel residing at the site; such costs are funded through a surcharge on electrical generation. However, the study does estimate the costs incurred with the interim on-site storage of the fuel pending shipment by the DOE to an off-site disposal facility.

2.1.1 Period 1 - Preparations In anticipation of the cessation of plant operations, detailed preparations are undertaken to provide a smooth transition from plant operations to site decommissioning. Through implementation of a staffing transition plan, the organization required to manage the intended decommissioning activities is assembled from available plant staff and outside resources. Preparations include the planning for permanent defueling of the reactor, revision of technical specifications applicable to the operating conditions and requirements, a characterization of the facility and major components, and the development of the PSDAR.

Engineering and Planning The PSDAR, required prior to or within two years of permanent cessation of operations, provides a description of the licensee's planned decommissioning activities, a timetable, and the associated financial requirements of the intended decommissioning program. Upon receipt of the PSDAR, the NRC will make the document available to the public for comment in a local hearing to be held in the vicinity of the reactor site.

Ninety days following submittal and NRC receipt of the PSDAR, the licensee may begin to perform major decommissioning activities under a modified 10 CFR §50.59 procedure, i.e., without specific NRC approval.

Major activities are defined as any activity that results in permanent removal of major radioactive components, permanently modifies the structure of the containment, or results in dismantling components (for shipment) containing GTCC, as defined by 10 CFR §61. Major>

components are further defined as comprising the reactor vessel and internals, large bore reactor coolant system piping, and other large components that are radioactive. The NRC includes the following additional criteria for use of the §50.59 process in decommissioning. The proposed activity must not:

@ foreclose release of the site for possible unrestricted use, TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 4 of 13

  • significantly increase decommissioning costs,
  • cause any significant environmental impact, or
  • violate the terms of the licensee's existing license Existing operational technical specifications are reviewed and modified to reflect plant conditions and the safety concerns associated with permanent cessation of operations. The environmental impact associated with the planned decommissioning activities is also considered.

Typically, a licensee will not be allowed to proceed if the consequences of a particular decommissioning activity are greater than that bounded by previously evaluated environmental assessments or impact statements.

In this instance, the licensee would have to submit a license amendment for the specific activity and update the environmental report.

The decommissioning program outlined in the PSDAR will be designed to accomplish the required tasks within the ALARA guidelines (as defined in 10 CFR §20) for protection of personnel from exposure to radiation hazards. It will also address the continued protection of the health and safety of the public and the environment during the dismantling activity. Consequently, with the development of the PSDAR, activity specifications, cost-benefit and safety analyses, work packages, and procedures, would be assembled to support the proposed decontamination and dismantling activities.

Site Preparations Following final plant shutdown, and in preparation for actual decommissioning activities, the following activities are initiated:

  • Characterization of the site and surrounding environs. This includes radiation surveys of work areas, major components (including the reactor vessel and its internals), internal piping, and primary shield cores.
  • Isolation of the spent fuel storage pools and fuel handling systems, such that decommissioning operations can commence on the balance of the plant. The pools will remain operational for approximately twelve years following the cessation of operations before the inventory resident at shutdown can be transferred to the ISFSI.
  • Specification of transport and disposal requirements for activated materials and/or hazardous materials, including shielding and waste stabilization.

TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 5 of 13 It Development of procedures for occupational exposure control, control and release of liquid and gaseous effluent, processing of radwaste (including dry-active waste, resins, filter media, metallic and non-metallic components generated in decommissioning), site security and emergency programs, and industrial safety.

2.1.2 Period 2 - Decommissioning Operations This period includes the physical decommissioning activities associated with the removal and disposal of contaminated and activated components and structures, including the successful release of the site from the 10 CFR §50 operating license, exclusive of the ISFSI.

Significant decommissioning activities in this phase include:

  • Construction of temporary facilities and/or modification of existing facilities to support dismantling activities. For example, this will include a centralized processing area to facilitate equipment removal and component preparations for off-site disposal.

$ Reconfiguration and modification of site structures and facilities as needed to support decommissioning operations. This will include the upgrading of roads (on- and off-site) to facilitate hauling and transport. Modifications will be required to the containment structure to facilitate access of large/heavy equipment. Modifications will also be required to the refueling area of the building to support the segmentation of the reactor vessel internals and component extraction.

It Transfer of the spent fuel from the storage pool to the ISFSI pad for interim storage.

  • Design and fabrication of temporary and permanent shielding to support removal and transportation activities, construction of contamination control envelopes, and the procurement of specialty tooling.

It Procurement (lease or purchase) of shipping canisters, cask liners, and industrial packages.

  • Decontamination of components and piping systems as required to control (minimize) worker exposure.

$ Removal of piping and components no longer essential to support decommissioning operations.

  • Removal of control rod drive housings and the head service structure from reactor vessel head. Segmentation of the vessel closure head.

TLG Services, Inc.

Diablo Canyon Power Plant Document P01-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 6 of 13

$ Removal and segmentation of the upper internals assemblies.

Segmentation will maximize the loading of the shielded transport casks, i.e., by weight and activity. The operations are conducted under water using remotely operated tooling and contamination controls.

  • Disassembly and segmentation of the remaining reactor internals, including the core former and lower core support assembly. Some material is expected to exceed Class C disposal requirements. As such, the segments will be packaged in modified fuel storage canisters for geologic disposal.

$ Segmentation of the reactor vessel. A shielded platform is installed for segmentation as cutting operations are performed in-air using remotely operated equipment within a contamination control envelope. The water level is maintained just below the cut to minimize the working area dose rates. Segments are transferred in-air to containers that are stored under water, for example, in an isolated area of the refueling canal.

$ Removal of the activated portions of the concrete biological shield and accessible contaminated concrete surfaces. If dictated by the steam generator and pressurizer removal scenarios, those portions of the associated cubicles necessary for access and component extraction are removed.

$ Removal of the steam generators and pressurizer for controlled disposal. The generators will be moved to an on-site processing center, the steam domes removed and segmented for transportation and disposal. The lower shell and tube bundle will be packaged as a one-piece container for direct disposal. These components can serve as their own disposal containers provided that all penetrations are properly sealed and steel shielding added, as necessary, to those external areas of the package to meet transportation limits and regulations.

At least two years prior to the anticipated date of license termination, an LTP is required. Submitted as a supplement to the Final Safety Analysis Report (FSAR) or its equivalent, the plan must include: a site characterization, description of the remaining dismantling activities, plans for site remediation, procedures for the final radiation survey, designation of the end use of the site, an updated cost estimate to complete the decommissioning, and any associated environmental concerns. The NRC will notice the receipt of the plan, make the plan available for public comment, and schedule a local hearing. LTP TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 7 of 13 approval will be subject to any conditions and limitations as deemed appropriate by the Commission. The licensee may then commence with the final remediation of site facilities and services, including:

~ Removal of remaining plant systems and associated components as they become nonessential to the decommissioning program or worker health and safety (e.g., waste collection and treatment systems, electrical power and ventilation systems).

@ Removal of the steel liners from refueling canal, disposing of the activated and contaminated sections as radioactive waste. Removal of activated/ contaminated concrete (all concrete inside the containment liner).

~ Surveys of the decontaminated areas of the containment structure.

@ Remediation and removal of the contaminated equipment and material from the auxiliary building and any other contaminated facility. Radiation and contamination controls will be utilized until residual levels indicate that the structures and equipment can be released for unrestricted access and conventional demolition. This activity may necessitate the dismantling and disposition of most of the systems and components (both clean and contaminated) located within these buildings. This activity facilitates surface decontamination and subsequent verification surveys required prior to obtaining release for demolition.

~ Routing of material removed in the decontamination and dismantling to a central processing area. Material certified to be free of contamination is released for unrestricted disposition, e.g., as scrap, recycle, or construction debris. Contaminated material is characterized and segregated for packaging and disposal at a low-level radioactive waste disposal facility.

Incorporated into the LTP is the Final Survey Plan. This plan identifies the radiological surveys to be performed once the decontamination activities are completed and is developed using the guidance provided in the "Multi-Agency Radiation Survey and Site Investigation Manual (MARSSIM)."[16] This document incorporates the statistical approaches to survey design and data interpretation used by the EPA. It also identifies commercially available instrumentation and procedures for conducting radiological surveys. Use of this guidance ensures that the surveys are conducted in a manner that provides a high degree of confidence that applicable NRC criteria are satisfied. Once the survey is complete, the results are provided to the NRC in a format that can be TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 8 of 13 verified. The NRC then reviews and evaluates the information, performs an independent confirmation of radiological site conditions, and makes a determination on the requested change to the operating licenses (that would release the property, exclusive of the ISFSI, for unrestricted use).

The NRC will amend the operating licenses if it determines that site remediation has been perfor_med in accordance with the LTP, and that the terminal radiation survey and associated documentation demonstrate that the property (exclusive of the ISFSI) is suitable for release.

2.1.3 Period 3 - Site Restoration Following completion of decommissioning operations, site restoration activities can begin. Efficient removal of the contaminated materials and verification that residual radionuclide concentrations are below the NRC limits will result in substantial damage to many of the structures.

Although performed in a controlled, safe manner, blasting, coring, drilling, scarification (surface removal), and the other decontamination activities will substantially degrade power block structures including the reactor and auxiliary buildings. Under certain circumstances, verifying that subsurface radionuclide concentrations meet NRC site release requirements will require removal of grade slabs and lower floors, potentially weakening footings and structural supports. This removal activity will be necessary for those facilities and plant areas where historical records indicate the potential for radionuclides having been present in the soil, where system failures have been recorded, or where it is required to confirm that subsurface process and drain lines were not breached over the operating life of the station.

It is not currently anticipated that these structures would be repaired and preserved after the radiological contamination is removed. The cost to dismantle site structures with a work force already mobilized on site is more efficient than if the process is deferred.

This cost study presumes that non-essential structures and site facilities are dismantled as a continuation of the decommissioning activity.

Foundations and exterior walls are removed to a nominal depth of three feet below grade. The three-foot depth allows for the placement of gravel for drainage, as well as topsoil, so that vegetation can be established for erosion control. Non-contaminated concrete rubble produced by demolition activities is processed on -site to remove reinforcing steel and TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 9 of 13 miscellaneous embedments. The processed rubble is then transported and disposed of offsite. Below grade voids are backfilled with clean imported fill to provide a reasonably uniform site contour (i.e., no large localized on site depressions). Site areas affected by the dismantling activities are restored and the plant area graded as required to prevent ponding and inhibit the refloating of subsurface materials.

2.1.4 ISFSI Operations and Decommissioning The ISFSI will continue to operate under a separate and independent license (10 CFR §72) following the termination of the §50 operating licenses. Completion of the decommissioning process is dependent upon the DOE's ability to remove spent fuel from the site in a manner timely enough to complete license termination activities within 60 years of unit shut down. This analysis assumes that the last of the spent fuel will be removed from the site within approximately 31 years of the shutdown of Unit 1 or year 2055.

At the conclusion of the spent fuel transfer process, the ISFSI will be decommissioned. The Commission will terminate the §72license when it determines that the remediation of the ISFSI has been performed in accordance with an ISFSI license termination plan and that the final radiation survey and associated documentation demonstrate that the facility is suitable for release. Once the requirements are satisfied, the NRC can terminate the license for the ISFSI.

The ISFSI is based upon the currently licensed facility that uses multi-purpose canisters and concrete overpacks for pad storage. For purposes of this cost analysis, it is assumed that once the inner canisters containing the spent fuel assemblies have been removed, any required decontamination performed on the storage overpack (some minor neutron activation is assumed), and the license for the facility terminated, the concrete overpacks can be dismantled using conventional techniques for the demolition of reinforced concrete. The concrete storage pad is then removed and the area regraded.

2.2 SAFSTOR The NRC defines SAFSTOR as "the alternative in which the nuclear facility is placed and maintained in a condition that allows the nuclear facility to be safely stored and subsequently decontaminated (deferred decontamination) to levels that permit release for unrestricted use." The facility is left intact (during the dormancy period), with structures maintained in a sound condition.

TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 10 of 13 Systems that are not required to support the spent fuel pool or site surveillance and security are drained, de-energized, and secured. Minimal cleaning/removal of loose contamination and/or fixation and sealing of remaining contamination are performed. Access to contaminated areas is secured to provide controlled access for inspection and maintenance.

The engineering and planning requirements for physical dismantling activities are similar to those for the DECON alternative. Site preparations for physical dismantling are also similar to those. for the DECON alternative, with the exception of certain activities, such as spent fuel pool operations and maintenance, and chemical decontamination of primary systems.

Decommissioning operations are assumed to begin once the transfer of the spent fuel to the DOE is completed (in year 2055).

2.2.1 Period 1 - Preparations Preparations for long-term storage include the planning for permanent defueling of the reactor, revision of technical specifications appropriate to the operating conditions and requirements, a characterization of the facility and major components, and the development of the PSDAR.

The process of placing the plant in safe-storage includes, but is not limited to, the following activities:

$ Isolation of the spent fuel storage services and fuel handling systems so that safe-storage operations may commence on the balance of the plant. This activity may be carried out by plant personnel in accordance with existing operating technical specifications. Activities are scheduled around the fuel handling systems to the greatest extent possible.

$ Transferring the spent fuel from the storage pool to the ISFSI for interim storage, following the minimum required cooling period in the spent fuel pooL

~ Draining and de-energizing of the non-contaminated systems not required to support continued site operations or maintenance.

$ Disposing of ,contaminated filter elements and resin beds not required for processing wastes from layup activities for future operations.

~ Draining of the reactor vessel, with the internals left in place and the vessel head secured.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 11 of 13

  • Draining and de-energizing non-essential, contaminated systems with decontamination as required for future maintenance and inspection.
  • Preparing lighting and alarm systems whose continued use is required; de-energizing portions of fire protection, electric power, and HVAC systems whose continued use is not required.
  • Cleaning of the loose surface contamination from building access pathways.
  • Performing an interim radiation survey of plant, posting warning signs where appropriate.
  • Erecting physical barriers and/or securing all access to radioactive or contaminated areas, except as required for inspection and maintenance.
  • Installing security and surveillance monitoring equipment and relocating security fence around secured structures, as required.

2.2.2 Period 2 - Dormancy The second phase identified by the NRC in its rule addresses licensed activities during a storage period and is applicable to the dormancy phases of the deferred decommissioning alternatives. Dormancy activities include a 24-hour security force, preventive and corrective maintenance on security systems, area lighting, general building maintenance, heating and ventilation of buildings, routine radiological inspections of contaminated structures, maintenance of structural integrity, and a site environmental and radiation monitoring program.

Resident maintenance personnel perform equipment maintenance, inspection activities, routine services to maintain safe conditions, adequate lighting, heating, and ventilation, and periodic preventive maintenance on essential site services.

An environmental surveillance program is carried out during the dormancy period to ensure that releases of radioactive material to the environment are prevented or detected and controlled. Appropriate emergency procedures are established and initiated for potential releases that exceed prescribed limits. The environmental surveillance program constitutes an abbreviated version of the program in effect during normal plant operations.

Security during the dormancy period is conducted primarily to prevent unauthorized entry and to protect the public from the consequences of TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 12 of 13 its own actions. The security fence, sensors, alarms, and other surveillance equipment provide security. Fire and radiation alarms are also monitored and maintained.

Consistent with the DECON scenario, the spent fuel storage pools are emptied within approximately 12 years of the cessation of operations.

The transfer of the spent fuel to the DOE takes place during the dormancy period until completed in 2055. Once emptied, the ISFSI is secured decommissioned along with the power block structures in Period 4.

2.2.3 Periods 3 and 4 - Delayed Decommissioning Prior to the commencement of decommissioning operations, preparations are undertaken to reactivate site services and prepare for decommissioning. Preparations include engineering and planning, a detailed site characterization, and the assembly of a decommissioning management organization. Final planning for activities and the writing of activity specifications and detailed procedures are also initiated at this time.

Much of the work in developing a termination plan is relevant to the development of the detailed engineering plans and procedures. The activities associated with this phase and the follow-on decontamination and dismantling processes are detailed in Sections 2.1.1 and 2.1.2. The primary difference between the sequences anticipated for the DECON and this deferred scenario is the absence, in the latter, of any constraint on the availability of the fuel storage facilities for decommissioning.

Variations in the length of the dormancy period are expected to have little effect upon the quantities of radioactive wastes generated from system and structure removal operations. Given the levels of radioactivity and spectrum of radionuclides expected from forty years of plant operation, no plant process system identified as being contaminated upon final shutdown will become releasable due to the decay period alone, i.e., there is no significant reduction in the waste generated from the decommissioning activities. However, due to the lower activity levels, a greater percentage of the waste volume can be designated for off-site processing and recovery.

The delay in decommissioning also yields lower working area radiation levels. As such, the estimate for this delayed scenario incorporates TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 13 of 13 reduced ALARA controls for the SAFSTOR's lower occupational exposure potential.

Although the initial radiation levels due to 60CO will decrease during the dormancy period, the internal components of the reactor vessel will still exhibit sufficiently high radiation dose rates to require remote sectioning under water due to the presence of long-lived radionuclides such as 94Nb, 59Ni, and 63Ni. Therefore, the dismantling procedures described for the DECON alternative would still be employed during this scenario. Portions of the biological shield will still be radioactive due to the presence of activated trace elements with long half-lives (152Eu and 154Eu). Decontamination will require controlled removal and disposal. It is assumed that radioactive corrosion products on inner surfaces of piping and components will not have decayed to levels that will permit unrestricted use or allow conventional removal. These systems and components will be surveyed as they are removed and disposed of in accordance with the existing radioactive release criteria.

2.2.4 Period 5 - Site Restoration Following completion of decommissioning operations, site-restoration activities begin. Dismantling, as a continuation of the decommissioning process is a cost-effective option, as described in Section 2.1.3. The basis for the dismantling cost is consistent with that described for DECON, presuming the removal of structures and site facilities to a nominal depth of three feet below grade and the limited restoration of the site.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 1 of 29

3. COST ESTIMATES The cost estimates prepared for decommissioning Diablo Canyon consider the unique features of the site, including the nuclear steam supply system, electric power generating systems, structures, and supporting facilities. The basis of the estimates, including the sources of information relied upon, the estimating methodology employed, site-specific considerations, and other pertinent assumptions, is described in this section.

3.1 BASIS OF ESTIMATES The estimates were developed using site-specific, technical information extracted from the 2008 and previous estimates. This information was reviewed for the current analysis and updated as deemed appropriate. The site-specific considerations and assumptions used in the previous evaluation were also revisited. Modifications were incorporated where new information was available or experience from ongoing decommissioning programs provided viable alternatives or improved processes. The following are the significant changes associated with the plant configuration or radiological status that have been incorporated into the current estimate.

$ Concrete located within the containment building was reclassified as potentially contaminated and disposed of as radioactive waste.

  • The turbine, condenser, and their associated systems were previously categorized as potentially contaminated. Based on updated information provided by PG&E this status was changed to expected to meet release criteria. As such the materials are removed as "clean" and released as scrap metal from the station.

$ Portions of the reactor building base mat concrete located greater than 3 feet below grade were left in place in previous studies. Consistent with the basis of the estimate the inventory was modified to remove this concrete to a level of 3 feet below grade.

  • Removing and disposing of materials associated with recently installed security measures, particularly physical barriers, were incorporated into the estimate.

3.2 METHODOLOGY The methodology used to develop the estimates follows the basic approach originally presented in the AIF/NESP-036 study report, "Guidelines for TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 2 of 29 Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates,"[17] and the DOE "Decommissioning Handbook."[18] These documents present a unit factor method for estimating decommissioning activity costs, which simplifies the estimating calculations. Unit factors for concrete removal ($/cubic yard), steel removal ($/ton), and cutting costs ($/inch) are developed using local labor rates. The activity-dependent costs are estimated with the item quantities (cubic yards and tons), developed from plant drawings and inventory documents. Removal rates and material costs for the conventional disposition of components and structures rely upon information available in the industry publication, "Building Construction Cost Data," published by R.S. Means. [19]

The unit factor method provides a demonstrable basis for establishing reliable cost estimates. The detail provided in the unit factors, including activity duration, labor costs (by craft), and equipment and consumable costs, ensures that essential elements have not been omitted. Appendix A presents the detailed development of a typical unit factor. Appendix B provides the values contained within one set of factors developed for this analysis.

This analysis reflects lessons learned from TLG's involvement in the Shippingport Station Decommissioning Project, completed in 1989, as well as the decommissioning of the Cintichem reactor, hot cells, and associated facilities, completed in 1997. In addition, the planning and engineering for the Pathfinder, Shoreham, Rancho Seco, Trojan, Yankee Rowe, Big Rock Point, Maine Yankee, Humboldt Bay-3, Oyster Creek, Connecticut Yankee, and San Onofre-1 nuclear units have provided additional insight into the process, the regulatory aspects, and the technical challenges of decommissioning commercial nuclear units.

Wor k Difficulty Factors TLG has historically applied work difficulty adjustment factors (WDFs) to account for the inefficiencies in working in a power plant environment. WDFs are assigned to each unique set of unit factors, commensurate with the inefficiencies associated with working in confined, hazardous environments.

The ranges used for the WD Fs are as follows:

$ Access Factor 10% to 20%

$ Respiratory Protection Factor 10% to 50%

$ Radiation/ALARA Factor 10% to 37%

$ Protective Clothing Factor 10% to 30%

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 3 of 29

  • Work Break Factor 8.33%

The factors and their associated range of values were developed in conjunction with the AIF/NESP-036 study. The application of the factors is discussed in more detail in that publication.

Scheduling Program Durations The unit factors, adjusted by the WDFs as described above, are applied against the inventory of materials to be removed in the radiological controlled areas.

The resulting labor-hours, or crew-hours, are used in the development of the decommissioning program schedule, using resource loading and event sequencing considerations. The scheduling of conventional removal and dismantling activities is based upon productivity information available from the "Building Construction Cost Data" publication. In the DECON alternative, dismantling of the fuel handing systems and decontamination of the spent fuel pool is also dependent upon the timetable for the transfer of the spent fuel assemblies from the pool to the ISFSI.

An activity duration critical path is used to determine the total decommissioning program schedule. The schedule is relied upon in calculating the carrying costs, which include program management, administration, field engineering, equipment rental, and support services such as quality control and security. This systematic approach for assembling decommissioning estimates ensures a high degree of confidence in the reliability of the resulting costs.

3.3 IMPACT OF DECOMMISSIONING MULTIPLE REACTOR UNITS In estimating the near simultaneous decommissioning of two co-located reactor units there can be opportunities to achieve economies of scale, by sharing costs between units, and coordinating the sequence of work activities. There will also be schedule constraints, particularly where there are requirements for specialty equipment and staff, or practical limitations on when final status surveys can take place. For purposes of the estimate, Units 1 and 2 are assumed to be essentially identical. Common facilities have been assigned to Unit 2. A summary of the principal impacts are listed below.

$ The sequence of work generally follows the principal that the work is done at Unit 1 first, followed by similar work at Unit 2. This permits the experience gained at Unit 1 to be applied by the workforce at the second unit. It should be noted however, that the estimate does not consider productivity improvements at the second unit, since there is little TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 4 of 29 documented experience with decommissioning two units simultaneously.

The work associated with developing activity specifications and procedures can be considered essentially identical between the two units, therefore the second unit costs are assumed to be a fraction of the first unit (--- 43%).

~ Segmenting the reactor vessel and internals will require the use of special equipment. This equipment will be shared between the two reactors. The decommissioning project will be scheduled such that Unit 2's reactor internals and vessel are segmented immediately after the activities at Unit 1 have been completed.

tI!t Some program management and support costs, particularly costs associated with the more senior positions, can be avoided with two reactors undergoing decommissioning simultaneously. As a result, the estimate is based on a "lead" unit that includes these senior positions, and a "second" unit that excludes these positions. The designation as lead is based on the unit undertaking the most complex tasks (for instance vessel segmentation) or performing tasks for the first time.

The final radiological survey sched ule is also affected by a two-unit decommissioning schedule. It would be considered impractical to try to complete the final status survey of Unit 1, while Unit 2 still has ongoing radiological remediation work and waste handling in process. As such, the transfer of the spent fuel from the storage pools and subsequent decontamination of the spent fuel pool areas is coordinated so as to synchronize the final status survey for the station.

~ The final demolition of buildings at Units 1 and 2 are considered to take place concurrently.

tI!t Unit 1, as the first unit to enter decommissioning, incurs the majority of site characterization costs.

~ Shared systems and common structures are generally assigned to Unit 2.

tI!t Station costs such as emergency response fees, regulatory agency fees, corporate overhead, and insurance are generally allocated on an equal basis between the two units.

3.4 FINANCIAL COMPONENTS OF THE COST MODEL TLG's proprietary decommissioning cost model, DECCER, produces a number of distinct cost elements. These direct expenditures, however, do not comprise the total cost to accomplish the project goal, i.e., license termination, spent fuel management and site restoration.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 5 of 29 3.4.1 Contingency The activity- and period-dependent costs are combined to develop the total decommissioning cost. A contingency is then applied on a line-item basis, using one or more of the contingency types listed in the AIF/NESP-036. study. "Contingencies" are defined in the American Association of Cost Engineers "Project and Cost Engineers' Handbook" [20] as "specific provision for unforeseeable elements of cost within the defined project scope; particularly important where previous experience relating estimates and actual costs has shown that unforeseeable events which will increase costs are likely to occur." The cost elements in this analysis are based upon ideal conditions and maximum efficiency; therefore, consistent with industry practice, contingency is included. In the AIF/NESP-036 study, the types of unforeseeable events that are likely to occur in decommissioning are discussed and guidelines are provided for percentage contingency in each category. It should be noted that contingency, as used in this analysis, includes contingency based on a preliminary technical position

[21] to reflect the California Public Utilities Commission's desire for owners to conservatively establish an appropriate contingency factor for inclusion in the decommissioning revenue requirements.

Contingency Based on AIF Guidelines As stated in the AIF study contingency funds are an integral part of the total cost to complete the decommissioning process. Exclusion of this component puts at risk a successful completion of the intended tasks and, potentially, subsequent related activities. For this study, TLG examined the major activity-related problems (decontamination, segmentation, equipment handling, packaging, transport, and waste disposal) that necessitate a contingency. Individual activity contingencies ranged from 10% to 75%, depending on the degree of difficulty judged to be appropriate from TLG's actual decommissioning experience. The contingency values used in this study are as follows:

~ Decontamination 50%

~ Contaminated Component Removal 25%

  • Contaminated Component Packaging 10%
  • Contaminated Component Transport 15%

~ Low -Level Radioactive Waste Disposal 25%

~ Reactor Segmentation 75%

  • NSSS Component Removal 25%

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 6 of 29

~ Reactor Waste Packaging 25%

~ Reactor Waste Transport 25%

~ Reactor Vessel Component Disposal 50%

~ GTCC Disposal 15%

~ Non-Radioactive Component Removal 15%

~ Heavy Equipment and Tooling 15%

~ Supplies 25%

~ Engineering 15%

~ Energy 15%

~ Characterization and Termination Surveys 30%

~ Construction 15%

~ Taxes and Fees 10%

CII Insurance 10%

~ Staffing 15%

The contingency values are applied to the appropriate components of the estimates on a line item basis. The composite contingency value (excluding additional contingency described in the Preliminary Technical Position) for the DECON alternative is approximately 17.7%.

The value for the SAFSTOR alternative is approximately 17.5%.

Contingency Based on Preliminary Technical Position In addition to the contingency based on the AIF guidelines additional contingency was added to reflect the California Public Utilities Commission desire for owners to conservatively establish an appropriate contingency factor for inclusion in the decommissioning revenue requirements. Based on the previously referenced technical position, additional contingency was added to reflect an overall project contingency of 25% (both scenarios). This contingency was incorporated on a line item basis, with each line item receiving a pro-rated share of the increase.

3.4.2 Financial Risk In addition to the routine uncertainties addressed by contingency, another cost element that is sometimes necessary to consider when bounding decommissioning costs relates to uncertainty, or risk.

Examples can include changes in work scope, pricing, job performance, and other variations that could conceivably, but not necessarily, occur.

Consideration is sometimes necessary to generate a level of confidence in TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 7 of 29 the estimate, within a range of probabilities. TLG considers these types of costs under the broad term "financial risk." Included within the category of financial risk are:

  • Transition activities and costs: ancillary expenses associated with eliminating 50% to 80% of the site labor force shortly after the cessation of plant operations, added cost for worker separation packages throughout the decommissioning program, national or company-mandated retraining, and retention incentives for key personnel.

~ Delays in approval of the decommissioning plan due to intervention, public participation in local community meetings, legal challenges, and national and local hearings.

~ Changes in the project work scope from the baseline estimate, involving the discovery of unexpected levels of contaminants, contamination in places not previously expected, contaminated soil previously undiscovered (either radioactive or hazardous material contamination), variations in plant inventory or configuration not indicated by the as-built drawings.

~ Regulatory changes, for example, affecting worker health and safety, site release criteria, waste transportation, and disposal.

~ Policy decisions altering national commitments (e.g., in the ability to accommodate certain waste forms for disposition, or in the timetable for such, or the start and rate of acceptance of spent fuel by the DOE.

~ Pricing changes for basic inputs such as labor, energy, materials, and waste disposal.

This cost study does not add any additional costs to the estimate for financial risk, since there is insufficient historical data from which to project future liabilities. Consequently, the areas of uncertainty or risk are revisited periodically and addressed through repeated revisions or updates of the base estimates.

3.5 SITE-SPECIFIC CONSIDERATIONS There are a number of site-specific considerations that affect the method for dismantling and removal of equipment from the site and the degree of restoration required. The cost impact of the considerations identified below is included in this cost study.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 8 of 29 3.5.1 Spent Fuel Management The cost to dispose of spent fuel generated from plant operations is not reflected within the estimates to decommission the Diablo Canyon site.

Ultimate disposition of the spent fuel is within the province of the DOE's Waste Management System, as defined by the NWPA. As such, the disposal cost is financed by a 1 milllkWhr surcharge paid into the DOE's waste fund during operations. However, the NRC requires licensees to establish a program to manage and provide funding for the management of all irradiated fuel at the reactors until title of the fuel is transferred to the Secretary of Energy. This funding requirement is fulfilled through inclusion of certain high-level waste cost elements within the estimate, as described below.

The total inventory of assemblies that will require handling during decommissioning is based upon the following assumptions. The DOE's generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. For purposes of this analysis, acceptance of Diablo Canyon spent fuel by the DOE is expected to be complete by 2055 to permit license termination within approximately 32 years of unit shut down. The first assemblies removed from the Diablo Canyon site are assumed to be in 2033.

The estimates incorporate a minimum cooling period of approximately 12 years for the spent fuel that resides in the storage pools when operations cease. The current Part 72 ISFSI license does not allow dry cask storage of spent fuel with burnups above 45,000 MWD/metric ton.

It is assumed that PG&E can amend the Part 72 license to store the higher burnup fuel, but that as a condition of the amendment it will require longer decay times (12 years) before storing the spent fuel in the casks.

In both scenarios, any residual, fuel remaining in the pool after the 12-year period is relocated to the ISFSI to await transfer to a DOE facility.

Operation and maintenance costs for the storage facilities are included within the estimates and address the cost for staffing the facilities, as well as security, insurance, and licensing fees. The estimates include the costs to purchase, load, and transfer the fuel storage canisters. Costs are also provided for the final disposition of the facilities once the transfer is complete.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 9 of 29 Canister Design A multi-purpose storage canister (HOLTEC HI-STORM 100 system),

with a 32-fuel assemblies capacity, is assumed for future cask acquisitions. A unit cost of $1,500,000 is used for pricing the internal multi-purpose canister (MPC) and concrete overpack.

Canister Loading and Transfer An average cost of $1,000,000 per canister is used for the labor and consumables to load/transport the spent fuel from the pools to the ISFSI pad, based upon Diablo Canyon operating experience. The same cost,

$1,000,000 per canister, is used to estimate the cost to transfer the fuel from the spent fuel pools to the DOE. For estimating purposes, 50% of the pool to DOE cost is used to estimate the cost to transfer the fuel from the ISFSI to the DOE.

Operations and Maintenance Annual costs (excluding labor) of $1.53 million and $180,000 are used for operation and maintenance of the spent fuel pools and the ISFSI, respectively.

ISFSI Decommissioning Design Considerations A HI-STORM multi-purpose (storage and transport) dry shielded storage canister with a vertical, reinforced concrete storage overpack is used as a basis for the cost analyses. Approximately seven overpacks per unit (quantity necessary to manage the final core offload) are assumed to have some level of neutron-induced activation as a result of the long-term storage of the fuel, i.e., to levels exceeding free-release limits. The steel liners in these activated overpacks are assumed to be removed and disposed of as radioactive material. The cost to dispose of this material, as well as the demolition of the ISFSI facility, is included in the estimates.

GTCC The dismantling of the reactor internals generates radioactive waste considered unsuitable for shallow land disposal (i.e., low-level radioactive waste with concentrations of radionuclides that exceed the limits established by the NRC for Class C radioactive waste (GTCC>>.

The Low-Level Radioactive Waste Policy Amendments Act of 1985 TLG Services, Inc.

Diablo Canyon Power Plant Document P01-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 10 of 29 assigned the federal government the responsibility for the disposal of this material. The Act also stated that the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste. Although there are strong arguments that GTCC waste is covered by the spent fuel contact with DOE and the fees being paid pursuant to that contract, DOE has taken the position that GTCC waste is not covered by that contract or its fees and that utilities, including PG&E, will have to pay an additional fee for the disposal of their GTCC waste. However, to date, the federal government has not identified a cost for disposing of GTCC or a schedule for acceptance. As such, the GTCC radioactive waste has been packaged and disposed of as high-level waste, at a cost equivalent to that envisioned for the spent fuel.

For purposes of this study, GTCC is packaged in the same type of canister used to store spent fuel. Disposal costs are based upon a cost equivalent to that envisioned for the spent fuel. It is not anticipated that the DOE would accept this waste prior to completing the transfer of spent fuel. Therefore, until such time the DOE is ready to accept GTCC waste, it is reasonable to assume that this material would remain in storage with the spent fuel in the ISFSI at the Diablo Canyon site (for the DECON alternative). In the SAFSTOR scenario, the GTCC material is shipped directly to a DOE facility as it is generated since the fuel has been removed from the site prior to the start of decommissioning and the ISFSI deactivated.

The cost to dispose of GTCC material is based on the equivalent cost to dispose of spent fuel (weight basis). The details for estimating this value is provided in Section 5 of this analysis.

3.5.2 Reactor Vessel and Internal Components The reactor pressure vessel and internal components are segmented for disposal in shielded, reusable transportation casks. Segmentation is performed in the refueling canal, where a turntable and remote cutter are installed. The vessel is segmented in place, using a mast-mounted cutter supported off the lower head and directed from a shielded work platform installed overhead in the reactor cavity. Transportation cask specifications and transportation regulations dictate the segmentation and packaging methodology.

Intact disposal of reactor vessel shells has been successfully demonstrated at several of the sites that have been decommissioned.

TLG Services, Inc.

Diablo Canyon Power Plant Document P01-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 11 of 29 Access to navigable waterways has allowed these large packages to be transported to the Barnwell disposal site with minimal overland travel.

Intact disposal of the reactor vessel and internal components as a single package can provide savings in cost and worker exposure by eliminating the complex segmentation requirements, isolation of the GTCC material, and transport/storage of the resulting waste packages. Portland General Electric (PGE) was able to dispose of the Trojan reactor as an intact package (including the internals). However, its location on the Columbia River simplified the transportation analysis since:

~ the reactor package could be secured to the transport vehicle for the entire journey, i.e., the package was not lifted during transport,

~ there were no man-made or natural terrain features between the plant site and the disposal location that could produce a large drop, and

~ transport speeds were very low, limited by the overland transport vehicle and the river barge.

As a member of the Northwest Compact, PGE had a site available for disposal of the package - the US Ecology facility in Washington State.

The characteristics of this arid site proved favorable in demonstrating compliance with land disposal regulations.

It is not known whether this option will be available when the Diablo Canyon plant ceases operation. Future viability of this option will depend upon the ultimate location of the disposal site, as well as the disposal site licensee's ability to accept highly radioactive packages and effectively isolate them from the environment. Consequently, the study assumes that the reactor vessel will require segmentation, as a bounding condition.

3.5.3 Primary System Components In the DECON scenario, the reactor coolant system components are assumed to be decontaminated using chemical agents prior to the start of dismantling operations. This type of decontamination can be expected to have a significant ALARA impact, since in this scenario the removal work is done within the first few years of shutdown. A decontamination factor (average reduction) of 10 is assumed for the process. Disposal of the decontamination solution effluent is included within the estimate as a "process liquid waste" charge. In the SAFSTOR scenarios, radionuclide TLG Services, Inc.

Diablo Canyon Power Plant Document POI-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 12 of 29 decay is expected to provide the same benefit and, therefore, a chemical decontamination is not included.

The following discussion deals with the removal and disposition of the steam generators, but the techniques involved are also applicable to other large components, such as heat exchangers, component coolers, and the pressurizer. The steam generators' size and weight, as well as their location within the reactor building, will ultimately determine the removal strategy.

A trolley crane is set up for the removal of the generators. It can also be used to move portions of the steam generator cubicle walls and floor slabs from the reactor building to a location where they can be decontaminated and transported to the material handling area.

Interferences within the work area, such as grating, piping, and other components are removed to create sufficient laydown space for processing these large components.

The generators are rigged for removal, disconnected from the surrounding piping and supports, and maneuvered into the open area where they are lowered onto a dolly. Each generator is rotated into the horizontal position for extraction from the containment and placed onto a multi-wheeled vehicle for transport to an on-site processing and storage area.

The generators are disassembled on-site with the outer shell and lightly contaminated subassemblies designated for segmentation and direct disposal. The more highly contaminated tube sheet and tube bundle contained within the steam generator lower shell are packaged as a one-piece container for direct disposal.

Disposal costs are based upon the displaced volume and weight of the units.

Reactor coolant piping is cut from the reactor vessel once the water level in the vessel (used for personnel shielding during dismantling and cutting operations in and around the vessel) is dropped below the nozzle zone .. The piping is boxed and transported by shielded van. The reactor coolant pumps and motors are lifted out intact, packaged, and transported for processing and/or disposal.

TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 13 of 29 3.5.4 Main Turbine and Condenser The main turbine is dismantled uSIng conventional maintenance procedures. The turbine rotors and shafts are removed to a laydown area. The lower turbine casings are removed from their anchors by controlled demolition. The main condensers are also disassembled and moved to a laydown area. Material is then surveyed and prepared for transportation to an off-site scrap facility.

3.5.5 Retired Components Both Diablo Canyon units have replaced their original sets of steam generators and reactor closure heads; these retired components are stored on site within a concrete protective structure. The cost for transportation and disposal of these items has been included in this analysis.

3.5.6 Transportation Methods Contaminated piping, components, and structural material other than the highly activated reactor vessel and internal components will qualify as LSA-I, II or III or Surface Contaminated Object, SCO-I or II, as described in Title 49. [22] The contaminated material will be packaged in Industrial Packages (IP-l, IP-2, or IP-3, as defined in subpart 173.411) for transport unless demonstrated to qualify as their own shipping containers. The reactor vessel and internal components are expected to be transported in accordance with 10 CFR Part 71, in Type B containers.

It is conceivable that the reactor, due to its limited specific activity, could qualify as LSA II or III. However, the high radiation levels on the outer surface would require that additional shielding be incorporated within the packaging so as to attenuate the dose to levels acceptable for transport.

Any fuel cladding failure that occurred during the lifetime of the plant is assumed to have released fission products at sufficiently low levels that the buildup of quantities of long-lived isotopes (e.g., 137CS, 90Sr, or transuranics) has been prevented from reaching levels exceeding those that permit the major reactor components to be shipped under current transportation regulations and disposal requirements.

Transport of the highly activated metal, produced in the segmentation of the reactor vessel and internal components, will be by shielded truck cask. Cask shipments may exceed 95,000 pounds, including vessel TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 14 of 29 segment(s), supplementary shielding, cask tie-downs, and tractor-trailer.

The maximum level of activity per shipment assumed permissible was based upon the license limits of the available shielded transport casks.

The segmentation scheme for the vessel and internal segments is designed to meet these limits.

The transport of large intact components (e.g., large heat exchangers and other oversized components) will be by a combination of truck, rail, and/or multi-wheeled transporter.

Transportation costs for Class A radioactive material requIrIng controlled disposal are based upon the mileage to the EnergySolutions facility in Clive, Utah. Transportation costs for the higher activity Class Band C radioactive material are based upon the mileage to the WCS facility in Andrews County, Texas. The transportation cost for the GTCC material is assumed to be contained within the disposal cost. Truck transport costs were developed from published tariffs from Tri-State Motor Transit. [23]

3.5.7 Low-Level Radioactive Waste Disposal The mass of radioactive waste generated during the various decommissioning activities at the site is shown on a line-item basis in the detailed Appendices C through E, and summarized in Section 5. The quantified waste summaries shown in these tables are consistent with 10 CFR Part 61 classifications. Commercially available steel containers are presumed to be used for the disposal of piping, small components, and concrete. Larger components can serve as their own containers, with proper closure of all openings, access ways, and penetrations. The volumes are calculated based on the exterior package dimensions for containerized material or a specific calculation for components serving as their own waste containers.

The more highly activated reactor components will be shipped in reusable, shielded truck casks with disposable liners. In calculating disposal costs, the disposal fees are applied against the liner volume, as well as the special handling requirements of the payload. Packaging efficiencies are lower for the highly activated materials (greater than Class A waste), where high concentrations of gamma-emitting radionuclides limit the capacity of the shipping canisters.

TLG Services, Inc.

Diablo Canyon Power Plant Document POI-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 15 of 29 Class A Waste For the purpose of this analysis, the EnergySolutions' facility is used as the disposal site for the majority of the radioactive waste (Class A). The disposal costs for Class A low-level radioactive waste are based on a study sponsored by PG&E and Southern California Edison Company, "Establishing an Appropriate Disposal Rate for Low Level Radioactive Waste During Decommissioning" [11] , escalated to year 2011 dollars. A complete explanation of the basis for Class A waste disposal is provided in Section 5 of this analysis.

Class Band C Waste For purposes of this analysis, the Waste Control Specialists (WCS)

Andrews County, TX facility is used as the disposal site for the higher radioactivity waste (Class B and C). The disposal costs are based on a combination of two WCS rates projected for out-of-compact generators. A complete explanation of the basis for class Band C waste disposal is provided in Section 5 of this analysis.

3.5.8 Site Restoration Following License Termination The NRC will amend or terminate the site license if it determines that site remediation has been performed in accordance with the license termination plan, and that the terminal radiation survey and associated documentation demonstrate that the facility is suitable for release. The NRC's involvement in the decommissioning process will end at this point. Building codes and environmental regulations will dictate the next step in the decommissioning process, as well as owner's own future plans for the site.

Only existing site structures are considered in the dismantling cost. It is assumed that the electrical switchyards remain after Diablo Canyon is decommissioned. Structures are removed to a nominal depth of three feet below grade. The voids are backfilled with clean fill and capped with soil. The site is then re-graded to conform to the adjacent landscape.

Vegetation is established to inhibit erosion. These "non-radiological costs" are included in the total cost of decommissioning.

Concrete rubble generated from demolition activities is processed and transported off-site for disposal. Clean fill is brought on site to backfill below grade voids as needed. The excavations will be regraded such that the power block area will have a final contour consistent with adjacent surroundings.

TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 16 of 29 The estimates do not assume the remediation of any significant volume of contaminated soil.

3.6 ASSUMPTIONS The following are the major assumptions made In the development of the estimates for decommissioning the site.

3.6.1 Estimating Basis Decommissioning costs are reported in the year of projected expenditure; however, the values are provided in 2011 dollars. Costs are not inflated, escalated, or discounted over the periods of performance.

The estimates were developed using site-specific, technical information extracted from the 2008 estimates. This information was reviewed for the current analysis and updated as deemed appropriate. The site-specific considerations and assumptions used in the previous evaluation were also revisited. Modifications were incorporated where new information was available or experience from ongoing decommissioning programs provided viable alternatives or improved processes.

The study follows the principles of ALARA through the use of work duration adjustment factors. These factors address the impact of activities such as radiological protection instruction, mock-up training, and the use of respiratory protection and protective clothing. The factors lengthen a task's duration, increasing costs and lengthening the overall schedule. ALARA planning is considered in the costs for engineering and planning, and in the development of activity specifications and detailed procedures. Changes to worker exposure limits may impact the decommissioning cost and project schedule.

3.6.2 Labor Costs The craft labor required to decontaminate and dismantle the nuclear units will be acquired through standard site contracting practices. The current cost of labor at the site is used as an estimating basis. Costs for site administration, operations, construction, and maintenance personnel are based upon average salary information provided by PG&E.

PG&E will hire a Decommissioning Operations Contractor (DOC) to manage the decommissioning. The owner will provide site security, TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 17 of 29 radiological health and safety, quality assurance and overall site administration during the decommissioning and demolition phases.

Contract personnel will provide engineering services (e.g., for preparing the activity specifications, work procedures, activation, and structural analyses) under the direction of PG&E.

Personnel costs are based upon average salary information provided by PG&E. Overhead costs are included for site and corporate support, reduced commensurate with the staffing of the project.

Security is maintained close to operational levels while fuel is stored in the spent fuel pool. Security is reduced substantially once all spent fuel has been relocated to the ISFSI.

Staffing levels are assigned for each unit by sub-period and functional area. Economies of a multi-unit decommissioning are recognized by establishing a primary and a secondary staff level. The unit assigned the primary staff will include common supervisory positions and positions that may be shared across both units. The types of positions and staffing levels are adjusted based upon the type of activity occurring in each sub-period.

3.6.3 Design Conditions Any fuel cladding failure that occurred during the lifetime of the plant is assumed to have released fission products at sufficiently low levels that the buildup of quantities of long-lived isotopes (e.g., 137CS, 90Sr , or transuranics) has been prevented from reaching levels exceeding those that permit the major NSSS components to be shipped under current transportation regulations and disposal requirements.

The curie contents of the vessel and internals at final shutdown are derived from those listed in NUREG/CR-347 4)24] Actual estimates are derived from the curie/gram values contained therein and adjusted for the different mass of the Diablo Canyon components, projected operating life, and different periods of decay. Additional short-lived isotopes were derived from NUREG/CR-0130[25] and NUREG/CR-0672,f26] and benchmarked to the long-lived values from NUREG/CR-3474.

It is anticipated that there will be control element assemblies (CEAs) in the spent fuel pool at the cessation of operations, including those CEAs from the final core. This analysis assumes that the CEAs can be disposed of along with the spent fuel at no additional cost.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 18 of 29 Neutron activation of the containment building structure is assumed to be confined to the biological shield.

3.6.4 General Transition Activities Existing warehouses are cleared of non-essential material and remain for use by PG&E and its subcontractors. The plant's operating staff performs the following activities at no additional cost or credit to the project during the transition period:

<$ Drain and collect fuel oils, lubricating oils, and transformer oils for recycle and/or sale.

$ Drain and collect acids, caustics, and other chemical stores for recycle and/or sale.

$ Process operating waste inventories. Disposal of operating wastes (e.g., filtration media, resins) during this initial period is not considered a decommissioning expense; however, the estimates do include the disposition of a small volume of material currently being stored in the spent fuel pool (as described in Section 5).

Scrap and Salvage The existing plant equipment is considered obsolete and suitable for scrap as deadweight quantities only. PG&E will make economically reasonable efforts to salvage equipment following final plant shutdown.

However, dismantling techniques assumed by TLG for equipment in this analysis are not consistent with removal techniques required for salvage (resale) of equipment. Experience has indicated that some buyers wanted equipment stripped down to very specific requirements before they would consider purchase. This required expensive rework after the equipment had been removed from its installed location. Since placing a salvage value on this machinery and equipment would be speculative, and the value would be small in comparison to the overall decommissioning expenses, this analysis does not attempt to quantify the value that an owner may realize based upon those efforts.

It is ass:umed, for purposes of this analysis, that any value received from the sale of scrap generated in the dismantling process would be offset by the on-site processing costs. The dismantling techniques assumed in the TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 19 of 29 decommissioning estimates do not include the additional cost for size reduction and preparation to meet "furnace ready" conditions. For example, the recovery of copper from electrical cabling may require the removal and disposition of any contaminated insulation, an added expense. With a volatile market, the potential profit margin in scrap recovery is highly speculative, regardless of the ability to free release this material. This assumption is an implicit recognition of scrap value in the disposal of clean metallic waste at no additional cost to the project.

Furniture, tools, mobile equipment such as forklifts, trucks, bulldozers, and other property is removed at no cost or credit to the decommissioning project. Disposition may include relocation to other facilities. Spare parts are also made available for alternative use.

Energy For estimating purposes, the plant is assumed to be de-energized, with the exception of those facilities associated with spent fuel storage.

Replacement power costs are used to calculate the cost of energy consumed during decommissioning for tooling, lighting, ventilation, and essential services.

Insurance Costs for continuing coverage (nuclear liability and property insurance) following cessation of plant operations and during decommissioning are included and based upon current operating premiums. Reductions in premiums, throughout the decommissioning process, are based upon the guidance and the limits for coverage defined in the NRC's proposed rulemaking "Financial Protection Requirements for Permanently Shutdown Nuclear Power Reactors." [27] The NRC's financial protection requirements are based on varIOUS reactor (and spent fuel) configurations.

Taxes Property taxes (land) are included for all decommissioning periods.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 20 of 29 Site Modifications The perimeter fence and in-plant security barriers will be moved, as appropriate, to conform to the Site Security Plan in force during the various stages of the project.

3.7 COST ESTIMATE

SUMMARY

Schedules of expenditures for the DECON and SAFSTOR scenarios are provided in Tables 3.1 and 3.2. The tables delineate the cost contributors by year of expenditures as well as cost contributor (e.g., labor, materials, and waste disposal).

Additional tables in Appendices C and D provide detailed costs elements. The cost elements are also assigned to one of three subcategories: "License Termination," "Spent Fuel Management," and "Site Restoration." The subcategory "License Termination" is used to accumulate costs that are consistent with "decommissioning" as defined by the NRC in its financial assurance regulations (i.e., 10 CFR §50.75). The cost reported for this subcategory is generally sufficient to terminate the plant's operating license, recognizing that spent fuel management represents an additional cost liability that will interact with the license termination effort.

The "Spent Fuel Management" subcategory contains costs associated with the containerization and transfer of spent fuel from the pools to the DOE and the transfer of casks from the ISFSI to the DOE. Costs are also included for the operations of the pools and management of the ISFSI until such time that the transfer of all fuel from this facility to an off-site location (e.g., geologic repository) is complete.

"Site Restoration" is used to capture costs associated with the dismantling and demolition of buildings and facilities demonstrated to be free from contamination. This includes structures never exposed to radioactive materials, as well as those facilities that have been decontaminated to appropriate levels. Structures are removed to a depth of three feet and backfilled to conform to local grade.

As discussed in Section 3.4.1, it is not anticipated that the DOE will accept the GTCC waste prior to completing the transfer of spent fuel. Therefore, the cost of GTCC disposal is shown in the final year of ISFSI operation (for the DECON alternative). While designated for disposal at the geologic repository along with the spent fuel, GTCC waste is still classified as low-level radioactive waste and, as such, included as a "License Termination" expense.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 21 of 29 Decommissioning costs are reported in 2011 dollars. Costs are not inflated, escalated, or discounted over the period of expenditure (or projected lifetime of the plant). The schedules are based upon the detailed activity costs reported in Appendices C and D, along with the time line presented in Section 4.

The decommissioning cost estimate for the DECON - 20 Year License Renewal scenario is provided in Appendix E. This appendix contains an explanation of the specific contributors that influenced the decommissioning cost, as well as the results provided in tables similar to that provided for the base case DECON scenario.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 22 of 29 TABLE 3.1 DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES, UNIT 1 (thousands, 2011 dollars)

PG&E Equipment & Contractor LLRW Year Labor Materials Labor Disposal Other Total 2025 58,057 t-----_ _- ; - - _ . ! . - - - - - t ._ _ _ 1_O-'-,2_6_7__+_1_ _37,515 6, 55,320 I 167,616 I 2026 49,863 29,643 I 41,863 36,795 31,841 I 190,005!

2027 45,242 32,533 I 40,970 45,334 27,142 I 191,220 i 2028 37,792 11,225 I 26,247 26,764 17,535 I 119,563 I 2029 37,688 11,194 I 26,175 26,691 17,487 I 119,236 I 2030 .........! 25,553 I .......... *.........*.9,041 4,736 . . . *r******

. . . .. . . *. .*. *. * . **i>iii*4* *. . * . 3*:3'2..

. . . . . . . . . . . . . . . . . ~.?.Q~J 41 . . . . i....I ...J..9.?.§'J~. 59,166. . *. . I1 7,423 . . 1'I. . * * . *. * * . *. ***2*ti:*6*S*5 2031 19,385 2032 i____

*-*t 19,438

-'_ _--+--._ _ _1--<.,_4_5_8_-+1____ 333 41 7,444 I 28,713 I 2033 I 19,385 1,454 332 41 7,423 I 28,635 I 2034 i 19,385 1,454 332 41 7,423 28,635 I 2035 19,385 2040 6,347 7,966 i 12,319 0 3,020 29,652 I 2041 4,089 2,677 I 4,140 0, 2,923 13,829 I 2042 2,950 0 I 0 0 : 2,878 I 5,828 1

--~~!!--' ~: :~~

~.--+-~-+_----~-----r_------+----~-~--

~ ~-----____~_l ______ t~~~ --I-t~~:--I 2045 2,950 0 0 0 2,878 I 5,828 2046 2,950 0 0 0 2,878 I 5,828 J 2047 2,950 0 0 0 2,878 I 5,8281 2053 2,950 0 0 0 2,878 I 5,828 I TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 23 of 29 TABLE 3.1 (continued)

DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES, UNIT 1 (thousands, 2011 dollars)

PG&E Equipment & Contractor LLRW Year Labor Materials Labor Disposal Other Total

.:**::::*:.:::*g.Q*§*~:::""::'*:::*I:'''''''''.2, 9§..9......... 0 0 *****************-0*********1********************************2~**8*78*******T*** . . . . . . .§.J.. §~.~. . . . .

e-' 2055 2, 950 f************************************************ * *. ,. .8** * *5* *

  • 5* * * * * * . t ..... ,.......................................*"("..0. . *.). . . . . .1..........*................*..............*,,"..........0. . *. . . . i!i .......................... i3, 96'6. . .

2 19,711 2056 369 738 1,261 532 1 1,005 3,905 Total 1 467,076 139,347 253,726 164,315 298,004 1,322,468 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 24 of 29 TABLE 3.2 DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES, UNIT 2 (thousands, 2011 dollars)

PG&E Equipment & Contractor LLRW Year Labor Materials Labor Disposal Other Total

.................................................................................................................................................................... ****.. ****************T****** .........................................................................................................................................., ............................ *********************************************1

. . . . . . . .g.9.gJ?. . . . . . ...I.............!..7..?..4..~.7.......... . . . . . . . . .. . . . . . .g.? . !..g.~. . . ...l.......... . ............. §J.. Q.~.§........ .. . . . . . . . . . . . . ....!.?. §.. !.. ! . . . . ! . . . . . . . . . . . .gQJ.. §..~.7.. . . . .t. . . . . . . * * * * * * *. *§.*QJ.**Q~*~*********II 2026 I 49,808 9,039 I 23,451 8,837 46,092 I 137,228.

2027 46,771 28,350 I 38,828 41,865 13,885 I 169,699 i 2028 46,102 26,378 I 39,424 41,291 13,784 166,979 I 2029 i 45,094 12,443 32,973 25,785 17,265 I 133,560 I 2030 45,094 12,443 32,973 25,785 17,265 I 133,560 I

i6~-i ---I ~:: ~~~ i:-}~~- ----5'~-~in----~'-~~~-:---------i:~-~i--l- --~~~i~ij

_~_0_33_~!. . _~_5,_87.~_ 1,548 352 ______4~_-t 7,918 I 35,739 III 2034 25,876 1,548 352 45! 7,918 35,739 2035 25,876 1,548 352 45 7,918 35,739 2041 4,080 14,827 11,948 0 2,970 I 33,825 I 2042 2,944 0 0 0 2,872 I 5,816 I 2043 2,944 0 0 0 2,872 I 5,816 I

~2. . .J,..*99. . . ~4. . .24.. . . . .. . . . .... ...........................................0. . . . . . . 1.......

1 2 0 4.4 . . . . . . . . . . ...............

" 0 0: 2,880 I . . . . . . . . . .Q.?.§.9..g I

'--------~ . .--~--: -----~:~~TT- ~:~~:-I 1

2 2046 0 4 5 2,944 00 1 2047 2,944 0 0 0 2,872 I 5,816 2048 2,952 0 0 0 2,880 5,832 2049 2,944 0 0 0 2,872 5,816 I

. 29.~.9. . . . . . . .: . . . . . . . .g.?.~.4..4......... 0 0 ............................................9 2,872 . . . . §..?.§..!..~.....1

~~~~--i-i:-~:~-- ~ ~ ...n ----%~: ::::::::~::~~~:::r--t~~~ -I 2053 2,944 0 0 0 2,872 I 5,816 2054 2,944 0 I 0 0 2,872 5,816 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 25 of 29 TABLE 3.2 (continued)

DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES, UNIT 2

~housands,2011dollar~

PG&E Equipment & Contractor LLRW Year Labor Materials Labor Disposal Other Total

.*.*. * * .* *.*. *. * * * .*. I 2055

  • r...........***..**************************. *********T..*....*..*****.........

2,944 I E

                              • 2*65*6***********. *1"***************************36*8********r*************. ********

Total I 503,289 221,200 312,806 160,290 266,020 1,463,605 TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 26 of 29 TABLE 3.3 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES, UNIT 1 (thousands, 2011 dollars)

PG&E Equipment & Contractor LLRW Year Labor Materials Labor Disposal Other Total

%~~:- -:::~~~!~-+-. :B~FF'-':Hf!1:=::'-=a!F :::::::~~:~~FI::::=~!~:~~:1 2026 32,819 5,566 3,358 I 695 32,454 74,891 I 2027 20,346 2,474 673 I 25 10,562 34,081 I 2028 20,402 2,480 675 ' 25 10,591 34,174 I 2029 20,346 2,474 673 i 25 10,562 34,081 I 2039.. . . . . . . ,.. .. . . ~.9.?.?..4..~. .. . . . . . . . . . .~.?.4.7..4.. .. . . . . . . . . .~.7..~.. i ..............................~.§.......... . . . . . .. . . . .J..9.1. ~. ~.~. . . . l. . . . . . . . . . ?.4..1. 9§I. . . . j j

~31 , 20,346: 2,474 ****i,l* 673 25 10,5621....- 34,081 I 2032 I 20,402 I 2,48Q 675 25 10,591 I 34,174 I

-*2033*---~,346t----2"--,4-74--+----67-3--' . 25 10,562 34,081 I 2034 20,346 2,474 673 25 10,562 34,081 2045 5,576 315 12 3,442 9,346 2048 5,591 316 ° 12 3,451 I 9,371 2~0~4:9~  :=:H ,:. . . . . . . . . . . . .33****1!*55********1**.......... ........................99.........................

55', 55:7~f 6 1122 . . . . . . . . . . . . . . . . . . .39..'., .44..4 2. . . . . . . 11....... . ..................... 9 * * * ,~* 3?*4 *6~*

  • I F ***************s*ii5. * *
  • r *****************..*.. ° 42 12 . *****************************3*~**442********r***.. 9,346 . . .

2052 5,591 316 ° 12 3,451 I 9,371 2053 5,576 315 ° 12 3,442 9,346 TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 27 of 29 TABLE 3.3 (continued)

SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES, UNIT 1 (thousands, 2011 dollars)

PG&E Equipment & Contractor LLRW Year Labor Materials Labor Disposal Other Total

.....................................+...................§..1. §..7..~. . .

2054

-- 2055 I 5,576 2056 25,568 2057 25,281 19,571 34,344 i 29,425 10,447 119,069 2058 22,630 25,410 34,083 i 49,206 14,638 145,966 2059 16,984 8,226 22,941 i 27,369 6,172 81,692 3,::: I 2060

..........................*...... . :..........!.!.?..9.?....! i ...........................§.I. g.iHt. . ..L................. 2.~, 004 . . . . . . . . . . . ?.!..1. 4..4..4........... . . . . . . . . . . . . . . ~.?..!. ~.~. .. . .§.!.?.~.!.~. . . . .l r______

2061 2062 4 -_____~5t_4_0_9-+__ _

8,542 3,~~~ I ~~:~~: 12,O~~  :~:~~: I 2063 4,412 2064 3,331 8,202 12,870 0 345 I 24,748 2065 2,285 5,625 8,826 0 236 I 16,972 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 28 of 29 TABLE 3.4 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES, UNIT 2 (thousands, 2011 dollars)

PG&E Equipment & Contractor LLRW Year Labor Materials Labor Disposal Other Total

-- 2027 18,837 2,331 I 1,181 318 18,283 40,951 2028 13,724 1,891 494 21 8,811 24,941 I 2029 13,687 1,886 493 21 8,786. 24,873 2030 13,687 1,886 I 493 21 8,786 I 24,873 I'

-i~~i--li~~~~I--- ----t~~i--I  ::: ----------i}- -----~:-Hi--1-~!~-~II--1 2033 L_~3,687 1,886 I 493 21 8,786 24,873 2034 13,687 1,886 I 493 21 8,786 24,873 2035 13,687 1,886 I 493 21 8,786 24,873 2036 13,724 1,891 I 494 21 8,8111 24,941 22 00 338 7 0~2

, . . . . . . 9. . . . '.,. 9. . . . :5?3. . . . . .:. :. .: : .' .. . . . . . . . . . . . . . 12..??.9. . . . 1.......**..............................?.gJ. . . . .l. . . . . . . . . . . . . . . ...!.7............. 6,910 I . . . . . . . . . . . . ...!.??.. ~.g~... ./

3 0Q 3 ~ I . .~?.7..§.?.. . I

  • ~:~:~-----~~~-T-----~f---i~

301 I 10 3 436

~~:~ f:!~-r-- ~:~~~ 1 2041 3,032 301 I 3 10 3,436 6,783 I 2042 3,032 301 I 3 10 3,436 6,783 I 2046 3,032 301 I 3 10 3,436 6,783 2047 3,032 301 3 10 3,436 6,783 I 2048 3,040 302 3 10 3,446 6,801 I 2049 3,032 301 3 10 3,436 6,783 I

---~~!!-:::-:::~:~1~- ------- :~! T:::::::::~:::1:;---------!~-----:~!!~:::f:::::=:::~~~~:::1 2053 3,032 301 I " 3 10 3,436 I 6,783 2054 3,032 301 3 10 3,436 6,783 I TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 29 of 29 TABLE 3.4 (continued)

SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES, UNIT 2 (thousands, 2011 dollars)

PG&E Equipment & Contractor LLRW Year Labor Materials Labor Disposal Other Total 2058 22,297 20,195 29,378 29,042 10,258 I 111,169 2059 25,056 26,668 36,948 48,171 14,335 I 151,178 2060 24,201 9,347 29,608 25,762 5,927 I 94,845 .

._._.~Q§L.~ ..~1,!§.~(_... ... -!l.&?} ..f ..... .?1).L~~!L 25,~!l..? ... _.~,!l..lLt ....__9.M~_6.i 2062 15,626 I 5,275 I 33,566 11,851 3,231 I 69,549 I f-- 2063 4,385, 35,166 1 __ 36,192 10 594 I. 76,348 I 2064 3,311 44,349 I 36,069 0 500 I 84,229 I 2065 2,271 30,414 24,736 0 343 57,764 1.................. T.9..t..9.:.! . . .I.......4.J. 7.J.. 4.. §.~..... .. . . . . . . . . . . . ~.?.9.?.. 7..?..~ . ...1...... .......... ?~.~.J.§.~ . . . . . . . . . .J4..~.??. ~.?.. . . . ..I.. .............~.§.?.?...~.4..~ . . .I ............L.?~.4.?. ?.Q.~. . . . .1 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 1 of 6

4. SCHEDULE ESTIMATE The schedules for the decommissioning scenarios considered in this study follow the sequences presented in the AIF/NESP-036 study, with minor changes to reflect recent experience and site-specific constraints. In addition, the scheduling has been revised to reflect the spent fuel management plan described in Section 3.5.1.

A schedule or sequence of activities for the DECON alternative from shutdown to ISFSI site restoration is presented in Figure 4.1. The scheduling sequence is based on the fuel being removed from the spent fuel pools within twelve years. The key activities listed in the schedule do not reflect a one-to-one correspondence with those activities in the cost tables, but reflect dividing some activities for clarity and combining others for convenience. The schedule was prepared using the "Microsoft Project Professional 2010" computer softwareJ28]

4.1 SCHEDULE ESTIMATE ASSUMPTIONS The schedule reflects the results of a precedence network developed for the site decommissioning activities, i.e., a PERT (Program Evaluation and Review Technique) Software Package. The work activity durations used in the precedence network reflect the actual man-hour estimates from the cost table, adjusted by stretching certain activities over their slack range and shifting the start and end dates of others. The following assumptions were made in the development of the decommissioning schedule:

  • The spent fuel pools are isolated until such time that all spent fuel has been discharged from the spent fuel pools to the DOE. Decontamination and dismantling of the storage pools is initiated once the transfer of spent fuel is complete (DECON option).

~ All work (except vessel and internals removal) is performed during an 8-hour workday, 5 days per week, with no overtime.

  • Reactor and internals removal activities are performed by using separate crews for different activities working on different shifts, with a corresponding backshift charge for the second shift.

~ Multiple crews work parallel activities to the maximum extent possible, consistent with optimum efficiency, adequate access for cutting, removal and laydown space, and with the stringent safety measures necessary during demolition of heavy components and structures.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 2 of 6

  • For plant systems removal, the systems with the longest removal durations in areas on the critical path are considered to determine the duration of the activity.

4.2 PROJECT SCHEDULE The period-dependent costs presented in the detailed cost tables are based upon the durations developed in the schedules for decommissioning. Durat,ions are established between several milestones in each project period; these durations are used to establish a critical path for the entire project. In turn, the critical path duration for each period is used as the basis for determining the period-dependent costs. A second critical path is shown for the spent fuel storage period, which determines the release of the fuel handling area of the auxiliary building for final decontamination.

Project timelines are for the DECON and SAFSTOR scenarios are provided in Figures 4.2 and 4.3 with milestone dates based on the 2024 and 2025 shutdown dates for Units 1 and 2, respectively. The fuel pools are emptied approximately twelve years after shutdown, while ISFSI operations continue until the DOE can complete the transfer of assemblies to its geologic repository. Deferred decommissioning in the SAFSTOR scenarios is assumed to commence so that the physical dismantling takes place immediately after all spent fuel has been removed from the site.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 3 of 6 FIGURE 4.1 ACTIVITY SCHEDULE - DECON Task Name Y1 I Y3 I Y5 I Y7 I Y9 I Y11 I Y13 I 115 I 117 I Y19 J 321 Y23 Y25 Y2'7 Y29 Y31 Y33 Y35 Y37 lDi alJle CBI1yon !'()\ller ~a,J1t :P:E_()()!II _______ ._____ ____ _

Diablo Canyon Uni11 Shutdown Date November

  • 1 1

2,2024

-p.;~i-Crl-i~ stiui.do;.mihi:ouiitiT~mitio~ I!!!::lII Certificate .of permanent CE;"ssatien efope;.;:tions-submitted 1

~~i:~~~i~8e: ~~i_oj;e;i~ti~~~ ~I

.1)r.Y_ ~\J!l1. _s.t<:lr_'!i,!ClPe.r_ati_eJ1!;_ m;g l Re.c.o.nfigure pla,nt ~I

!'r..!lp_3£e_:l£.ti~_ty_~~~~~~~ ~I

~I Perferm site characterizaticin

_~~~ui:!rik~ ::::": --.. -

Written certificate .of perm ~nt re~eval .of fuel

_~u):l!Ilitte~ _____ _

  • ~

Site specific decommissiening cost estimate ~

submitted 1

_ j:l9..Q:i~9jL~9~Ij~L_ ~

Pe!!~Jb__Il?C:OIl.l!Ills_s19t:1.it:lg !'reParations I:!!

F\le.1. stet:a gep<:l()! _ep~r.!l-ti()l}s _ o i

~.2!!.~gu~plant j:entinued)

Dry fuel sterage eperatians

?tep'~j:I~t~!I~d ~r!tp~~dut:es DeconNSSS

_ jSi~ti~~nt&~~L _____ _ ~

Period 2a, Lar.ge Compon.ellt Remaval ~

_Jf\l~I _s_t.~r~ge_ P()<l1()PIlE_a~()Il_s ~

Dryfue} star age eperatiens ~

~p_arat!Q.n fer reactor vess~ fetp.ev~

9 1

~ I

_~l!c.t.o.r'y~ss.~L~_!J:lll:!rl}~_s Remaining large NSSS cempenents dispositien ~,

Nen-essential systems ,

M;;;~-t~ti~ige;:;r~~ 1 Main cerrlenser 1

_~~S_~ns.Il_~~!~il}!l-ti()!l pl.!lJ.1_ ~~I:rn_*_E!~

perl9£l_gtl_P.eE.on~i!l_ati()l} (VIJ!3tJuel)
  • ~I
li'llel s.tllr.!l-ge_ PCl()~ppe.r.!l-ti()l}s _

/,., ":."." ,,1 prY.f\J8_!.~()r.age_ .op~r!l-_ti.o_rlS___ ______ _ _. _. ______ _

Remeve systems not supporting wet fuel storage I;:;;;;:;;*::

DeCo~buiidings net ~upportiiig wet fuel starage ~:

1 ,

__ p'~e~e. t.e~nii_ii~~.o_ri_pi~_~Jr'()~~ _. ___ . _____ _ 1 ~

Period :£ Spent Fuel Delay Prier t.o Spent Fuel FOOl , 1m'l!l!~rl!m~~!lm!lI Decon tti~is§i~~~~_i.oy_eE~~i?:ris  :, g~~:,.:;.~~:~>:;:;~  :.j;. .,:.:'~:-::;;:':;~; :'.:~

p'ry f~l _~~arag~ .o~~_B:tiel1S

, , 1 ,

nlabio 6~y';n Unit 2 siiuirl~wnriate August 26,

_2 (m._ 1 1 1

.TJP:i!?Jl~Il!~~LW.e.U!()r.,!-ge_ (1.~XI:l'!-r.~) 9"" ....-..-...... " *., ";' * **:;;'1*;-;;.'(***;.1,** *****;-*1',**,*<;-"',J Perioj l ,a S,hutdeVlll1 _Through _TransitieIl , _ ~

Certificate .of permanent cessatian .of eper atiens ~

s.1J.~Ill_it.!-el:! 1 P.\Jf:lL~!QE~e P().oJ.pp~Ia~e_~ t2Zl i

~Y~IJf3J. ,~b.?r,lIgl:l, ()pe.r_!l-ti()n.s lleconfigur~ pi_ant

_PrePare _l1-Cti vi ty _specific_~ien_s Perferm site characterizati.on PsD.~s.Ubli-itt;;ct-Certificate .of permanent rem .oval .of fuel submitted

~te specific decommissianing cost estimate submitted

-:iX)C~~-mobil;zed -

Pe!i.~JE.;Qe.c!?P.lIllJ.s_siel!iIlll, ;F!~p_ar,a~i~~

  • m Fuel stor age pool aperatiens E':;J

_I<icorlt'ig~~p'I~~_ I:Cll}tiIl1J.~) ~

_~y_ ~\J!lJ. .~!Q!'!ie_ llpe.r.a,gQI1~__ _ EZl Iiijj

_:f>r~p_ar~_ ge!.aJled :~rlt prCJ<:!l~_lIr_es DlcenNSSS !Oil

___ ji_oi:a:~:~~iitj~e.i~i , ________ , , , _ Iiijj J~It~Jl_3,.~g~CO.J!lp<:l~.12t~_m_e'!.al_ ~

Fuel storage pool eperatians ~

Milestone

  • Critical Path Task 1*<x,,:*: :<:<x .nx*<Xl Summary task Non-critical Tasks ...........;;;;;;;;;;;;..

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 4 of 6 FIGURE 4.1 (continued)

ACTIVITY SCHEDULE - DECON Task Name IX)' f1,lE!1.s.~rage. 9PElrllJiofls . . ..... .

Preparation for reactor vessel removal I::l I

~~act1)l' lIe~sel *&.intern.als Remaining large NSSS components disposition

$I fl ril?n:~_~flt;ai sys.te.m~

~Ilt.lIr!Ji.nelgenerator Main ~.nd8~r I

.. !it:eIlsEl. ~r.minati011 plan..stlbmi.tte!d

  • I'

~

= ,.~" ,

Peritxi 2b Decontamination (_t fuel)

_~Ls!Q~ag~pQ<lLo.E8.!a!i_I?~ ,-, .

IXyfuel storage operati0Ils . . ...

Remove systems not supporting wet fuel storage . ......

I Thcon buildings not supporting Wet fuel stcrage ~

.li.ce.ns~ terrnin¢.on planapllroved. . .

Peritxi a: Spent Fuel Delay Prior to Spent Fuel FOOl Decon

_. ~l ~U;i_~e.P<ioI ~~~iti~~

IXy fuel storage operations ,.::<>:3;:<;';:0;;:- + ,,>:;,,:<* <>:,.:<3 Peritxi a:t Unit 1 and 2 Decontamination Following ~

W.e.!:_F}l~1 IXy fuel stor age operations ~

~lIl.()lIe.EEl_rn~.lli.f1g. sys tl3111s. ~

Theon wet fuel stor age area Iii Perltxi 2fUnit i ~ 2li~en;e Termination m

-- ~Y~l.:siO~ag-e-pperations- .-_. - -.. G'J Flnal .Site. f3urvey ~

I ll!)

l"BQ!.e!!~y!:~ .apP~911~

Part 50. license terminated Pe.rll:Xi. ~ 1!llit 1.1lIld 2.8ite Restoration

  • ~

Dry fuel storage operations ~

Building demoli tions. backfill an::llandscaping ~

Period 9;) Fuel Storage OperationS/Shipping

.@~.!:?.o_~.5)... _ . ....

Peritxi 3:\ aTee Shipping I.SF.:~ J:le.CC?nt.an\illa.ti.o.ll .CJo.!5~)

ISFSI ~ite .Restoration (20.56)

Decommissionin Com lete Jul Milestone

  • Critical Path Task IXx."'.<:,!! ... :::"',,,, Summary task Non-critical Tasks 0;;;;;;;;;;;;;;;;;;;;;;;;;;.0 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 5 of 6 FIGURE 4.2 DECON ALTERNATIVE DECOMMISSIONING TIMELINE (not to scale)

Unit 1 (Shutdown November 2, 2024)

Pool and ISFSI Operations ISFSIOperations Period 1 Period 2 Period 3 Transition and Site Prepara tions Decommissioning Restoration ISFSIOperations ISFSI D&D 11/2024 05/2026 11/2038 05/2041 12/2055 07/2056 Storage Pools Empty Unit 1 - 11/2036 Unit 2 - 08/2037 Unit 2 (Shutdown August 26, 2025)

Period 1 Period 2 Period 3 Transition and Site Preparations Decommissioning Restoration ISFSIOperations ISFSI D&D 08/2025 02/2027 11/2038 05/2041 12/2055 07/2056 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 6 of 6 FIGURE 4.3 SAFSTOR ALTERNATIVE DECOMMISSIONING TIMELINE (not to scale)

Unit 1 (Shutdown November 2, 2024)

Period 1 Period 2 Period 3 Period 4 Period 5 Transition and Delayed Site Prep ara tions Dormancy Preparations Decommissioning Restoration 11/2024 05/2026 01/2056 07/2057 03/2063 09/2065 Unit 1 Pool Empty 11/2036 Dry Spent Fuel Storage ~I ISFSIEmpty 12/2055 Unit 2 (Shutdown August 26, 2025)

Period 1 Period 2 Period 3 Period 4 Period 5 Transition and Delayed Site Preparations Dormancy Preparations Decommissioning Restoration 08/2025 02/2027 01/2057 07/2058 03/2063 09/2065 Unit 2 Pool Empty 08/2037 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 1 of 7

5. RADIOACTIVE WASTES The objectives of the decommissioning process are the removal of all radioactive material from the site that would restrict its future use and the termination of the NRC license. This currently requires the remediation of all radioactive material at the site in excess of applicable legal limits. Under the Atomic Energy Act, [29] the NRC is responsible for protecting the public from sources of ionizing radiation. Title 10 of the Code of Federal Regulations delineates the production, utilization, and disposal of radioactive materials and processes. In particular, Part 71 defines radioactive material as it pertains to transportation and Part 61 specifies its disposition.

Most of the materials being transported for controlled Disposal are categorized as Low Specific Activity (LSA) or Surface Contaminated Object (SCO) materials containing Type A quantities, as defined in 49 CFR Parts 173-178. Shipping containers are required to be Industrial Packages (IP-l, IP-2 or IP-3, as defined in 10 CFR §173.411). For this study, commercially available steel containers are presumed to be used for the disposal of piping, small components, and limited quantities of concrete. Larger components can serve as their own containers, with proper closure of all openings, access ways, and penetrations. Material that is expected to meet requirements for transport in bulk, such as the majority of contaminated concrete, is disposed of without its' packaging.

The waste material produced in the decontamination and dismantling of the nuclear plants is primarily generated during Period 2 of DECON and Period 4 of SAFSTOR. The volumes of radioactive waste generated during the various decommissioning activities at the site are shown on a line-item basis in Appendices C and D, and summarized in Tables 5.1 and 5.2. The quantified waste volume summaries shown in these tables are consistent with Part 61 classifications. The volumes are calculated based on the exterior dimensions for containerized material and on the displaced volume of components serving as their own waste containers.

The reactor vessel and internals are categorized as large quantity shipments and, accordingly, will be shipped in reusable, shielded truck casks with disposable liners.

In calculating disposal costs, the disposal fees are applied against the liner volume, as well as the special handling requirements of the payload. Packaging efficiencies can be lower for the highly activated materials (greater than Type A quantity waste), where high concentrations of gamma-emitting radionuclides limit the capacity of the shipping canisters.

No process system containing/handling radioactive substances at shutdown is presumed to meet material release criteria by decay alone (i.e., systems radioactive TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 2 of 7 at shutdown will still be radioactive over the time period during which the decommissioning is accomplished, due to the presence of long-lived radionuclides).

While the dose rates decrease with time, radionuclides such as 137CS will still control the disposition requirements.

Disposal costs are based on the following:

Class A Waste For the purpose of this analysis, the EnergySolutions' facility is used as the disposal site for the majority of the radioactive waste (Class A). The disposal costs for Class A low-level radioactive waste are based on a study sponsored by PG&E and Southern California Edison Company, "Establishing an Appropriate Disposal Rate for Low Level Radioactive Waste During Decommissioning"[11], escalated to year 2011 dollars. The study was originally done in 2008 dollars to reflect the California Public Utilities Commission's desire for these owners to be consistent and to conservatively estimate their nuclear decommissioning LLRW disposal rates. The rates published in the study were escalated from 2008 to 2011 year dollars using an average rate of 6.93% per year, which reflects a rate consistent with CPUC Decision 10-07-047 dated July 29, 2010. This decision approved use of a LLRW escalation rate of 6.93 percent per year for SONGS and 7.5 percent per year for Diablo Canyon. The resulting 2011 rates, using this approach, results in a disposal cost of

$76 per cubic foot for "Bulk" waste and a cost of $307 per cubic foot for "General" waste.

Class Band C Waste For purposes of this analysis, the WCS Andrews County, TX facility is used as the disposal site for the higher activity radioactive waste (Class Band C).The disposal costs for this waste is based on the following:

In 2008 there were no currently operating disposal facilities available to PG&E that had a license to dispose of the more highly radioactive waste (Classes B and C), for example, generated in the dismantling of the reactor vessel. As such, waste disposal costs were estimated using information extracted from the previously referenced study establishing appropriate disposal rates for decommissioning.

In March of 2012, the Texas compact opened its LLRW disposal site in Andrews County, Texas. This disposal site is operated by Waste Control Specialists LLC (WCS). Out-of-compact generators may send waste to WCS, if approved by the Texas Low-Level Radioactive Waste Compact Commission, at higher rates than in-compact generators.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 3 of 7 As of November 2011, rates for out-of-compact generators (including California utilities) in 2012 were projected to be $6,200 for Routine Class Band C waste, and

$18,500 per cubic foot for High Activity Class Band C waste.

While the projected decommissioning waste for Diablo Canyon has not been divided precisely into these WCS categories (which are different from other disposal sites),

it is clear that use of these rates for Diablo Canyon would result in LLRW disposal costs significantly higher than the 2008 rates ($2,916 per cubic foot) escalated to 2011 dollars ($3,572 per cubic foot). However, since the 2008 cost for Class Band C waste was not based on an available facility, the WCS rate for disposal of this waste has been used instead of the previous rate (w hich was based on costs from Barnwell, which is no longer available for California generators). A combination of the two WCS Class Band C rates would predict an average disposal cost of $7,384 per cubic foot (using the waste distribution provided by WCS). The 2011 study uses

$7,000 per cubic foot for disposal of Class Band C radioactive waste.

GTCC Waste The volume and cost to dispose of GTCC material is developed using the following method:

  • A projection of the amount of electricity delivered from the station through the end of currently licensed life is calculated. Using a rate of 1 mill per kw-hr (DOE standard contract rate) this is converted to a total spent fuel disposal cost for the station.

~ An estimate of the total weight of spent fuel generated through the end of currently licensed life is calculated.

  • An average disposal cost for the spent fuel (per pound) is calculated by dividing the total spent fuel disposal cost by the total spent fuel mass. This calculation results in the cost per pound used for disposal ($107 per pound).

~ This average disposal cost is applied against the total mass of GTCC material to estimate the GTCC disposal cost. This cost is also used in alternate scenarios (20 year license renewal) for consistency.

  • The reported disposal volume is calculated by assuming that GTCC waste is placed in a canister equivalent in size to a spent fuel canister (nominal 360 cubic feet, each) and loading these canisters with up to 20,000 pounds of waste. The reported disposal mass is the mass of the GTCC material plus the mass of the spent fuel canister (nominal 53,000 pounds).

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 4 of 7 TABLE 5.1 DECON ALTERNATIVE DECOMMISSIONING WASTE

SUMMARY

, UNIT 1 I Waste Volume I!

Weight Class I Waste ii Cost Basis [1] (cubic feet) I (pounds)

! iI I I Low-Level Radioactive Ii EnergySolutions I 94,959 I!

Waste (near-surface I LarKe Component A 7,860,384 disposal) I EnergySolutions I~.----------

General ..--..-----.----- .-..-_._._A.._...._----.- *-**-*--------*****--**-*-*--*---------**-*1--*--*-*-*-...

147,369 I I 9,579,584 I EnergySolutions I Bulk A 331,077 I 33,107,720 EnergySolutions DAW A 14,017 I 288,673 WCS ._-_.._......-.-B 1,732/

....__...._..__..... -_.._-_ ......__..........._-_...._._-._....._-_ ..._............_........"("-_. __... __ 197,501 WCS C 574 I 69,650 Greater than Class C Spent Fuel (geologic repository) I Equivalent GTCC 1,785 I! 350,510 Ij I

-..-..-..-.... ~-- ...*.-.-- .

i Total [2] 591,514 51,454,022

[1] Waste is classified according to the requirements as delineated in Title 10 CFR, Part 61.55

[2] Columns may not add due to rounding.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 5 of 7 TABLE 5.2 DECON ALTERNATIVE DECOMMISSIONING WASTE

SUMMARY

, UNIT 2 Waste Volume II Weight Waste Cost Basis Class [1] (cubic feet) (pounds)

Low-Level Radioactive I EnergySolutions Waste (near-surface I Large Component A 94,9591 7,860,384 disposal) EnergySolutions I General A 138,015 I

-*--**------**--**-*-*-*-*--*--**---r-**-*--**--*-*--*-.-.----.--.

9,004,003 EnergySolutions Bulk A 337,395 I 33,739,520 I EnergySolutions II IDAW A 15,898 327,416 I

WCS B 1,732 I 197,501

-~--------::r-:~

WCS Greater than Class C I Spent Fuel I Jgeologic repository) I Equivalent GTCC 1,785 i 350,510 i****-*-***---***-**---*---***-***--*****-*---**-*-*--*--*-**-***--*-*---*-**-*****---t----****------*------.-..- ...- ...-.--.-.--._-+---..-.--.-.-.-.-+ ..-..--.. . -..-..-.--.--.-.-.......--....- ..----..----*-+*----*---*-*-****-***-***----*--*-*i Total [2] 590,359 51,548,984

[1] Waste is classified according to the requirements as delineated in Title 10 CFR, Part 61.55

[2] Columns may not add due to rounding.

TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 6 of 7 TABLE 5.3 SAFSTOR ALTERNATIVE DECOMMISSIONING WASTE

SUMMARY

, UNIT 1 I Waste Volume I Weight Waste I Cost Basis Class [1] (cubic feet) I (pounds)

! i!

I!

I  !

Low -Level Radioactive I EnergySolutions I !

Waste (near-surface Large Component A 94,277 I 7,615,715 disposal) Energy Solutions I General --.--..

A

~--.--.-.

148,159 I 9,531,433

- - - - - . - - . - - -..- -..- . -....--t---..- ..- - . - - - - - - - - - - - - - - - - - . ,

EnergySolutions I

Bulk A 330,412 ! 33,041,160 I EnergySolutions I IDAW A 15,318 I 315,463 Iwcs B 3761 38,100 WCS C 5841 68,960 Greater than Class C Spent Fuel (geologic repository) Equivalent GTCC 1,7851 350,510 I

I Total [2]

Ii 590,911 I 50,961,341  !

[1] Waste is classified according to the requirements as delineated in Title 10 CFR, Part 61.55

[2] Columns may not add due to rounding.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 7 of 7 TABLE 5.4 SAFSTOR ALTERNATIVE DECOMMISSIONING WASTE

SUMMARY

, UNIT 2 i!

I Waste Volume  !

Weight Waste I Cost Basis Class [1] (cubic feet) I (pounds)

I I

I Low-Level Radioactive I EnergySolutions I i

Waste (near-surface  ! Large Component A 94,277 I 7,615,715 disposal) EnergySolutions i I

General ..-.--..

A

--.~---.--

138,969 I 8,975,852

.. ~-"--"----'------"---"--"'-'----""-""'r'--'-"'--...-.--------...-.-.--.-.--.

Energy Solutions Bulk A 335,149 I 33,514,930 EnergySolutions I

DAW A 15,850 I 326,419 WCS B 3761 38,100 WCS C I 5841 68,960 Greater than Class C Spent Fuel (geologic repository) Equivalent GTCC 1,785 350,510 I

Total [2] 586,991 II 50,890,486

[1] Waste is classified according to the requirements as delineated in Title 10 CFR, Part 61.55

[2] Columns may not add due to rounding.

TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 1 of 7

6. RESULTS The analysis to estimate the costs to decommission Diablo Canyon relied upon the site-specific, technical information extracted from the 2008 and previous estimates.

This information was reviewed for the current analysis and updated as deemed appropriate. The site-specific considerations and assumptions used in the previous evaluation were also revisited. Modifications were incorporated where new information was available or experience from ongoing decommissioning programs provided viable alternatives or improved processes. While not an engineering study, the estimates provide PG&E with sufficient information to assess their financial obligations, as they pertain to the eventual decommissioning of the nuclear station.

The estimates described in this report are based on numerous fundamental assumptions, including regulatory requirements, project contingencies, low-level radioactive waste disposal practices, high-level radioactive waste management options, and site restoration requirements. The decommissioning scenarios assume continued operation of the station's spent fuel pools for a minimum of twelve years following the cessation of operations for continued cooling of the assemblies.

The cost projected to promptly decommission (DECON) Diablo Canyon is estimated to be $2,786.1 million. The majority of this cost (approximately 73.1%) is associated with the physical decontamination and dismantling of the nuclear plant so that the operating license can be terminated. Another 16.4% is associated with the management, interim storage, and eventual transfer of the spent fueL The remaining 10.5% is for the demolition of the designated structures and limited restoration of the site.

The cost projected for deferred decommissioning (SAFSTOR) is estimated to be

$2,759.9 million. The majority of this cost (approximately 53.6%) is associated with placing the plant in storage, ongoing caretaking of the plant during dormancy, and the eventual physical decontamination and dismantling of the nuclear plant so that the operating license can be terminated. Another 35.8% is associated with the management, interim storage, and eventual transfer of the spent fueL The remaining 10.6% is for the demolition of the designated structures and limited restoration of the site.

The primary cost contributors, identified in Tables 6.1 thru 6.4, are either labor-related or associated with the management and disposition of the radioactive waste.

Program management is the largest single contributor to the overall cost. The magnitude of the expense is a function of both the size of the organization required to manage the decommissioning, as well as the duration of the program. The size and composition of the management organization varies with the decommissioning TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 2 of 7 phase and associated site activities. However, once the operating licenses are terminated, the staff is substantially reduced for the conventional demolition and restoration of the site, and the long-term care of the spent fuel (for the DECON alternative).

As described in this report, the spent fuel pools will remain operational for a minimum of twelve years following the cessation of operations. The pools will be isolated and independent spent fuel islands created. This will allow decommissioning operations to proceed in and around the pool areas. Over the twelve-year period, the spent fuel will be packaged into multi-purpose canisters for transfer to the ISFSI. Spent fuel stored in the ISFSI is assumed to be transferred to the DOE in order to support license termination within 60 years of shut down.

The cost for waste disposal includes those costs associated with the controlled disposition of the low-level radioactive waste generated from decontamination and dismantling activities, including plant equipment and components, structural material, filters, resins and dry-active waste. As described in Section 5, disposition of the majority of the low-level radioactive material requiring controlled disposal is at the EnergySolutions' facility. Highly activated components, requiring additional isolation from the environment (GTCC), are packaged for geologic disposal. The cost of geologic disposal is based upon a cost equivalent for spent fuel.

Decontamination and removal costs reflect the labor-intensive nature of the decommissioning process, as well as the management controls required to ensure a safe and successful program. Non-radiological demolition is a natural extension of the decommissioning process. With a work force mobilized to support decommissioning operations, non-radiological demolition can be an integrated activity and a logical expansion of the work being performed in the process of terminating the operating license. Prompt demolition reduces future liabilities and can be more cost effective than deferral, due to the deterioration of the facilities (and therefore the working conditions) with time.

The reported cost for transport includes the tariffs and surcharges associated with moving large components and/or overweight shielded casks overland, as well as the general expense, e.g., labor and fuel, of transporting material to the destinations identified in this report. For purposes of this analysis, material is primarily moved overland by truck.

Decontamination is used to reduce the plant's radiation fields and minimize worker exposure. Slightly contaminated material or material located within a contaminated area is sent to an off-site waste disposal facility, i.e., this analysis does not assume that contaminated plant components and equipment can be decontaminated for uncontrolled release in-situ.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 3 of 7 License termination survey costs are associated with the labor intensive and complex activity of verifying that contamination has been removed from the site to the levels specified by the NRC. This process involves a systematic survey of all remaining plant surface areas and surrounding environs, sampling, isotopic analysis, and documentation of the findings. The status of any plant components and materials not removed in the decommissioning process will also requIre confirmation and will add to the expense of surveying the facilities alone.

The remaining costs include allocations for heavy equipment and temporary services, as well as for other expenses such as regulatory fees and the premiums for nuclear insurance. While site operating costs are greatly reduced following the final cessation of plant operations, certain administrative functions do need to be maintained either at a basic functional or regulatory level.

Alternative Scenario In addition to the DECON and SAFSTOR alternatives considered in this analysis, one other decommissioning alternative was evaluated. The complete basis and results for this alternative are contained within the noted appendix.

Appendix E - DECON Alternative with 20 Year License Renewal The cost projected to promptly decommission Diablo Canyon under this alternative is estimated to be $2,624.4 million. The majority of this cost (approximately 77.4%)

is associated with the physical decontamination and dismantling of the nuclear plant so that the operating license can be terminated. Another 11.4% is associated with the management, interim storage, and eventual transfer of the spent fuel. The remaining 11.1% is for the demolition of the designated structures and limited restoration of the site.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 4 of 7 TABLE 6.1 DECON ALTERNATIVE DECOMMISSIONING COST ELEMENTS, UNIT 1 (thousands of 2011 dollars)

Cost Element Total I Percentage Decontamination 17,296 I 1.3 Removal 129,569 I 9.8

-P;~kagi~g-'-'----'--'-'--------'-----'-'-'------'-'-'.----.- -*----*-*-46~26s-T--------*--*3-~-*

Transportation 18,060 I 1.4 Waste

.. Disposal

-.------.--.. --.---..-.--------.----.-.-..----..----------.----.--.--------------t---------- 175,448 I 13.3 Program Management [1] 315,334 I 23.8 Security 273,454 I 20.7 I Spent Fuel Pool Isolation 24,045 I 1.8 Spent Fuel Management [2] 187,973 I 14.2 Insurance and Regulatory Fees 21,214 I 1.6

  • -E~;~-***---*-*-***-*-*-*--***--***-*-**-**-----*--*--.- . -.-.---.--.. .-.-.. . .--.. . . . . -.. . --.. . -.-. . --*----*----**---i-O~3-ii-*r*---------------**********O~'8 Characterization and Licensing Surveys 21,372 I 1.6

. . .!~E~P..~~~.~_!_~~~.~_. . ._.__.___. . _. . .__. _.____. _.__._. . .__._______._._. __. . _. . ._ ._. _. .-.---.-.--.-. -.. ._._.____. ~.?~_~.7.. J. _._ ._._. . ._._ . ________. _ _. .g~§_

Severance 74,269 I 5.6 Miscellaneous Equipment 7,849 I 0.6 Total [3] 1,322,468 I 100.0 Cost Element Total Percentage License

.._._..__._..__._... .... ._-_._.__._.__..._--_. __..*..._._._......_-_....-._....._._.__._--_..__._.. _._. . . ____.__. __. . Q.~!t, 92~_

__ __Termination --.--.--~

75.6 Spent Fuel Management 248,912 18.8 Site Restoration 73,630 5.6 Total [3] 1,322,468 100.0

[1] Includes engineering costs

[2] Excludes program management costs (staffing) but includes costs for spent fuel loadingltransfer costs/spent fuel pool O&M and EP fees

[3] Columns may not add due to rounding TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 5 of 7 TABLE 6.2 DECON ALTERNATIVE DECOMMISSIONING COST ELEMENTS, UNIT 2 (thousands of 2011 dollars)

Cost Element Total I Percentage Decontamination 20,420 I 1.4 Removal 283,111 I 19.3

---~k;gi~g--***---*---*-*--***-**-------*------*-"--.-.----------- . . . .*-----*-3~)"~786T--*--*--*--**---2-:7 nsportation 17,954 I 1.2 Waste Disposal 171,400 I 11

. Pr~-~;~-M~;;;ge~;~t-[i]------ . --*-- ******--*--**36S:34ST-*--*------25 Security 258,268 17.~

Spent Fuel Pool Isolation 15,996 ! 1.l Spent Fuel Management [2]

147,039 I i 10.0 Insurance and Regulatory Fees 18,358 I 1.3

.-.-.._ ..--...-.-_.--.---....-.--..._-.......--..-........-.....--...-......- ...-...-....-....-.._-...-.....-....-..-.--...-.-.-...--...--- ****--***-****-*-***---*-****-*---*--*--*-r-*..--*----..-...-.....- ...-..--.----..---.-

Energy 10,083 I 0.7 Characterization and Licensing Surveys 24,739 I 1. 7 Property Taxes 5,825 0.4 Severance 74,113 I

_-_._._-_...._._._....__....._..._._-._---Equipment

..Miscellaneous **......._.-_....._---_...__......._. __......._..__..._.__..__..__. - - -*.. --_..._-_._. __....._._-_. 8,167

__._.._-,. I __._--------_._.----

5.1 0.6 Total [3] 1,463,605 I 100.0 Cost Element Total Percentage

. J.~!~~~~~. . T~~.~i~~!i2.!!__.___. _. . . _._. . . . . . _. _._. . . _. ._. _. __.____. . ._. . . .__._. _. . . . . .J.?..9._?_~2...? 7~__._____.___. .___. . _'1..9* ~_

. Spent Fuel Management 207,854 14.2

._~i!.~. B~_~tora~ion____.__.___. __________________.__._. ____._. __.__._.~ 19~!}~ ____________E...:2...

Total [3] 1,463,605 100.0

[1] Includes engineering costs

[2] Excludes program management costs (staffing) but includes costs for spent fuel loading/transfer costs/spent fuel pool O&M and EP fees

[3] Columns may not add due to rounding TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 6 of 7 TABLE 6.3 SAFSTOR ALTERNATIVE DECOMMISSIONING COST ELEMENTS, UNIT 1 (thousands of 2011 dollars)

Cost Element Total I Percentage Decontamination 13,853 I 1.0 I Removal

'-p;~;gi~g--'-"'--'-'--'------"--"--'-'-'----'---' . . --..-.--..---.. * *. *-*-..* -. . -***--.. 128,358 30~285-1-*----**--**

I 9.2 2.2 Transportation 15,714 I 1.1 Waste Disposal

. - - - . - - - - -....--.-....----.--..- ..- - - - . - - -..- ..--.-----..-----....- - . - - - - - . - - -..- ....- ...--.------.-..- . - -..- .. t - . -....-

162,651 I 11.7 Program Management [1] 449,004 I 32.2 Security 214,618 I 15.4 Spent Fuel Pool Isolation 24,155 I 1. 7

~pent Fuel Management [2] 186,420 I 13.4

~~~~~~-----f--it~f---H-Characterization and Licensing Surveys 23,406 I 1.7 Property Taxes 7,750 I 0.6 Severance 74,608 I 5.3

-...Miscellaneous

--.-.. -.-.--..----.-.--.-.--.-.-----......... Equipment -.-....--..---....-.---.-----.----.-..-...-...-.-.-.-.. -......-....---...-. -.---..- . . -.-.--.....13,996 I -...-...-...-.--....-....-..--..-.-...-..----.

-.-..-..-...-.--...-..1"-.... 1.0. . ..

Total [3] 1,395,643 i 100.0 Cost Element Total Percentage License

.............. _._...._-_..._.__Termination

... ........... _.._.._ __.._.._...._..._.__..._._.._...._..._ _ -_ _._.................._..._.._ 736,693 52.8 Spent Fuel Management 584,671 41.9 Site Restoration 74,279 5.3 Total [3] 1,395,643 100.0

[1] Includes engineering costs

[2] Excludes program management costs (staffmg) but includes costs for spent fuel loadingltransfer costs/spent fuel pool O&M and EP fees

[3] Columns may not add due to rounding TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 7 of 7 TABLE 6.4 SAFSTOR ALTERNATIVE DECOMMISSIONING COST ELEMENTS, UNIT 2 (thousands of 2011 dollars)

Cost Element Total I Percentage I

Decontamination 20,517 I 1.5

-~~----~-"-----~~1-Transportation 15,641 I 1.1 Waste Disposal

- -..--.--.------------..-.----....- ...-.--..-----.-....--.....- - - - - - -..- . - -....---.---.--t------.--..-.---....- - - - -..

157,468 I 11.5 Program Management [1] 323,748 I 23.7 Security 205,101 I 15.0 Spent Fuel Pool Isolation 16,006 I 1.2 Spent Fuel Management [2] 144,752 I 10.6 Insurance and Regulatory Fees 33,152 I

.....- .........- ...._ ....- ....................- ....................- ...........- ...- . -..- ...- ......- -...-.-......t-..- . _ - -..._ -..- - . -..- ..._ ...-

2.4

! Energy 14,907 I 1.1 Characterization and Licensing Surveys 26,614 I 2.0 Property Taxes 7,564 I 0.6 Severance 74,158 I 5.4

. .Miscellaneous Equipment 14,476 . . .*. .*. . *-. . *r*I . . -.._. -..*. --..*-*. -_*.*--..--.-.

1.1.-.

Total [3] 1,364,305 I 100.0 st Element Total Percent

. . 1i~~.!?:~~.J~.erpli.!?-_~.!i2!.!. . . . .__. ._. ._. . .__. . _._. ._. __. . . ._. . _. . . . . . . . _... . . . . . . .___. __. ._.Z~!1. g§. ~. . . . _. ._._. ._.__. . . _. . . ._. . . . ._. __.____. .__.

Sent Fuel Mana ement 403,424 Total [3] 1,364,305 100.0

[1] Includes engineering costs

[2] Excludes program management costs (staffing) but includes costs for spent fuel loading/transfer costs/spent fuel pool O&M and EP fees

[3] Columns may not add due to rounding TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 7, Page 1 of 3

7. REFERENCES
1. U.S. Code of Federal Regulations, Title 10, Parts 30, 40, 50, 51, 70 and 72, "General Requirements for Decommissioning Nuclear Facilities," Nuclear Regulatory Commission, 53 Fed. Reg. 24018, June 27,1988.
2. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.159, "Assuring the Availability of Funds for Decommissioning Nuclear Reactors," Rev. 2, October 2011.
3. U.S. Code of Federal Regulations, Title 10, Part 20, Subpart E, "Radiological Criteria for License Termination."
4. U.S. Code of Federal Regulations, Title 10, Parts 20 and 50, "Entombment Options for Power Reactors," Advanced Notice of Proposed Rulemaking, 66 Fed.

Reg. 52551, October 16, 2001.

5. U.S. Code of Federal Regulations, Title 10, Parts 2, 50 and 51, "Decommissioning of Nuclear Power Reactors," Nuclear Regulatory Commission, 61 Fed. Reg. 39278, July 29, 1996.
6. "Nuclear Waste Policy Act of 1982 and Amendments," U.S. Department of Energy's Office of Civilian Radioactive Management, 1982
7. U.S. Code of Federal Regulations, Title 10, Part 50, "Domestic Licensing of Production and Utilization Facilities," Subpart 54 (bb), "Conditions of Licenses."
8. "Low Level Radioactive Waste Policy Act," Public Law 96-573, 1980.
9. "Low-Level Radioactive Waste Policy Amendments Act of 1985," Public Law 99-240,1986.
10. U.S. Code of Federal Regulations, Title 10, Part 61.55 "Waste Classification."
11. "Establishing an Appropriate Disposal Rate for Low Level Radioactive Waste During Decommissioning", Robert A Snyder, NEWEX, Revision 0, July 2008.
12. U.S. Code of Federal Regulations, Title 10, Part 20, Subpart E, "Final Rule, Radiological Criteria for License Termination," 62 Fed. Reg. 39058, July 21, 1997.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 7, Page 2 of 3

7. REFERENCES (continued)
13. "Establishment of Cleanup Levels for CERCLA Sites with Radioactive Contamination," EPA Memorandum OSWER No. 9200.4-18, August 22, 1997.
14. U.S. Code of Federal Regulations, Title 40, Part 141.16, "Maximum contaminant levels for beta particle and photon radioactivity from man-made radionuclides in community water systems."
15. "Memorandum of Understanding Between the Environmental Protection Agency and the Nuclear Regulatory Commission: Consultation and Finality on Decommissioning and Decontamination of Contaminated Sites," OSWER 9295.8-06a, October 9, 2002.
16. "Multi-Agency Radiation Survey and Site Investigation Manual (MARSSIM),"

NUREG/CR-1575, Rev. 1, EPA 402-R-97-016, Rev. 1, August 2000

17. T.S. LaGuardia et aI., "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates," AIF/NESP-036, May 1986.
18. W.J. Manion and T.S. LaGuardia, "Decommissioning Handbook," U.S.

Department of Energy, DOE/EV/I0128-1, November 1980.

19. "Building Construction Cost Data 2011," Robert Snow Means Company, Inc.,

Kingston, Massachusetts.

20. Project and Cost Engineers' Handbook, Second Edition, p. 239, American Association of Cost Engineers, Marcel Dekker, Inc., New York, New York, 1984.
21. "Technical Position Paper for Establishing an Appropriate Contingency Factor for Inclusion in the Decommissioning Revenue Requirements", Study Number:

DECON-POS-H002, Revision A, Status: Preliminary (provided by PG&E).

22. U.S. Department of Transportation, Title 49 of the Code of Federal Regulations, "Transportation," Parts 173 through 178.
23. Tri-State Motor Transit Company, published tariffs, Interstate Commerce Commission (ICC), Docket No. MC-427719 Rules Tariff, March 2004, Radioactive Materials Tariff, August 2011.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Section 7, Page 3 of 3

7. REFERENCES (continued)
24. J.C. Evans et aI., "Long-Lived Activation Products in Reactor Materials" NUREG/CR-34 74, Pacific Northwest Laboratory for the Nuclear Regulatory Commission, August 1984.
25. R.I. Smith, G.J. Konzek, W.E. Kennedy, Jr., "Technology, Safety and Costs of Decommissioning a Reference Pressurized Water Reactor Power Station,"

NUREG/CR-0130 and addenda, Pacific Northwest Laboratory for the Nuclear Regulatory Commission, June 1978.

26. H.D. Oak, et aI., "Technology, Safety and Costs of Decommissioning a Reference Boiling Water Reactor Power Station," NUREG/CR-0672 and addenda, Pacific Northwest Laboratory for the Nuclear Regulatory Commission, June 1980.
27. "Financial Protection Requirements for Permanently Shutdown Nuclear Power Reactors," 10 CFR Parts 50 and 140, Proposed Rule, 62 Fed. Reg. 58690, October 30, 1997.
28. "Microsoft Project Professional 2010," Microsoft Corporation, Redmond, WA.
29. "Atomic Energy Act of 1954," (68 Stat. 919).

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 1 of 4 APPENDIX A UNIT COST FACTOR DEVELOPMENT TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 2 of 4 APPENDIX A UNIT COST FACTOR DEVELOPMENT Example: Unit Factor for Removal of Contaminated Heat Exchanger < 3,000 lbs.

1. SCOPE Heat exchangers weighing < 3,000 lbs. will be removed in one piece using a crane or small hoist. They will be disconnected from the inlet and outlet piping. The heat exchanger will be sent to the waste processing area.
2. CALCULATIONS Activity Critical Act Activity Duration Duration ID Description (minutes) (minutes)*

a Remove insulation 60 (b) b Mount pipe cutters 60 60 c Install contamination controls 20 (b) d Disconnect inlet and outlet lines 60 60 e Cap openings 20 (d) f Rig for removal 30 30 g Unbolt from mounts 30 30 h Remove contamination controls 15 15 1 Remove, wrap, send to waste processing area 60 ~

Totals (Activity/Critical) 355 255 Duration adjustment(s):

+ Respiratory protection adjustment (50% of critical duration) 128

+ RadiationiALARA adjustment (37.1% of critical duration) 95 Adjusted work duration 478

+ Protective clothing adjustment (30% of adjusted duration) 143 Productive work duration 621

+ Work break adjustment (8.33 % of productive duration)

Total work duration (minutes) 673

      • Total duration = 11.217 hr ***
  • alpha designators indicate activities that can be performed in parallel TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 3 of 4 APPENDIX A (continued)

3. LABOR REQUIRED Duration Rate Crew Number (hours) ($/hr) Cost Laborers 3.00 11.217 $57.61 $1,938.63 Craftsmen 2.00 11.217 $70.00 $1,570.38 Foreman 1.00 11.217 $74.17 $831.96 General Foreman 0.25 11.217 $77.53 $217.41 Fire Watch 0.05 11.217 $57.61 $32.31 Health Physics Technician 1.00 11.217 $75.96 $852.04 Total Labor Cost $5,442.73
4. EQUIPMENT & CONSUMABLES COSTS Equipment Costs none ConsumableslMaterials Costs

-Universal Sorbent 50 @ $0.6 sq. ft. {l} , $30.00

-Tarpaulins (7.5 mils, oil resistant, fire retardant) 50 @ $0.44/sq. ft. {2} $22.00

-Gas torch consumables 1 @ $11.43/hr. x 1 hr. {3} $11.43 Subtotal cost of equipment and materials $63.43 Overhead & profit on equipment and materials @ 17.75 % $11.26 Total costs, equipment & material $74.69 TOTAL COST:

Removal of contaminated heat exchanger <3000 pounds: $5,517.42 Total labor cost: $5,442.73 Total equipment/material costs: $74.69 Total craft labor man-hours required per unit: 81.88 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 4 of 4

5. NOTES AND REFERENCES

$ Work difficulty factors were developed in conjunction with the Atomic Industrial Forum's (now NEI) program to standardize nuclear decommissioning cost estimates and are delineated in Volume 1, Chapter 5 of the "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates," AIF/NESP-036, May 1986.

  • References for equipment & consumables costs:
1. W\VW .mClnaster .conl online catalog, McMaster Carr Spill Control (7193T88)
2. R.S. Means (2011) Division 01 56, Section 13.60-0600, page 20
3. R.S. Means (2011) Division 01 5433, Section 40-6360, page 664
  • Material and consumable costs were adjusted using the regional indices for San Luis Obispo, California.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 1 of 7 APPENDIXB UNIT COST FACTOR LISTING (DECON: Power Block Structures Only)

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 2 of 7 APPENDIXB UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit($)

Removal of clean instrument and sampling tubing, $Ilinear foot 0.34 Removal of clean instrument and sampling tubing, $/linear foot 0.62 Removal of clean pipe 0.25 to 2 inches diameter, $/linear foot 6.65 Removal of clean pipe >2 to 4 inches diameter, $/linear foot 9.42 Removal of clean pipe >4 to 8 inches diameter, $/linear foot 18.11 Removal of clean pipe >8 to 14 inches diameter, $/linear foot 35.21 Removal of clean pipe> 14 to 20 inches diameter, $/linear foot 45.67 Removal of clean pipe >20 to 36 inches diameter, $/linear foot 67.22 Removal of clean pipe >36 inches diameter, $Ilinear foot 79.92 Removal of clean valve >2 to 4 inches 120.67 Removal of clean valve >4 to 8 inches 181.05 Removal of clean valve >8 to 14 inches 352.11 Removal of clean valve> 14 to 20 inches 456.72 Removal of clean valve >20 to 36 inches 672.25 Removal of clean valve >36 inches 799.18 Removal of clean pipe hanger for small bore piping 39.70 Removal of clean pipe hanger for large bore piping 145.82 Removal of clean pump, <300 pound 303.21 Removal of clean pump, 300-1000 pound 837.32 Removal of clean pump, 1000-10,000 pound 3,332.94 Removal of clean pump, >10,000 pound 6,438.29 Removal of clean pump motor, 300-1000 pound 352.43 Removal of clean pump motor, 1000-10,000 pound 1,388.37 Removal of clean pump motor, > 10,000 pound 3,123.85 Removal of clean heat exchanger <3000 pound 1,786.79 Removal of clean heat exchanger >3000 pound 4,487.38 Removal of clean feedwater heater/deaerator 12,670.50 Removal of clean moisture separator/reheater 26,076.35 Removal of clean tank, <300 gallons 390.29 Removal of clean tank, 300-3000 gallon 1,234.81 TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 3 of 7 APPENDIXB UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor CostlUnit($)

Removal of clean electrical equipment, <300 pound 166.34 Removal of clean electrical equipment, 300-1000 pound 573.79 Removal of clean electrical equipment, 1000-10,000 pound 1,147.59 Removal of clean electrical equipment, > 10,000 pound 2,720.43 Removal of clean electrical transformer < 30 tons 1,889.30 Removal of clean electrical transformer> 30 tons 5,440.85 Removal of clean standby diesel generator, <100 kW 1,929.75 Removal of clean standby diesel generator, 100 kW to 1 MW 4,307.34 Removal of clean standby diesel generator, > 1 MW 8,917.06 Removal of clean electrical cable tray, $/linear foot 15.49 Removal of clean electrical conduit, $/linear foot 6.76 Removal of clean mechanical equipment, <300 pound 166.34 Removal of clean mechanical equipment, 300-1000 pound 573.79 Removal of clean mechanical equipment, 1000-10,000 pound 1,147.59 Removal of clean mechanical equipment, > 10,000 pound 2,720.43 Removal of clean HVAC equipment, <300 pound 201.14 Removal of clean HVAC equipment, 300-1000 pound 689.47 Removal of clean HVAC equipment, 1000-10,000 pound 1,374.09 Removal of clean HVAC equipment, > 10,000 pound 2,720.43 Removal of clean HVAC ductwork, $/pound 0.66 Removal of contaminated instrument and sampling tubing, $/linear foot 2.04 Removal of contaminated pipe 0.25 to 2 inches diameter, $/linear foot 27.70 Removal of contaminated pipe >2 to 4 inches diameter, $/linear foot 47.43 Removal of contaminated pipe >4 to 8 inches diameter, $/linear foot 75.37 Removal of contaminated pipe >8 to 14 inches diameter, $/linear foot 147.47 Removal of contaminated pipe> 14 to 20 inches diameter, $/linear foot 177.17 Removal of contaminated pipe >20 to 36 inches diameter, $/linear foot 245.44 Removal of contaminated pipe >36 inches diameter, $/linear foot 290.25 Removal of contaminated valve >2 to 4 inches 577.75 Removal of contaminated valve >4 to 8 inches 689.57 TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 4 of 7 APPENDIXB UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor CostlUnit($)

Removal of contaminated valve >8 to 14 inches 1,413.45 Removal of contaminated valve> 14 to 20 inches 1,796.30 Removal of contaminated valve >20 to 36 inches 2,393.21 Removal of contaminated valve >36 inches 2,841.23 Removal of contaminated pipe hanger for small bore piping 190.43 Removal of contaminated pipe hanger for large bore piping 623.87 Removal of contaminated pump, <300 pound 1,227.21 Removal of contaminated pump, 300-1000 pound 2,803.76 Removal of contaminated pump, 1000-10,000 pound 9,063.05 Removal of contaminated pump, > 10,000 pound 22,071.48 Removal of contaminated pump motor, 300-1000 pound 1,193.21 Removal of contaminated pump motor, 1000-10,000 pound 3,690.68 Removal of contaminated pump motor, > 10,000 pound 8,286.03 Removal of contaminated heat exchanger <3000 pound 5,517.42 Removal of contaminated heat exchanger >3000 pound 15,980.87 Removal of contaminated tank, <300 gallons 2,040.84 Removal of contaminated tank, >300 gallons, $/square foot 39.33 Removal of contaminated electrical equipment, <300 pound 957.45 Removal of contaminated electrical equipment, 300-1000 pound 2,294.23 Removal of contaminated electrical equipment, 1000-10,000 pound 4,418.75 Removal of contaminated electrical equipment, > 10,000 pound 8,612.27 Removal of contaminated electrical cable tray, $/linear foot 46.12 Removal of contaminated electrical conduit, $/linear foot 22.38 Removal of contaminated mechanical equipment, <300 pound 1,065.25 Removal of contaminated mechanical equipment, 300-1000 pound 2,533.85 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 5 of 7 APPENDIXB UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor CostlUnit($)

Removal of contaminated mechanical equipment, 1000-10,000 pound 4,872.29 Removal of contaminated mechanical equipment, > 10,000 pound 8,612.27 Removal of contaminated HVAC equipment, <300 pound 1,065.25 Removal of contaminated HVAC equipment, 300-1000 pound 2,533.85 Removal of contaminated HVAC equipment, 1000-10,000 pound 4,872.29 Removal of contaminated HVAC equipment, > 10,000 pound 8,612.27 Removal of contaminated HVAC ductwork, $/pound 2.77 Removal/plasma arc cut of contaminated thin metal components, $/linear in. 5.00 Additional decontamination of surface by washing, $/square foot 10.55 Additional decontamination of surfaces by hydrolasing, $/square foot 43.80 Decontamination rig hook up and flush, $1 250 foot length 8,987.09 Chemical flush of components/systems, $/gallon 19.14 Removal of clean standard reinforced concrete, $/cubic yard 165.89 Removal of grade slab concrete, $/cubic yard 221.88 Removal of clean concrete floors, $/cubic yard 423.47 Removal of sections of clean concrete floors, $/cubic yard 1,280.23 Removal of clean heavily rein concrete wl#9 rebar, $/cubic yard 276.86 Removal of contaminated heavily rein concrete wl#9 rebar, $/cubic yard 2,579.29 Removal of clean heavily rein concrete wl#18 rebar, $/cubic yard 349.92 Removal of contaminated heavily rein concrete wl#18 rebar, $/cubic yard 3,411.52 Removal heavily rein concrete wl#18 rebar & steel embedments, $/cubic yard 544.96 Removal of below-grade suspended floors, $/cubic yard 423.47 Removal of clean monolithic concrete structures, $/cubic yard 1,073.10 Removal of contaminated monolithic concrete structures, $/cubic yard 2,568.55 Removal of clean foundation concrete, $/cubic yard 841.27 Removal of contaminated foundation concrete, $/cubic yard 2,392.56 Explosive demolition of bulk concrete, $/cubic yard 36.16 Removal of clean hollow masonry block wall, $/cubic yard 119.27 Removal of contaminated hollow masonry block wall, $/cubic yard 422.83 Removal of clean solid masonry block wall, $/cubic yard 119.27 TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 6 of 7 APPENDIXB UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor CostlUnit($)

Removal of contaminated solid masonry block wall, $/cubic yard 422.83 BackfIll of below-grade yoids, $/cubic yard 34.85 Removal of subterranean tunnels/voids, $/linear foot 137.89 Placement of concrete for below-grade voids, $/cubic yard 143.45 Excavation of clean material, $/cubic yard 3.69 Excavation of contaminated material, $/cubic yard 49.48 Removal of clean concrete rubble (tipping fee included), $/cubic yard 26.59 Removal of contaminated concrete rubble, $/cubic yard 30.10 Removal of building by volume, $/cubic foot 0.35 Removal of clean building metal siding, $/square foot 1.48 Removal of contaminated building metal siding, $/square foot 5.44 Removal of standard asphalt roofIng, $/square foot 2.91 Removal of transite panels, $/square foot 2.60 Scarifying contaminated concrete surfaces (drill & spall), $/square foot 15.71 Scabbling contaminated concrete floors, $/square foot 9.77 Scabbling contaminated concrete walls, $/square foot 26.03 Scabbling contaminated ceilings, $/square foot 89.56 Scabbling structural steel, $/square foot 8.04 Removal of clean overhead crane/monorail < 10 ton capacity 794.26 Removal of contaminated overhead crane/monorail < 10 ton capacity 2,338.53 Removal of clean overhead crane/monorail> 10-50 ton capacity 1,906.21 Removal of contaminated overhead crane/monorail> 10-50 ton capacity 5,611.50 Removal of polar crane> 50 ton capacity 7,948.73 Removal of gantry crane> 50 ton capacity 34,005.31 Removal of structural steel, $/pound 0.25 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 7 of 7 APPENDIXB UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor CostlUnit($)

Removal of clean steel floor grating, $/square foot 5.51 Removal of contaminated steel floor grating, $/square foot 16.62 Removal of clean free standing steel liner, $/square foot . 15.36 Removal of contaminated free standing steel liner, $/square foot 46.07 Removal of clean concrete-anchored steel liner, $/square foot 7.68 Removal of contaminated concrete-anchored steel liner, $/square foot 53.66 Placement of scaffolding in clean areas, $/square foot 19.77 Placement of scaffolding in contaminated areas, $/square foot 33.59 Landscaping with topsoil, $/acre 31,625.69 Cost of CPC B-88 LSA box & preparation for use 2,361.61 Cost of CPC B-25 LSA box & preparation for use 2,164.01 Cost of CPC B-12V 12 gauge LSA box & preparation for use 1,763.72 Cost of CPC B-144 LSA box & preparation for use 11,896.44 Cost of LSA drum & preparation for use 231.23 Cost of cask liner for CNSI 8 120A cask (resins) 8,816.85 Cost of cask liner for CNSI 8 120A cask (filters) 9,211.82 Decontamination of surfaces with vacuuming, $/square foot 0.96 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 1 of 20 APPENDIXC DETAILED COST ANALYSIS DECON TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 2 of 20 Table C-l Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours PERIOD la - Shutdown through Transition Period la Direct Decommissioning Activities 1a.1.1 Prepare preliminary decommissioning cost 191 41 232 232 1,300 1a.1.2 Notification of Cessation of Operations a la.1.3 Remove fuel & source material nfa la.1.4 Notification of Permanent Defueling a 1a.1.5 Deactivate plant systems & process waste a 1a.1.6 Prepare and submit PSDAR 294 63 357 357 2,000 1a.1.7 Review plant dwgs & specs. 676 144 820 820 4,600 1a.1.8 Perform detailed rad survey a la.1.9 Estimate by-product inventory 147 31 178 178 1,000 1a. 1. 10 End product description 147 31 178 178 1,000 1a. 1. 11 Detailed by-product inventory 191 41 232 232 1,300 1a.1.12 Define major work sequence 1,103 235 1,337 1,337 7,500 1a.1.13 Perform SER and EA 456 97 553 553 3,100 1a.1.14 Perform Site-Specific Cost Study 735 156 891 891 5,000 1a.1.15 Prepare/submit License Termination Plan 602 128 730 730 4,096 1a.1.16 Receive NRC approval oftermination plan a Activity Specifications 1a.1.17.1 Plant & temporary facilities 723 154 877 789 88 4,920 1a.1.17.2 Plant systems 613 130 743 669 74 4,167 la.1.17.3 NSSS Decontamination Flush 74 16 89 89 500 1a.1.17.4 Reactor internals 1,044 222 1,266 1,266 7,100 la.1.17.5 Reactor vessel 956 203 1,159 1,159 6,500 1a.1.17.6 Biological shield 74 16 89 89 500 1a.1.17.7 Steam generators 459 98 556 556 3,120 1a.1.17.8 Reinforced concrete 235 50 285 143 143 1,600 la.1.17.9 Main Turbine 59 13 71 71 400 1a.1.17.10 Main Condensers 59 13 71 71 400 1a.1.17.11 Plant structures & buildings 459 98 556 278 278 3,120 1a.1.17.12 Waste management 676 144 820 820 4,600 1a.1.17.13 Facility & site closeout 132 28 160 80 80 900 la.1.17 Total 5,561 1,184 6,744 5,938 806 37,827 Planning & Site Preparations 1a.1.18 Prepare dismantling sequence 353 75 428 428 2,400 1a.1.19 Plant prep. & temp. svces 2,800 596 3,396 3,396 1a.1.20 Design water clean-up system 206 44 250 250 1,400 1a.1.21 Rigging/Cont. Cntd Envlps/tooling/etc. 2,200 468 2,668 2,668 1a.1.22 Procure caskslliners & containers 181 38 219 219 1,230 1a.1 Subtotal Period 1a Activity Costs 15,842 3,372 19,214 18,408 806 73,753 Period 1a Additional Costs 1a.2.1 Spent Fuel Pool Isolation 19,825 4,220 24,045 24,045 la.2.2 Disposal of Contaminated Tools & Equipment 234 97 3,145 1,170 4,646 4,646 10,245 609,715 317 1a.2 Subtotal Period 1a Additional Costs 234 97 3,145 19,825 5,389 28,691 28,691 10,245 609,715 317 Period la Period-Dependent Costs 1a.4.1 Insurance 1,056 150 1,205 1,205 1a.4.2 Property taxes 165 23 189 189 1a.4.3 Health physics supplies 485 172 657 657 1a.4.4 Heavy equipment rental 480 102 582 582 la.4.5 Disposal ofDAW generated 15 4 49 21 89 89 645 13,281 20 1a.4.6 Plant energy budget 1,156 246 1,402 1,402 1a.4.7 NRC Fees 1,177 167 1,344 1,344 1a.4.8 Emergency Planning Fees 1,001 142 1,143 1,143 1a.4.9 Spent Fuel Pool O&M 763 162 926 926 1a.4.10 ISFSI Operating Costs 45 10 54 54 1a.4.11 Severance Related Costs 35,456 7,547 43,002 43,002 1a.4.12 Spent Fuel Storage Canisters/Overpacks 7,353 1,565 8,919 8,919 1a.4.13 Security Staff Cost 14,837 3,158 17,995 17,995 229,429 1a.4.14 Utility Staff Cost 33,000 7,024 40,024 40,024 423,400 1a.4 Subtotal Period 1a Period-Dependent Costs 965 15 4 49 96,010 20,489 117,533 106,491 11,042 645 13,281 20 652,829 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 3 of 20 Table C-l Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial f Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours 1a.0 TOTAL PERIOD la COST 965 249 101 3,194 131,677 29,250 165,437 153,590 11,042 806 10,890 622,996 337 726,581 PERIOD 1b - Decommissioning Preparations Period 1b Direct Decommissioning Activities Detailed Work Procedures Ib. 1. 1.1 Plant systems 696 148 844 759 84 4,733 lb. 1. 1.2 NSSS Decontamination Flush 147 31 178 178 1,000 1b.1.1.3 Reactor internals 368 78 446 446 2,500 1h. 1. 1.4 Remaining buildings 198 42 241 60 181 1,350 lb. 1. 1.5 CRD cooling assembly 147 31 178 178 1,000 lb. 1. 1.6 CRD housings & ICI tubes 147 31 178 178 1,000 lb. 1. 1. 7 Incore instrumentation 147 31 178 178 1,000 lb. 1. 1.8 Reactor vessel 534 114 647 647 3,630 lb. 1.1.9 Facility closeout 176 38 214 107 107 1,200 lb. 1. 1.10 Missile shields 66 14 80 80 450 1h. 1. 1.11 Biological shield 176 38 214 214 1,200 1h. 1. 1.12 Steam generators 676 144 820 820 4,600 lb. 1. 1.13 Reinforced concrete 147 31 178 89 89 1,000 lb. 1. 1.14 Main Turbine 229 49 278 278 1,560 lb. 1. 1.15 Main Condensers 229 49 278 278 1,560 lb. 1. 1.16 Auxiliary building 401 85 487 438 49 2,730 lb. 1.1.17 Reactor building 401 85 487 438 49 2,730 lb. 1.1 Total 4,887 1,040 5,927 4,812 1,115 33,243 1h.1.2 Decon primary loop 750 532 1,283 1,283 1,067 1b.1 Subtotal Period 1b Activity Costs 750 4,887 1,573 7,210 6,095 1,115 1,067 33,243 Period 1b Additional Costs 1b.2.1 Site Characterization 4,765 2,029 6,794 6,794 25,000 9,412 1b.2.2 Hazardous Waste Management 204 43 247 247 1b.2.3 Mixed Waste Management 270 57 327 327 1h.2 Subtotal Period 1b Additional Costs 5,239 2,129 7,368 7,368 25,000 9,412 Period 1b Collateral Costs 1b.3.1 Decon equipment 931 198 1,129 1,129 1b.3.2 DOC staff relocation expenses 1,415 301 1,716 1,716 1b.3.3 Process decommissioning water waste 46 21 66 88 81 302 302 291 17,471 57 1b.3.4 Process decommissioning chemical flush waste 2 63 256 6,210 2,267 8,797 8,797 887 94,531 166 1b.3.5 Small tool allowance 3 1 3 3 1b.3.6 Pipe cutting equipment 1,100 234 1,334 1,334 1b.3.7 Decon rig 1,500 319 1,819 1,819 1b.3.8 Spent Fuel Transfer - Pool to ISFSI 1,989 423 2,412 2,412 1b.3 Subtotal Period 1b Collateral Costs 2,479 1,103 84 321 6,298 3,404 3,825 17,513 15,100 2,412 291 887 112,002 223 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 28 10 38 38 1b.4.2 Insurance 523 74 598 598 1b.4.3 Property taxes 82 12 94 94 1b.4.4 Health physics supplies 269 96 365 365 1h.4.5 Heavy equipment rental 238 51 288 288 1b.4.6 DisposalofDAW generated 9 3 28 12 52 52 375 7,718 12 1b.4.7 Plant energy budget 1,147 244 1,391 1,391 1b.4.8 NRC Fees 346 49 395 395 1b.4.9 Emergency Planning Fees 497 70 567 567 1h.4.10 Spent Fuel Pool O&M 378 81 459 459 1h.4.11 ISFSI Operating Costs 22 5 27 27 1b.4.12 Severance Related Costs 5,351 1,139 6,490 6,490 1b.4.13 Spent Fuel Storage Canisters/Overpacks 7,347 1,564 8,911 8,911 1b.4.14 Security Staff Cost 7,357 1,566 8,924 8,924 113,771 Ib.4.15 DOC Staff Cost 6,563 1,397 7,960 7,960 63,091 1b.4.16 Utility Staff Cost 16,460 3,504 19,963 19,963 210,994 1b.4 Subtotal Period 1b Period-Dependent Costs 28 507 9 3 28 46,074 9,872 56,522 46,557 9,964 375 7,718 12 387,857 1h.0 TOTAL PERIOD 1b COST 3,257 1,610 93 324 6,326 59,604 17,399 88,612 75,121 12,377 1,115 666 887 119,720 26,301 430,512 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 4 of 20 Table C-l Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours PERIOD 1 TOTALS 3,257 2,575 342 425 9,520 191,280 46,649 254,049 228,711 23,418 1,920 11,556 887 742,716 26,638 1,157,093 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.1 Reactor Coolant Piping 370 354 52 40 1,342 880 3,038 3,038 2,276 260,153 10,138 2a. 1. 1.2 Pressurizer Quench Tank 39 35 8 6 189 110 387 387 329 36,557 1,073 2a.1.1.3 Reactor Coolant Pumps & Motors 118 126 103 185 1,443 694 2,669 2,669 4,701 774,960 4,185 100 2a.1.1.4 Pressurizer 50 70 448 114 750 414 1,846 1,846 2,443 286,592 2,365 938 2a.1.1.5 Steam Generators 477 4,206 3,368 1,922 12,807 7,260 30,039 30,039 41,712 3,350,761 27,047 1,750 2a.1.1.6 Retired Steam Generator Units 2,496 1,878 12,597 5,223 22,194 22,194 41,031 3,125,629 14,613 1,125 2a.1.1.7 CRDMslICIs/Service Structure Removal 196 112 262 37 444 381 1,433 1,433 3,881 86,025 4,285 2a.1.1.8 Reactor Vessel Internals 175 3,110 14,996 1,468 10,438 283 16,741 47,212 47,212 1,753 845 574 359,588 30,500 1,352 2a. 1. 1.9 Reactor Vessel 122 5,226 2,439 742 2,651 283 8,718 20,181 20,181 8,794 957,382 30,500 1,352 2a.1.1 Totals 1,546 13,241 24,170 6,392 42,661 567 40,422 128,998 128,998 106,920 845 574 9,237,647 124,706 6,617 Removal of Major Equipment 2a.1.2 Main Turbine/Generator 202 43 245 245 3,033 2a.1.3 Main Condensers 668 142 810 810 9,875 Cascading Costs from Clean Building Demolition 2a.1.4.1 *Reactor 1,194 254 1,448 1,448 11,895 2a.1.4.2 Containment Penetration Area 73 16 89 89 704 2a.1.4.3 Fuel Handling 193 41 234 234 1,746 2a.1.4 Totals 1,460 311 1,771 1,771 14,345 Disposal of Plant Systems 2a.1.5.1 Auxiliary Steam 148 31 179 179 2,310 2a.1.5.2 Auxiliary Steam (RCA) 277 61 19 652 342 1,351 1,351 2,054 126,415 3,758 2a.1.5.3 Condensate System 679 145 824 824 10,671 2a.1.5.4 Condensate System (Insulated) 281 60 341 341 4,367 2a.1.5.5 Containment Spray 249 167 53 1,786 757 3,011 3,011 5,631 346,093 3,734 2a.1.5.6 Extraction Steam & Heater Drip 263 56 318 318 4,152 2a.1.5.7 Feedwater System 46 10 56 56 706 2a.1.5.8 Feedwater System (Insulated) 168 36 204 204 2,655 2a.1.5.9 Feedwater System (RCA Insulated) 126 43 15 506 234 923 923 1,595 98,042 1,811 2a.1.5.10 Feedwater System (RCA) 6 2 1 27 12 48 48 84 5,160 87 2a.1.5.11 Lube Oil Distribution & Purification 115 25 140 140 1,817 2a.1.5.12 Nitrogen & Hydrogen 20 4 24 24 315 2a.1.5.13 Nitrogen & Hydrogen (Insulated) 1 0 1 17 2a.1.5.14 Nitrogen & Hydrogen (RCA Insulated) 6 1 0 5 4 16 16 17 1,040 78 2a.1.5.15 Nitrogen & Hydrogen (RCA) 110 12 3 102 78 305 305 320 19,767 1,478 2a.1.5.16 Oily Water Separator & TB Sump 37 12 5 157 72 282 282 494 30,347 480 2a.1.5.17 Saltwater System 190 41 231 231 2,926 2a.1.5.18 Turbine Steam Supply 759 161 920 920 11,955 2a.1.5.19 Turbine Steam Supply (RCA) 862 335 112 3,799 1,725 6,833 6,833 11,974 736,290 12,374 2a.1.5.20 Turbine and Generator 80 17 98 98 1,244 2a.1.5.21 Turbine and Generator (Insulated) 26 6 32 32 422 2a.1.5 Totals 4,450 633 207 7,034 3,814 16,138 12,770 3,368 22,169 1,363,155 67,355 2a.1.6 Scaffolding in support of decommissioning 2,465 9 5 113 917 3,509 3,509 369 32,791 16,818 2a.1 Subtotal Period 2a Activity Costs 1,546 22,486 24,812 6,604 49,808 567 45,648 151,472 147,048 4,424 129,458 845 574 10,633,590 236,132 6,617 Period 2a Additional Costs 2a.2.1 Retired Reactor Head 225 179 1,557 622 2,583 2,583 5,072 322,442 2,098 750 2a.2 Subtotal Period 2a Additional Costs 225 179 1,557 622 2,583 2,583 5,072 322,442 2,098 750 Period 2a Collateral Costs 2a.3.1 Process decommissioning water waste 84 40 122 163 149 558 558 540 32,379 105 2a.3.2 Process decommissioning chemical flush waste 2a.3.3 Small tool allowance 287 61 348 313 35 2a.3.4 Spent Fuel Transfer - Pool to ISFSI 9,666 2,057 11,723 11,723 2a.3 Subtotal Period 2a Collateral Costs 84 287 40 122 163 9,666 2,267 12,629 871 11,723 35 540 32,379 105 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 5 of 20 Table C-l Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours Period 2a Period-Dependent Costs 2a.4.1 Decon supplies 92 32 124 124 2a.4.2 Insurance 765 109 873 873 2a.4.3 Property taxes 267 38 304 274 30 2a.4.4 Health physics supplies 1,863 661 2,523 2,523 2a.4.5 Heavy equipment rental 3,362 716 4,077 4,077 2a.4.6 Disposal of DAW generated 96 27 305 127 555 555 4,010 82,574 124 2a.4.7 Plant energy hudget 1,770 377 2,146 2,146 2a.4.8 NRC Fees 1,022 145 1,167 1,167 2a.4.9 Emergency Planning Fees 1,152 163 1,315 1,315 2a.4.10 Spent Fuel Pool O&M 1,229 262 1,491 1,491 2a.4.11 ISFSI Operating Costs 72 15 87 87 2a.4.12 Severance Related Costs 3,173 675 3,848 3,848 2a.4.13 Spent Fuel Storage Canisters/Overpacks 20,381 4,338 24,720 24,720 2a.4.14 Security Staff Cost 23,902 5,087 28,989 28,989 369,600 2a.4.15 DOC Staff Cost 26,041 5,543 31,584 31,584 255,360 2a.4.16 Utility Staff Cost 36,803 7,834 44,636 44,636 467,141 2a.4 Suhtotal Period 2a Period-Dependent Costs 92 5,224 96 27 305 116,577 26,122 148,443 120,799 27,613 30 4,010 82,574 124 1,092,101 2a.0 TOTAL PERIOD 2a COST 1,722 27,997 25,173 6,932 51,833 126,809 74,660 315,127 271,302 39,336 4,489 139,080 845 574 11,070,990 238,459 1,099,468 PERIOD 2b - Site Decontamination Period 2h Direct Decommissioning Activities Disposal of Plant Systems 2h. 1. 1.1 Capital Additions 85*2002 (clean) 182 39 220 220 2,830 2h.1.1.2 Capital Additions 85*2002 (contaminated) 485 54 19 635 409 1,603 1,603 2,017 123,100 6,781 2h.1.1.3 Chemical & Volume Control 875 1,229 197 67 2,277 1,907 6,551 6,551 7,273 441,322 27,754 2h. 1. 1.4 Chemical & Volume Control (Insulated) 324 465 50 14 466 570 1,887 1,887 1,463 90,248 10,807 2h.1.1.5 Component Cooling Water 196 42 237 237 3,078 2h.1.1.6 Component Cooling Water (RCA) 617 194 67 2,260 1,063 4,201 4,201 7,126 438,014 8,605 2h.1.1.7 Compressed Air 174 37 211 211 2,744 2h.1.1.8 Compressed Air (Insulated) 6 1 7 7 98 2h.1.1.9 Compressed Air (RCA Insulated) 29 4 1 31 22 87 87 98 6,066 397 2h. 1. 1.10 Compressed Air (RCA) 534 67 18 595 414 1,626 1,626 1,868 115,262 7,278 2h. 1. 1. 11 Diesel Engine-Generator 179 38 217 217 2,760 2h.1.1.12 Diesel Engine-Generator (Insulated) 11 2 14 14 178 2b.1.1.13 Electrical (Clean) 2,130 453 2,584 2,584 32,770 2b. 1. 1.14 Electrical (Contaminated) 633 91 38 1,275 698 2,735 2,735 4,028 247,187 8,649 2b. 1. 1.15 Electrical (Decontaminated) 3,324 708 4,032 4,032 49,541 2b. 1. 1.16 Fire Protection 386 147 54 1,820 815 3,222 3,222 5,929 352,716 5,474 2b. 1. 1.17 Gaseous Radwaste 88 10 3 91 66 258 258 287 17,725 1,175 2b.1.l.18 HVAC (Clean Insulated) 29 6 35 35 475 2b.1.1.19 HVAC (Clean) 372 79 451 451 6,016 2b.1.1.20 HVAC (Contaminated Insulated) 309 55 22 733 382 1,501 1,501 2,315 142,139 4,107 2h.1.1.21 HVAC (Contaminated) 1,372 272 108 3,662 1,848 7,262 7,262 11,560 709,746 18,491 2b.1.1.22 Liquid Radwaste 582 785 116 38 1,283 1,171 3,973 3,973 4,116 248,609 18,831 2b.1.1.23 Liquid Radwaste (Insulated) 69 86 10 3 91 114 372 372 287 17,717 2,114 2b.1.1.24 Make-up Water 360 77 437 437 5,614 2b.1.1.25 Make-up Water (Insulated) 33 7 40 40 521 2h.1.1.26 Make-up Water (RCA Insulated) 44 8 2 81 46 182 182 255 15,691 602 2h.1.1.27 Make-up Water (RCA) 237 46 14 459 256 1,012 1,012 1,443 88,918 3,184 2b.1.1.28 Miscellaneous Reactor Coolant 21 137 17 5 155 121 455 455 491 30,030 2,172 2b.1.1.29 Nuclear Stearn Supply Sampling 182 13 4 141 117 457 457 444 27,315 2,715 2b.1.1.30 Nuclear Stearn Supply Sampling (Insulated 55 2 1 19 27 103 103 58 3,590 826 2b.1.1.31 Residual Heat Removal 319 336 165 55 1,873 1,045 3,793 3,793 5,901 363,036 6,105 2h.1.1.32 Safety Injection 128 22 7 245 137 538 538 784 47,397 1,860 2b.1.1.33 Safety Injection (Insulated) 6 1 0 11 6 24 24 33 2,043 90 2b.1.1.34 Safety Injection (RCA Insulated) 42 9 3 95 50 198 198 299 18,385 564 2b.1.1.35 Safety Injection (RCA) 350 80 25 854 444 1,753 1,753 2,689 165,467 4,712 2b.1.1.36 Service Cooling Water 118 25 143 143 1,856 2b.1.1.37 Service Cooling Water (RCA) 30 7 2 73 38 149 149 228 14,053 411 2b.l.l Totals 2,188 15,679 1,635 567 19,225 13,278 52,572 43,945 8,628 60,992 3,725,778 252,189 2h.1.2 Scaffolding in support of decommissioning 3,081 12 6 141 1,146 4,387 4,387 462 40,989 21,023 TLG Services. Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 6 of 20 Table C-l Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours Decontamination of Site Buildings 2b.1.3.1 *Reactor 958 2,483 1,120 5,645 26,011 12,149 48,366 48,366 331,897 33,045,180 43,301 2b.1.3.2 Capital Additions 85-2004 33 27 7 3 96 69 236 236 317 18,653 847 2b.1.3.3 Containment Penetration Area 327 213 26 28 379 452 1,425 1,425 2,121 172,739 7,351 2b.1.3 Totals 1,318 2,724 1,153 5,677 26,486 12,669 50,027 50,027 334,335 33,236,570 51,499 2b.1 Subtotal Period 2b Activity Costs 3,506 21,484 2,800 6,250 45,852 27,093 106,986 98,358 8,628 395,789 37,003,340 324,711 Period 2b Collateral Costs 2b.3.1 Process decommissioning water waste 133 65 199 266 241 904 904 881 52,880 172 2b.3.2 Process decommissioning chemical flush waste 3 103 420 782 384 1,692 1,692 1,459 155,522 273 2b.3.3 Small tool allowance 408 87 495 495 2b.3.4 Spent Fuel Transfer - Pool to ISFSI 7,355 1,566 8,921 8,921 2b.3 Subtotal Period 2b Collateral Costs 136 408 168 620 1,048 7,355 2,277 12,012 3,091 8,921 2,341 208,402 445 Period 2b Period-Dependent Costs 2b.4.1 Decon supplies 796 283 1,079 1,079 2b.4.2 Insurance 1,138 162 1,300 1,300 2b.4.3 Property taxes 397 56 453 453 2b.4.4 Health physics supplies 2,527 897 3,424 3,424 2b.4.5 Heavy equipment rental 4,962 1,056 6,018 6,018 2b.4.6 Disposal ofDAW generated 104 29 330 138 601 601 4,338 89,346 134 2b.4.7 Plant energy budget 2,079 443 2,522 2,522 2b.4.8 NRC Fees 1,521 216 1,737 1,737 2b.4.9 Emergency Planning Fees 1,714 243 1,957 1,957 2b.4.10 Spent Fuel Pool O&M 1,829 389 2,219 2,219 2b.4.11 Liquid Radwaste Processing Equipment/Services 465 99 563 563 2b.4.12 ISFSI Operating Costs 107 23 130 130 2b.4.13 Severance Related Costs 7,661 1,631 9,291 9,291 2b.4.14 Spent Fuel Storage Canisters/Overpacks 11,034 2,349 13,383 13,383 2b.4.15 Security Staff Cost 35,568 7,571 43,139 43,139 550,000 2b.4.16 DOC Staff Cost 26,233 5,584 31,816 31,816 270,000 2b.4.17 Utility Staff Cost 38,925 8,285 47,210 47,210 502,500 2b.4 Subtotal Period 2b Period-Dependent Costs 796 7,490 104 29 330 128,671 29,422 166,842 149,153 17,689 4,338 89,346 134 1,322,500 2b.0 TOTAL PERIOD 2b COST 4,439 29,382 3,072 6,899 47,230 136,026 58,793 285,840 250,603 26,610 8,628 402,468 37,301,080 325,289 1,322,500 PERIOD 2c - Spent fuel delay prior to SFP decon Period 2c Direct Decommissioning Activities Period 2c Collateral Costs 2c.3.1 Spent Fuel Transfer - Pool to ISFSI 7,990 1,701 9,691 9,691 2c.3 Subtotal Period 2c Collateral Costs 7,990 1,701 9,691 9,691 Period 2c Period-Dependent Costs 2c.4.1 Insurance 3,475 493 3,968 3,968 2c.4.2 Property taxes 1,211 172 1,383 1,383 2c.4.3 Health physics supplies 2,437 864 3,301 3,301 2c.4.4 Disposal ofDAW generated 70 20 220 92 401 401 2,896 59,642 89 2c.4.5 Plant energy budget 1,692 360 2,053 2,053 2c.4.6 NRC Fees 2,671 379 3,050 3,050 2c.4.7 Emergency Planning Fees 5,232 742 5,975 5,975 2c.4.8 Spent Fuel Transfer - Pool or ISFSI to DOE 12,973 2,761 15,735 15,735 2c.4.9 Spent Fuel Pool O&M 5,585 1,189 6,773 6,773 2c.4.10 Liquid Radwaste Processing Equipment/Services 355 75 430 430 2c.4.11 ISFSI Operating Costs 327 70 397 397 2c.4.12 Spent Fuel Storage Canisters/Overpacks 11,985 2,551 14,535 14,535 2c.4.13 Security Staff Cost 108,574 23,110 131,684 131,684 1,678,914 2c.4.14 Utility Staff Cost 8,384 1,785 10,169 10,169 114,471 2c.4 Subtotal Period 2c Period-Dependent Costs 2,437 70 20 220 162,464 34,644 199,853 156,438 43,415 2,896 59,642 89 1,793,386 2c.0 TOTAL PERIOD 2c COST 2,437 70 20 220 170,454 36,344 209,544 156,438 53,106 2,896 59,642 89 1,793,386 TLG Services, Inc.

Diablo Canyon Power Plant Document POI-I648-00I, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 7 of 20 Table C-l Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours PERIOD 2d - Decontamination Following Wet Fuel Storage Period 2d Direct Decommissioning Activities 2d.1.1 Remove spent fuel racks 585 56 174 36 1,207 896 2,954 2,954 3,812 233,945 962 Disposal of Plant Systems 2d.1.2.1 Electrical (Contaminated) - FHB 184 14 6 194 138 536 536 614 37,673 2,491 2d.1.2.2 Electrical (Decontaminated) - FHB 1,165 133 53 1,781 1,075 4,206 4,206 5,623 345,118 15,061 2d.1.2.3 Fire Protection (RCA) 250 50 14 471 266 1,052 1,052 1,481 91,338 3,363 2d.1.2.4 HVAC (Contaminated) - FHB 326 64 25 838 427 1,680 1,680 2,644 162,353 4,383 2d.1.2.5 Spent Fuel Pit Cooling 94 65 21 706 297 1,183 1,183 2,223 136,855 1,433 2d.1.2.6 Spent Fuel Pit Cooling - FHB 130 70 23 764 332 1,319 1,319 2,405 148,051 1,959 2d.1.2 Totals 2,150 396 140 4,754 2,535 9,976 9,976 14,990 921,389 28,690 Decontamination of Site Buildings 2d.1.3.1 Fuel Handling 811 859 63 41 637 1,124 3,534 3,534 3,443 251,129 23,547 2d.1.3 Totals 811 859 63 41 637 1,124 3,534 3,534 3,443 251,129 23,547 2d.1.4 Scaffolding in support of decommissioning 616 2 28 229 877 877 92 8,198 4,205 2d.l Subtotal Period 2d Activity Costs 1,396 3,682 635 218 6,626 4,784 17,342 17,342 22,337 1,414,661 57,404 Period 2d Additional Costs 2d.2.1 License Termination Survey Planning 800 340 1,140 1,140 6,240 2d.2 Subtotal Period 2d Additional Costs 800 340 1,140 1,140 6,240 Period 2d Collateral Costs 2d.3.1 Process decommissioning water waste 34 19 58 77 67 255 255 257 15,400 50 2d.3.2 Process decommissioning chemical flush waste 2d.3.3 Small tool allowance 84 18 101 101 2d.3.4 Decommissioning Equipment Disposition 155 54 1,828 682 2,718 2,718 5,771 354,194 88 2d.3 Subtotal Period 2d Collateral Costs 34 84 174 112 1,905 766 3,075 3,075 6,028 369,594 138 Period 2d Period-Dependent Costs 2d.4.1 Decon supplies 209 74 283 283 2d.4.2 Insurance 219 31 250 250 2d.4.3 Property taxes 76 11 87 87 2dAA Health physics supplies 443 157 600 600 2dA.5 Heavy equipment rental 953 203 1,156 1,156 2dA.6 Disposal of DAW generated 34 9 106 44 194 194 1,397 28,775 43 2dA.7 Plant energy budget 213 45 258 258 2dA.8 NRC Fees 250 35 285 285 2dA.9 Emergency Planning Fees 165 23 188 188 2dA.10 Spent Fuel Transfer - Pool or ISFSI to DOE 690 147 837 837 2dA.11 Liquid Radwaste Processing Equipment/Services 178 38 216 216 2dA.12 ISFSI Operating Costs 21 4 25 25 2dA.13 Severance Related Costs 9,595 2,042 11,637 11,637 2dA.14 Security Staff Cost 1,035 220 1,255 1,255 18,960 2dA.15 DOC Staff Cost 3,363 716 4,078 4,078 35,040 2dA.16 Utility Staff Cost 4,500 958 5,458 5,458 58,080 2d.4 Subtotal Period 2d Period-Dependent Costs 209 1,396 34 9 106 20,304 4,750 26,808 25,757 1,050 1,397 28,775 43 112,080 2d.0 TOTAL PERIOD 2d COST 1,639 5,161 842 339 8,638 21,103 10,641 48,364 47,314 1,050 29,762 1,813,030 57,585 118,320 PERIOD 2f - License Termination Period 2f Direct Decommissioning Activities 2f.1.1 ORISE confirmatory survey 178 76 254 254 2f.1.2 Terminate license a 2f.1 Subtotal Period 2f Activity Costs 178 76 254 254 Period 2f Additional Costs 2f.2.1 License Termination Survey 9,248 3,937 13,184 13,184 126,393 3,120 2f.2 Subtotal Period 2f Additional Costs 9,248 3,937 13,184 13,184 126,393 3,120 TLG Services, Inc.

Diablo Canyon Power Plant Document POJ-J648-00J, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 8 of 20 Table C-l Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activit Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours Period 2f Collateral Costs 2f.3.1 DOC staff relocation expenses 1,415 301 1,716 1,716 2f.3 Subtotal Period 2f Collateral Costs 1,415 301 1,716 1,716 Period 2fPeriod-Dependent Costs 2fA.1 Insurance 319 45 365 365 2fA.2 Property taxes 125 18 142 142 2£.1.3 Health physics supplies 632 224 856 856 2£.1.1 Disposal of DAW generated 9 2 27 11 49 49 356 7,337 11 2£.1.5 Plant energy budget 174 37 211 211 2£.1.6 NRC Fees 462 66 528 528 2fA.7 Emergency Planning Fees 269 38 308 308 2fA.8 Spent Fuel Transfer - Pool or ISFSI to DOE 1,130 241 1,371 1,371 2£.4.9 ISFSI Operating Costs 34 7 41 41 2fA.10 Security Staff Cost 1,694 361 2,055 2,055 31,036 2£.1.11 DOC Staff Cost 4,689 998 5,687 5,687 46,750 2£.4.12 Utility Staff Cost 5,150 1,096 6,246 6,246 60,107 2£.1 Subtotal Period 2£ Period-Dependent Costs 632 9 2 27 14,047 3,142 17,859 16,140 1,719 356 7,337 11 137,893 2f.O TOTAL PERIOD 2fCOST 632 9 2 27 24,887 7,456 33,012 31,293 1,719 356 7,337 126,404 141,013 PERIOD 2 TOTALS 7,800 65,609 29,166 14,192 107,948 479,280 187,894 891,887 756,949 121,822 13,117 574,562 845 574 50,252,080 747,827 4,474,686 PERIOD 3b - Site Restoration Period 3b DiI'ect Decommissioning Activities Demolition of Remaining Site Buildings 3b.LLl *Reactor 6,798 1,447 8,245 8,245 67,914 3b.l.l.2 Capital Additions 85-2004 302 64 366 366 3,572 3b.l.l.3 Containment Penetration Area 686 146 832 832 6,563 3b.l.l.4 Miscellaneous 28 6 34 34 249 3b.l.l.5 Turbine 3,659 779 4,438 4,438 38,603 3b.l.l.6 Turbine Pedestal 1,318 281 1,599 1,599 11,300 3b.l.l.7 Fuel Handling 1,858 395 2,253 2,253 16,750 3b.Ll Totals 14,650 3,118 17,768 17,768 144,951 Site Closeout Activities 3b.l.2 Grade & landscape site 2,758 587 3,345 3,345 4,587 3b.1.3 Final report to NRC 229 49 278 278 1,560 3b.1 Subtotal Period 3b Activity Costs 17,407 229 3,754 21,391 278 21,113 149,538 1,560 Period 3b Additional Costs 3b.2.1 Concrete Crushing 476 0 101 577 577 1,971 3b.2.2 Cofferdam Construction and Teardown 478 102 580 580 4,004 3b.2.3 Soil f Sediment Control Plant Area 1,052 224 1,276 1,276 10,271 3b.2 Subtotal Period 3b Additional Costs 2,006 0 427 2,433 2,433 16,247 Period 3b Collateral Costs 3b.3.1 Small tool allowance 210 45 254 254 3b.3 Subtotal Period 3b Collateral Costs 210 45 254 254 Period 3b Period-Dependent Costs 3bA.1 Insurance 525 74 599 599 3bA.2 Property taxes 410 58 468 468 3bA.3 Heavy equipment rental 7,347 1,564 8,911 8,911 3bAA Plant energy budget 286 61 347 347 3bA.5 NRC ISFSI Fees 348 49 397 397 3bA.6 Emergency Planning Fees 885 126 1,011 1,011 3bA.7 Spent Fuel Transfer - Pool or ISFSI to DOE 3,711 790 4,501 4,501 3b.4.8 ISFSI Operating Costs 111 24 134 134 3bA.9 Security Staff Cost 5,569 1,185 6,754 0 5,471 1,283 102,023 3bA.10 DOC Staff Cost 14,111 3,003 17,114 17,114 136,891 3bA.ll Utility Staff Cost 7,357 1,566 8,923 1,785 7,138 87,197 3bA Subtotal Period 3b Period-Dependent Costs 7,347 33,312 8,501 49,160 0 14,366 34,794 326,112 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning C~st Analysis Appendix C, Page 9 of 20 Table C-l Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index tion Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours 3b.0 TOTAL PERIOD 3b COST 26,970 33,542 12,726 73,238 278 14,366 58,594 165,784 327,672 PERIOD 3c - Fuel Storage Operations/Shipping Period 3c Direct Decommissioning Activities Period 3c Period*Dependent Costs 3c.4.1 Insurance 3,099 440 3,539 3,539 3c.4.2 Property taxes 2,420 343 2,764 2,764 3e.4.3 Plant energy budget 3c.4.4 NRC ISFSI Fees 2,054 292 2,346 2,346 3e.4.5 Emergency Planning Fees 5,228 742 5,970 5,970 3e.4.6 Spent Fuel Transfer* Pool or ISFSI to DOE 21,995 4,682 26,676 26,676 3c.4.7 ISFSI Operating Costs 654 139 793 793 3c.4.8 Security Staff Cost 26,771 5,698 32,469 32,469 411,789 3c.4.9 Utility Staff Cost 8,802 1,874 10,676 10,676 103,100 3c.4 Subtotal Period 3c Period* Dependent Costs 71,024 14,209 85,233 85,233 514,888 3c.0 TOTAL PERIOD 3c COST 71,024 14,209 85,233 85,233 514,888 PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d. 1.1.1 Vessel & Internals GTCC Disposal 2,500 9,179 2,309 13,988 13,988 1,785 350,510 3d.l.l Totals 2,500 9,179 2,309 13,988 13,988 1,785 350,510 3d.l Subtotal Period 3d Activity Costs 2,500 9,179 2,309 13,988 13,988 1,785 350,510 Period 3d Collateral Costs 3d.3 Subtotal Period 3d Collateral Costs Period 3d Period-Dependent Costs 3d.4.1 Insurance 10 11 11 3dA.2 Property taxes 8 9 9 3dA.3 Plant energy budget 3dA.4 NRC ISFSI Fees 6 1 7 7 3dA.5 ISFSI Operating Costs 2 0 3 3 3dA.6 Security Staff Cost 85 18 103 103 1,311 3d.4.7 Utility Staff Cost 28 6 34 34 328 3dA Subtotal Period 3d Period-Dependent Costs 139 28 167 167 1,640 3d.0 TOTAL PERIOD 3d COST 2,500 9,179 139 2,336 14,155 13,988 167 1,785 350,510 1,640 PERIOD 3e - ISFSI Decontamination Period 3e Direet Decommissioning Activities Period 3e Additional Costs 3e.2.1 ISFSI License Termination 40 6 14 393 622 290 1,365 1,365 1,305 108,721 4,535 360 3e.2 Subtotal Period 3e Additional Costs 40 6 14 393 622 290 1,365 1,365 1,305 108,721 4,535 360 Period 3e Collateral Costs 3e.3.1 Small tool allowance 0 3e.3 Subtotal Period 3e Collateral Costs 0 Period 3e Period-Dependent Costs 3e.4.1 Insurance 3eA.2 Property taxes 55 8 63 63 3e.4.3 Heavy equipment rental 136 29 165 165 3e.4.4 Plant energy budget 3eA.5 NRC ISFSI Fees 94 13 107 107 3e.4.6 Security Staff Cost 61 13 74 74 1,901 3eA.7 Utility Staff Cost 163 35 198 198 1,901 3e.4 Subtotal Period 3e Period*Dependent Costs 136 373 98 607 607 3,803 3e.0 TOTAL PERIOD 3e COST 177 6 14 393 995 388 1,973 1,973 1,305 108,721 4,535 4,163 TLG Services, Inc.

Diablo Canyon Power Plant Document P01-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 10 of 20 Table C-l Diablo Canyon Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume -C:::::-Ia-s-s-:A:----:C::CI:=-a.::ss::.:::B::......:...::::C:::I:::as:.::s:::.C-:::---:G"'T=C:::-::C,--- Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lhs. Manhours Manhours PERIOD 3f - ISFSI Site Restoration Period 3fDirect Decommissioning Activities Period 3f Additional Costs 3f.2.1 ISFSI Demolition and Site Restoration 1,371 27 297 1,695 1,695 15,387 80 3f.2.2 ISFSI Area Soil! Sediment Control 16 4 20 20 2,568 3f.2 Subtotal Period 3f Additional Costs 1,387 27 301 1,715 1,715 17,955 80 Period 3f Collateral Costs 3f.3.1 Small tool allowance 20 4 24 24 3f.3 Subtotal Period 3£ Collateral Costs 20 4 24 24 Period 3fPeriod-Dependent Costs 3f.4.1 Insurance 3f.4.2 Property taxes 28 4 32 32 3f.4.3 Heavy equipment rental 54 11 65 65 3f.4.4 Plant energy budget 3f.4.5 Security Staff Cost 11 2 14 14 349 3f.4.6 Utility Staff Cost 69 15 83 83 784 3£.4 Subtotal Period 3fPeriod-Dependent Costs 54 108 32 193 193 1,133 3£.0 TOTAL PERIOD 3f COST 1,461 134 338 1,932 1,932 17,955 1,213 PERIOD 3 TOTALS 28,607 2,506 14 9,572 105,834 29,997 176,531 14,266 103,672 58,594 1,305 1,785 459,231 188,274 849,575 TOTAL COST TO DECOMMISSION 11,057 96,791 32,014 14,632 127,040 776,395 264,540 1,322,468 999,926 248,912 73,630 587,422 1,732 574 1,785 51,454,030 962,738 6,481,355 TOTAL COST TO DECOMMISSION WITH 25.01% CONTINGENCY: $1,322,468 thousands of 2011 dollars TOTAL NRC LICENSE TERMINATION COST IS 75.61% OR: $999,926 thousands of 2011 dollars SPENT FUEL MANAGEMENT COST IS 18.82% OR: $248,912 thousands of 2011 dollars NON-NUCLEAR DEMOLITION COST IS 5.57% OR: $73,630 thousands of 2011 dollars TOTAL SCRAP METAL REMOVED: 49,854 Tons TOTAL CRAFT LABOR REQUIREMENTS: 962,738 Man-hours EndNotes:

nla - indicates that this activity not charged as decommissioning expense.

a - indicates that this activity performed by decommissioning staff.

o - indicates that this value is less than 0.5 but is non-zero.

a cell containing" - " indicates a zero value TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 11 of 20 Table C-2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours PERIOD Ia - Shutdown through Transition Period Ia Direct Decommissioning Activities 1a.1.1 Prepare preliminary decommissioning cost 82 17 99 99 556 la.1.2 Notification of Cessation of Operations a 1a.1.3 Remove fuel & source material nla 1a.1.4 Notification of Permanent Defueling a 1a.1.5 Deactivate plant systems & process waste a 1a.1.6 Prepare and submit PSDAR 126 26 152 152 856 1a.1.7 Review plant dwgs & specs. 289 61 350 350 1,969 1a.1.8 Perform detailed rad survey a la.1.9 Estimate by-product inventory 63 13 76 76 428 1a.l.10 End product description 63 13 76 76 428 1a.1.11 Detailed by-product inventory 82 17 99 99 556 1a.1.12 Define major work sequence 472 99 571 571 3,210 1a.1.13 Perform SER and EA 195 41 236 236 1,327 1a.1.14 Perform Site-Specific Cost Study 315 66 381 381 2,140 1a.1.15 Prepare/submit License Termination Plan 258 54 312 312 1,753 1a.1.16 Receive NRC approval of termination plan a Activity Specifications 1a.1.17.1 Plant & temporal'y facilities 310 65 375 337 37 2,106 1a.1.17.2 Plant systems 262 55 317 286 32 1,783 1a.1.17.3 NSSS Decontamination Flush 31 7 38 38 214 1a.1.17.4 Reactor internals 447 94 541 541 3,039 1a.1.17.5 Reactor vessel 409 86 495 495 2,782 la.1.17.6 Biological shield 31 7 38 38 214 1a.1.17.7 Steam generators 196 41 238 238 1,335 1a.1.17.8 Reinforced concrete 101 21 122 61 61 685 1a.1.17.9 Main Turbine 25 5 30 30 171 la.1.17.10 Main Condensers 25 5 30 30 171 1a.1.17.11 Plant structures & buildings 196 41 238 119 119 1,335 1a.1.17.12 Waste management 289 61 350 350 1,969 1a.1.17.13 Facility & site closeout 57 12 69 34 34 385 1a.1.17 Total 2,380 500 2,880 2,536 344 16,190 Planning & Site Preparations 1a.U8 Prepare dismantling sequence 151 32 183 183 1,027 1a.l.19 Plant prep. & temp. svces 2,800 589 3,389 3,389 1a.l.20 Design water clean-up system 88 19 107 107 599 1a.l.21 Rigging/Cant. Cntrl Envlps/tooling/etc. 2,200 463 2,663 2,663 1a.l.22 Procure caskslliners & containers 77 16 94 94 526 1a.1 Subtotal Period 1a Activity Costs 9,640 2,027 11,668 11,323 344 31,566 Period la Additional Costs 1a.2.1 Spent Fuel Pool Isolation 13,217 2,779 15,996 15,996 1a.2.2 Disposal of Contaminated Tools & Equipment 234 97 3,145 1,156 4,632 4,632 10,245 609,715 317 la.2 Subtotal Period 1a Additional Costs 234 97 3,145 13,217 3,935 20,628 20,628 10,245 609,715 317 Period 1a Period-Dependent Costs 1a.4.1 Insurance 1,056 148 1,204 1,204 1a.4.2 Property taxes 165 23 189 189 1a.4.3 Health physics supplies 457 160 617 617 la.4.4 Heavy equipment rental 480 101 580 580 1a.4.5 Disposal ofDAW generated 14 4 45 19 83 83 598 12,310 18 1a.4.6 Plant energy budget 1,156 243 1,399 1,399 1aA.7 NRC Fees 838 117 955 955 la.4.8 Emergency Planning Fees 1,001 140 1,142 1,142 la.4.9 Spent Fuel Pool O&M 763 160 924 924 la.4.10 ISFSI Operating Costs 45 9 54 54 la.4.11 Severance Related Costs 38,503 8,097 46,600 46,600 1a.4.12 Spent Fuel Storage Canisters/Overpacks 5,714 1.202 6,916 6,916 1a.4.13 Security Staff Cost 14,837 3,120 17,957 17,957 229,429 la.4.14 Utility Staff Cost 26,317 5,534 31,851 31,851 346,229 la.4 Subtotal Period 1a Period-Dependent Costs 936 14 4 45 90,395 19.075 110,470 101,435 9,035 598 12,310 18 575,657 TLG Services, Inc_

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 12 of 20 Table C-2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours 1a.0 TOTAL PERIOD 1a COST 936 248 101 3,190 113,252 25,038 142,766 133,387 9,035 344 10,843 622,025 336 607,223 PERIOD Ib - Decommissioning Preparations Period 1b Direct Decommissioning Activities Detailed Work Procedures 1b.l.1.1 Plant systems 298 63 360 324 36 2,026 lb. 1. 1.2 NSSS Decontamination Flush 63 13 76 76 428 lb. 1. 1.3 Reactor internals 157 33 190 190 1,070 lb. 1. 1.4 Remaining buildings 85 18 103 26 77 578 1b.1.1.5 CRD cooling assembly 63 13 76 76 428 1b.1.1.6 CRD housings & ICI tubes 63 13 76 76 428 1b.l.l. 7 Incore instrumentation 63 13 76 76 428 lb. 1. 1.8 Reactor vessel 228 48 *276 276 1,554 1b.1.1.9 Facility closeout 75 16 91 46 46 514 lb. l. 1.10 Missile shields 28 6 34 34 193 Ib.1.1.11 Biological shield 75 16 91 91 514 1b.1.1.12 Steam generators 289 61 350 350 1,969 1b.1.1.13 Reinforced concrete 63 13 76 38 38 428 1b.1.1.14 Main Turbine 98 21 119 119 668 lb. l. 1.15 Main Condensers 98 21 119 119 668 lb. 1. 1.16 Auxiliary building 172 36 208 187 21 1,168 lb. 1. 1.17 Reactor building 172 36 208 187 21 1,168 1b.1.l Total 2,092 440 2,531 2,055 476 14,228 1b.1.2 Decon primary loop 750 526 1,276 1,276 1,067 1b.1 Subtotal Period 1b Activity Costs 750 2,092 966 3,808 3,332 476 1,067 14,228 Period 1b Additional Costs 1b.2.1 Site Characterization 2,038 857 2,895 2,895 10,690 4,024 1b.2.2 Hazardous Waste Management 204 43 247 247 1b.2.3 Mixed Waste Management 270 57 327 327 1b.2 Subtotal Period 1b Additional Costs 2,512 957 3,468 3,468 10,690 4,024 Period 1b Collateral Costs 1b.3.1 Decon equipment 931 196 1,126 1,126 1b.3.2 DOC staff relocation expenses 1,415 297 1,712 1,712 1b.3.3 Process decommissioning water waste 46 21 66 88 80 301 301 291 17,471 57 1b.3A Process decommissioning chemical flush waste 2 63 256 6,210 2,240 8,770 8,770 887 94,531 166 1b.3.5 Small tool allowance 3 1 3 3 1b.3.6 Pipe cutting equipment 1,100 231 1,331 1,331 1b.3.7 Decon rig 1,500 315 1,815 1,815 1b.3 Subtotal Period Ib Collateral Costs 2,479 1,103 84 321 6,298 1,415 3,361 15,060 15,060 291 887 112,002 223 Period 1b Period* Dependent Costs 1bA.1 Decon supplies 28 10 38 38 1b.4.2 Insurance 523 73 597 597 IbA.3 Property taxes 82 12 94 94 1b.4A Health physics supplies 249 87 336 336 IbA.5 Heavy equipment rental 238 50 288 288 IbA.6 Disposal ofDAW generated 8 2 26 11 47 47 341 7,016 11 1bA.7 Plant energy budget 1,147 241 1,388 1,388 1bA.8 NRC Fees 237 33 270 270 Ib.4.9 Emergency Planning Fees 497 70 566 566 IbA.I0 Spent Fuel Pool O&M 378 80 458 458 IbA.ll ISFSI Operating Costs 22 5 27 27 1b.4.12 Severance Related Costs 2,018 424 2,442 2,442 IbA.13 Spent Fuel Storage Canisters/Overpacks 3,086 649 3,735 3,735 1b.4.14 Security Staff Cost 7,357 1,547 8,905 8,905 113,771 1bA.15 DOC Staff Cost 4,664 981 5,645 5,645 46,543 1b.4.16 Utility Staff Cost 13,050 2,744 15,795 15,795 171,691 1b.4 Subtotal Period 1b Period*Dependent Costs 28 487 8 2 26 33,062 7,017 40,630 35,844 4,786 341 7,016 11 332,006 1b.0 TOTAL PERIOD Ib COST 3,257 1,589 92 324 6,323 39,080 12,300 62,965 57,703 4,786 476 632 887 119,017 11,990 350,258 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 13 of 20 Table C-2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours PERIOD 1 TOTALS 3,257 2,525 341 425 9,514 152,332 37,338 205,731 191,090 13,821 820 11,475 887 741,042 12,325 957,482 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.l Reactor Coolant Piping 370 354 52 40 1,342 869 3,027 3,027 2,276 260,153 10,138 2a.1.1.2 Pressurizer Quench Tank 39 35 8 6 189 108 385 385 329 36,557 1,073 2a.1.1.3 Reactor Coolant Pumps & Motors 118 126 103 185 1,443 686 2,661 2,661 4,701 774,960 4,185 100 2a.1.1.4 Pressurizer 50 70 448 114 750 409 1,841 1,841 2,443 286,592 2,365 938 2a.1.1.5 Steam Generators 477 4,206 3,368 1,922 12,807 7,173 29,952 29,952 41,712 3,350,761 27,047 1,750 2a.1.1.6 Retired Steam Generator Units 2,496 1,878 12,597 5,160 22,131 22,131 41,031 3,125,629 14,613 1,125 2a.1.1.7 CRDMsllCIs/Service Structure Removal 196 112 262 37 444 377 1,428 1,428 3,881 86,025 4,285 2a.1.1.8 Reactor Vessel Internals 163 3,064 14,919 1,413 10,366 278 16,385 46,588 46,588 1,502 845 574 352,188 29,833 1,325 2a.L1.9 Reactor Vessel 122 5,180 2,387 742 2,651 278 8,545 19,905 19,905 8,794 957,382 29,833 1,325 2a.1.1 Totals 1,534 13,148 24,042 6,336 42,589 556 39,714 127,919 127,919 106,670 845 574 9,230,247 123,373 6,564 Removal of Major Equipment 2a.1.2 Main Turbine/Generator 202 43 245 245 3,033 2a.1.3 Main Condensers 668 141 809 809 9,875 Cascading Costs from Clean Building Demolition 2a.L4.1 *Reactor 1,194 251 1,445 1,445 11,895 2a.L4.2 Auxiliary 719 151 870 870 7,054 2a.1.4.3 Containment Penetration Area 73 15 89 89 704 2a.L4.4 Radwaste Storage 91 19 110 110 918 2a.1.4.5 Fuel Handling 193 41 234 234 1,746 2a.1.4 Totals 2,270 477 2,747 2,747 22,317 Disposal of Plant Systems 2a.1.5.1 Auxiliary Steam 76 16 92 92 1,179 2a.1.5.2 Auxiliary Steam (RCA) 141 32 9 319 168 670 670 1,004 61,868 1,935 2a.1.5.3 Building Services (Non-Power Block) 7 1 8 8 106 2a.1.5.4 Condensate System 619 130 749 749 9,716 2a.1.5.5 Condensate System (Insulated) 274 58 332 332 4,253 2a.1.5.6 Containment Spray 235 161 51 1,719 718 2,885 2,885 5,421 333,235 3,521 2a.1.5.7 Extraction Steam & Heater Drip 230 48 279 279 3,625 2a.1.5.8 Feedwater System 67 14 82 82 1,038 2a.1.5.9 Feedwater System (Insulated) 162 34 196 196 2,547 2a.1.5.10 Feedwater System (RCA Insulated) 119 42 15 497 225 897 897 1,567 96,264 1,710 2a.L5.11 Feedwater System (RCA) 6 2 1 26 12 46 46 82 5,067 82 2a.1.5.12 NSSS Sampling 159 9 3 100 93 364 364 315 19,386 2,404 2a.1.5.13 NSSS Sampling (Insulated) 47 1 0 10 20 78 78 31 1,903 712 2a.1.5.14 Nitrogen & Hydrogen 19 4 23 23 309 2a.1.5.15 Nitrogen & Hydrogen (Insulated) 1 0 1 1 16 2a.1.5.16 Nitrogen & Hydrogen (RCA Insulated) 5 0 5 4 15 15 15 937 74 2a.1.5.17 Nitrogen & Hydrogen (RCA) 103 11 3 92 71 280 280 288 17,804 1,405 2a.1.5.18 Oily Water Separator & TB Sump 29 11 3 102 48 192 192 319 19,671 410 2a.1.5.19 Saltwater System 181 38 219 219 2,779 2a.1.5.20 Turbine Steam Supply 762 160 922 922 12,007 2a.1.5.21 Turbine Steam Supply (RCA) 878 345 117 3,961 1,769 7,070 7,070 12,485 767,598 12,605 2a.1.5.22 Turbine and Generator 81 17 98 98 1,250 2a.1.5.23 Turbine and Generator (Insulated) 24 5 29 29 378 2a.1.5 Totals 4,226 614 201 6,830 3,653 15,525 12,496 3,029 21,528 1,323,732 64,060 2a.1.6 Scaffolding in support of decommissioning 4,785 21 11 251 1,770 6,838 6,838 818 72,662 35,763 2a.1 Subtotal Period 2a Activity Costs 1,534 25,300 24,677 6,548 49,671 556 45,798 154,083 150,001 4,082 129,016 845 574 10,626,640 258,421 6,564 Period 2a Additional Costs 2a.2.1 Retired Reactor Head 225 179 1,557 615 2,576 2,576 5,072 322,442 2,098 750 2a.2 Subtotal Period 2a Additional Costs 225 179 1,557 615 2,576 2,576 5,072 322,442 2,098 750 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 14 of 20 Table C-2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activit Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours Period 2a Collateral Costs 2a.3.1 Process decommissioning water waste 85 40 123 165 149 562 562 545 32,727 106 2a.3.2 Process decommissioning chemical flush waste 2a.3.3 Small tool allowance 315 66 381 343 38 2a.3.4 Spent Fuel Transfer - Pool to ISFSI 2,279 479 2,758 2,758 2a.3 Subtotal Period 2a Collateral Costs 85 315 40 123 165 2,279 694 3,701 905 2,758 38 545 32,727 106 Period 2a Period-Dependent Costs 2aA.1 Decon supplies 92 32 124 124 2aA.2 Insurance 768 108 875 875 2aA.3 Property taxes 268 38 305 275 31 2aA.4 Health physics supplies 1,968 690 2,658 2,658 2aA.5 Heavy equipment rental 3,373 709 4,082 4,082 2aA.6 Disposal ofDAW generated 110 31 349 144 635 635 4,593 94,597 142 2aA.7 Plant energy budget 1,776 373 2,149 2,149 2aA.8 NRC Fees 724 102 826 826 2aA.9 Emergency Planning Fees 1,156 162 1,318 1,318 2aA.10 Spent Fuel Pool O&M 1,234 259 1,493 1,493 2aA.ll ISFSI Operating Costs 72 15 88 88 2aA.12 Severance Related Costs 494 104 598 598 2aA.13 Spent Fuel Storage Canisters/Overpacks 3,418 719 4,137 4,137 2aA.14 Security Staff Cost 23,983 5,044 29,027 29,027 370,857 2aA.15 DOC Staff Cost 26,130 5,495 31,625 31,625 256,229 2aA.16 Utility Staff Cost 37,794 7,948 45,742 45,742 477,057 2aA Subtotal Period 2a Period-Dependent Costs 92 5,341 110 31 349 97,815 21,942 125,681 118,615 7,035 31 4,593 94,597 142 1,104,143 2a.0 TOTAL PERIOD 2a COST 1,711 30,956 25,052 6,881 51,741 100,650 69,049 286,040 272,096 9,793 4,151 139,227 845 574 11,076,410 260,767 1,111,457 PERIOD 2b - Site Decontamination Period 2b Direct Decommissioning Activities Disposal of Plant Systems 2b. 1. 1.1 Capital Additions 85-2002 (Clean) 450 95 544 544 7,040 2b. 1. 1.2 Capital Additions 85-2002 (contaminated) 483 61 24 797 462 1,827 1,827 2,532 154,520 6,606 2b.1.1.3 Chemical & Volume Control 809 1,066 172 58 1,966 1,666 5,736 5,736 6,290 380,935 24,738 2b. 1. 1.4 Chemical & Volume Control (Insulated) 294 432 47 13 438 520 1,744 1,744 1,376 84,904 9,960 2b.L1.5 Component Cooling Water 190 40 230 230 2,984 2h.LL6 Component Cooling Water (RCA) 595 191 66 2,245 1,036 4,133 4,133 7,077 435,000 8,301 2h.L1.7 Compressed Air 118 25 143 143 1,881 2h.L1.8 Compressed Air (Insulated) 6 1 8 8 99 2h.L1.9 Compressed Air (RCA Insulated) 29 4 1 33 23 89 89 104 6,415 404 2h.L1.10 Compressed Air (RCA) 531 69 19 629 420 1,667 1,667 1,976 121,884 7,315 2h.Ll.11 Diesel Engine-Generator 137 29 165 165 2,089 2h.L1.l2 Diesel Engine-Generator (Insulated) 3 1 4 4 48 2h.1.1.13 Electrical (Clean) 3,115 655 3,770 3,770 47,918 2h.L1.l4 Electrical (Contaminated) 360 44 18 613 351 1,386 1,386 1,936 118,833 4,901 2h.L1.15 Electrical (RCA) 1,875 394 2,269 2,269 27,955 2h.1.1.16 Fire Protection 364 148 53 1,792 788 3,145 3,145 5,838 347,206 5,173 2h.L1.l7 Gaseous Radwaste 133 20 6 217 127 502 502 690 41,995 1,842 2h. 1. 1.18 HVAC (Clean Insulated) 40 8 48 48 662 2h.L1.l9 HVAC (Clean) 428 90 518 518 7,019 2h. 1. 1.20 HVAC (Contaminated Insulated) 232 37 15 506 267 1,057 1,057 1,598 98,113 3,075 2h.l.l.21 HVAC (Contaminated) 1,033 185 76 2,563 1,302 5,159 5,159 8,091 496,626 13,890 2b.1.1.22 Liquid Radwaste 362 447 74 25 862 728 2,498 2,498 2,791 166,964 11,333 2b.1.1.23 Liquid Radwaste (Insulated) 29 44 5 45 53 177 177 142 8,780 1,007 2h. 1. 1.24 Luhe Oil Distribution & Purification 126 26 152 152 1,964 2h. 1. 1.25 Make-up Water 244 51 296 296 3,794 2h.1.1.26 Make-up Water (Insulated) 24 5 29 29 376 2h. 1. 1.27 Make-up Water (RCA Insulated) 32 7 2 67 36 144 144 210 12,938 448 2h.L1.28 Make-up Water (RCA) 164 39 11 378 198 790 790 1,190 73,314 2,245 2h. 1. 1.29 Mechanical Department Equipment 1 0 1 19 2h.1.1.30 Miscellaneous Reactor Coolant 21 141 17 5 158 123 464 464 500 30,589 2,240 2b.1.1.31 Nuclear Steam Supply Sampling 21 2 1 21 15 61 61 66 4,072 282 2b.1.1.32 Nuclear Steam Supply Sampling (Insulated 2b.1.1.33 Residual Heat Removal 307 9

305 1

162 ° 54 9

1,845 7

1,003 26 3,675 26 3,675 28 5,811 1,745 357,510 121 5,524 2b.L1.34 Safety Injection 124 21 7 242 133 527 527 776 46,891 1,799 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 15 of 20 Table C-2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index tion Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours Disposal of Plant Systems (continued) 2h. 1. 1.35 Safety Injection (Insulated) 5 1 0 10 6 23 23 32 1,987 76 2h. 1. 1.36 Safety Injection (RCAlnsulated) 38 8 3 92 48 189 189 291 17,880 522 2h.1.1.37 Safety Injection (RCA) 322 76 24 830 420 1,672 1,672 2,616 160,916 4,326 2h. 1. 1.38 Service Cooling Water 138 29 167 167 2,186 2h.L1.39 Service Cooling Water (RCA) 37 9 3 96 49 195 195 303 18,679 513 2h.1.1.40 Sewer System Expansion 47 10 57 57 746 2h.1.l Totals 1,821 13,893 1,400 485 16,454 11,238 45,291 36,887 8,403 52,266 3,188,694 223,417 2h.1.2 Scaffolding in support of decommissioning 5,982 26 14 313 2,213 8,548 8,548 1,023 90,828 44,703 Decontamination of Site Buildings 2h.1.3.1 *Reactor 959 2,483 1,120 5,645 26,011 12,003 48,221 48,221 331,897 33,045,180 43,302 2h.1.3.2 Auxiliary 1,325 739 65 98 927 1,542 4,695 4,695 6,943 585,598 28,092 2h.1.3.3 Capital Additions 85*2004 423 168 10 20 151 414 1,187 1,187 1,331 117,734 8,113 2h.1.3.4 Containment Penetration Area 327 213 26 28 379 446 1,420 1,420 2,121 172,739 7,351 2h.1.3.5 Radwaste Storage 8 62 4 9 59 51 194 194 627 55,654 867 2h.L3 Totals 3,042 3,666 1,224 5,801 27,526 14,457 55,716 55,716 342,918 33,976,900 87,726 2h.1 Suhtotal Period 2b Activity Costs 4,863 23,541 2,650 6,300 44,293 27,908 109,554 101,151 8,403 396,208 37,256,420 355,847 Period 2b Collateral Costs 2h.3.1 Process decommissioning water waste 143 69 213 284 254 964 964 942 56,542 184 2h.3.2 Process decommissioning chemical flush waste 3 90 369 687 333 1,482 1,482 1,281 136,538 240 2b.3.3 Small tool allowance 445 94 539 539 2b.3.4 Spent Fuel Transfer - Pool to 1SFS1 7,172 1,508 8,681 8,681 2h.3 Subtotal Period 2b Collateral Costs 145 445 160 582 971 7,172 2,189 11,665 2,985 8,681 2,224 193,081 424 Period 2b Period-Dependent Costs 2hA.1 Decon supplies 1,456 510 1,966 1,966 2hA.2 Insurance 1,136 159 1,295 1,295 2hA.3 Property taxes 396 55 451 451 2h.4.4 Health physics supplies 2,764 969 3,733 3,733 2bA.5 Heavy equipment rental 4,951 1,041 5,992 5,992 2b.4.6 Disposal of DAW generated 127 36 401 166 730 730 5,286 108,867 163 2h.4.7 Plant energy budget 2,074 436 2,510 2,510 2bA.8 NRC Fees 1,072 150 1,222 1,222 2bA.9 Emergency Planning Fees 1,710 240 1,950 1,950 2h.4.10 Spent Fuel Pool O&M 1,825 384 2,209 2,209 2bA.ll Liquid Radwaste Processing Equipment/Services 463 97 561 561 2bA.12 ISFSI Operating Costs 107 22 129 129 2bA.13 Severance Related Costs 7,908 1,663 9,571 9,571 2b.4.14 Spent Fuel Storage Canisters/Overpacks 10,760 2,263 13,023 13,023 2bA.15 Security Staff Cost 35,487 7,463 42,950 42,950 548,743 2bA.16 DOC Staff Cost 37,206 7,824 45,030 45,030 364,166 2bA.17 Utility Staff Cost 53,628 11,278 64,905 64,905 675,951 2bA Subtotal Period 2b Period-Dependent Costs 1,456 7,715 127 36 401 153,771 34,722 198,227 180,916 17,311 5,286 108,867 163 1,588,860 2b.0 TOTAL PERIOD 2b COST 6,464 31,701 2,936 6,918 45,666 160,943 64,819 319,447 285,051 25,992 8,403 403,718 37,558,370 356,433 1,588,860 PERIOD 2c - Spent fuel delay prior to SFP decon Period 2c Direct Decommissioning Activities Period 2c Collateral Costs 2c.3.1 Spent Fuel Transfer - Pool to ISFSl 7,549 1,588 9,137 9,137 2c.3 Subtotal Period 2c Collateral Costs 7,549 1,588 9,137 9,137 Period 2c Period-Dependent Costs 2c.4.1 Insurance 3,088 433 3,521 3,521 2c.4.2 Property taxes 1,076 151 1,227 1,227 2cA.3 Health physics supplies 2,326 815 3,142 3,142 2cA,4 Disposal of DAW generated 68 19 216 89 392 392 2,839 58,472 88 2cA.5 Plant energy budget 1,504 316 1,820 1,820 2cA.6 NRC Fees 2,000 280 2,281 2,281 2cA.7 Emergency Planning Fees 4,651 652 5,303 5,303 2cA.8 Spent Fuel Transfer - Pool or ISFSI to DOE 13,947 2,933 16,880 16,880 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 16 of 20 Table C-2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial f Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours Period 2c Period*Dependent Costs (continued) 2c.4.9 Spent Fuel Pool O&M 4,964 1,044 6,007 6,007 2c.4.10 Liquid Radwaste Processing Equipment/Services 315 66 381 381 2c.4.11 ISFSI Operating Costs 291 61 352 352 2c.4.12 Spent Fuel Storage Canisters/Overpacks 11,323 2,381 13,704 13,704 2c.4.13 Security Staff Cost 96,501 20,294 116,795 116,795 1,492,229 2c.4.14 Utility Staff Cost 42,556 8,950 51,506 51,506 535,846 2c.4 Subtotal Period 2c Period* Dependent Costs 2,326 68 19 216 182,217 38,467 223,313 181,066 42,246 2,839 58,472 88 2,028,074 2c.O TOTAL PERIOD 2c COST 2,326 68 19 216 189,766 40,054 232,449 181,066 51,383 2,839 58,472 88 2,028,074 PERIOD 2d - Decontamination Following Wet Fuel Storage Period 2d Direct Decommissioning Activities 2d.1.l Remove spent fuel racks 585 56 174 36 1,207 885 2,943 2,943 3,812 233,945 962 Disposal of Plant Systems 2d.1.2.1 Electrical (Contaminated) - FHB 111 8 3 115 81 317 317 362 22,201 1,497 2d.L2.2 Electrical (RCA).FHB 690 78 31 1,042 624 2,464 2,464 3,290 201,925 8,926 2d.L2.3 Fire Protection (RCA) 264 67 18 613 321 1,283 1,283 1,925 118,758 3,614 2d.L2.4 HVAC (Contaminated) - FHB 231 39 16 542 280 1,107 1,107 1,711 104,999 3,086 2d.L2.5 Spent Fuel Pit Cooling 94 65 21 712 296 1,189 1,189 2,243 138,063 1,442 2d.L2.6 Spent Fuel Pit Cooling* FHB 130 71 23 772 331 1,327 1,327 2,430 149,602 1,956 2d.L2 Totals 1,520 328 112 3,795 1,933 7,688 7,688 11,961 735,547 20,523 Decontamination of Site Buildings 2d.L3.1 Fuel Handling 811 859 63 41 637 1,110 3,521 3,521 3,443 251,129 23,547 2d.L3 Totals 811 859 63 41 637 1,110 3,521 3,521 3,443 251,129 23,547 2d.L4 Scaffolding in support of decommissioning 1,196 5 3 63 443 1,710 1,710 205 18,166 8,941 2d.1 Subtotal Period 2d Activity Costs 1,396 3,632 570 191 5,702 4,370 15,862 15,862 19,420 1,238,787 53,973 Period 2d Additional Costs 2d.2.1 License Termination Survey Planning 800 336 1,136 1,136 6,240 2d.2 Subtotal Period 2d Additional Costs 800 336 1,136 1,136 6,240 Period 2d Collateral Costs 2d.3.1 Process decommissioning water waste 37 20 62 82 70 271 271 272 16,319 53 2d.3.2 Process decommissioning chemical flush waste 2d.3.3 Small tool allowance 79 17 96 96 2d.3.4 Decommissioning Equipment Disposition 155 54 1,828 674 2,710 2,710 5,771 354,194 88 2d.3 Subtotal Period 2d Collateral Costs 37 79 175 115 1,910 760 3,076 3,076 6,043 370,513 141 Period 2d Period-Dependent Costs 2d.4.1 Decon supplies 209 73 282 282 2d.4.2 Insurance 219 31 249 249 2d.4.3 Property taxes 76 11 87 87 2d.4.4 Health physics supplies 445 156 601 601 2d.4.5 Heavy equipment rental 953 200 1,153 1,153 2d.4.6 Disposal of DAW generated 45 13 143 59 260 260 1,885 38,817 58 2d.4.7 Plant energy budget 213 45 258 258 2d.4.8 NRC Fees 175 24 199 199 2d.4.9 Emergency Planning Fees 165 23 188 188 2d.4.10 Spent Fuel Transfer - Pool or ISFSI to DOE 1,216 256 1,472 1,472 2d.4.11 Liquid Radwaste Processing Equipment/Services 178 38 216 216 2d.4.12 ISFSI Operating Costs 21 4 25 25 2d.4.13 Severance Related Costs 12,313 2,589 14,902 14,902 2d.4.14 Security Staff Cost 1,035 218 1,253 1,253 18,960 2d.4.15 DOC Staff Cost 4,884 1,027 5,911 5,911 48,000 2d.4.16 Utility Staff Cost 7,532 1,584 9,117 9,117 91,680 2d.4 Subtotal Period 2d Period-Dependent Costs 209 1,398 45 13 143 28,027 6,338 36,173 34,488 1,685 1,885 38,817 58 158,640 2d.0 TOTAL PERIOD 2d COST 1,642 5,108 790 319 7,755 28,826 11,805 56,246 54,561 1,685 27,348 1,648,117 54,172 164,880 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 17 of 20 Table C-2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index tion Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours PERIOD 2f - License Termination Period 2fDirect Decommissioning Activities 2£.1.1 ORISE confirmatory survey 178 75 253 253 2£.1.2 Terminate license a 2£.1 Subtotal Period 2f Activity Costs 178 75 253 253 Period 2f Additional Costs 2£.2.1 License Termination Survey 14,399 6,056 20,456 20,456 200,468 3,120 2£2 Subtotal Period 2f Additional Costs 14,399 6,056 20,456 20,456 200,468 3,120 Period 2f Collateral Costs 2f.3.1 DOC staff relocation expenses 1,415 297 1,712 1,712 2f.3 Subtotal Period 2f Collateral Costs 1,415 297 1,712 1,712 Period 2fPeriod-Dependent Costs 2f.4.1 Insurance 319 45 364 364 2f.4.2 Property taxes 125 17 142 142 2f.4.3 Health physics supplies 834 292 1,127 1,127 2f.4.4 Disposal of DAW generated 9 2 27 11 49 49 356 7,337 11 2f.4.5 Plant energy budget 174 37 211 211 2£.4.6 NRC Fees 312 44 356 356 2£.4.7 Emergency Planning Fees 269 38 307 307 2f.4.8 Spent Fuel Transfer - Pool or ISFSI to DOE 1,130 238 1,368 1,368 2f.4.9 ISFSI Operating Costs 34 7 41 41 2£.4.10 Security Staff Cost 1,694 356 2,050 2,050 31,036 2f.4.11 DOC Staff Cost 4,689 986 5,675 5,675 46,750 2f.4.12 Utility Staff Cost 5,150 1,083 6,233 6,233 60,107 2f.4 Subtotal Period 2fPeriod-Dependent Costs 834 9 2 27 13,897 3,154 17,924 16,208 1,716 356 7,337 11 137,893 2f.O TOTAL PERIOD 2f COST 834 9 2 27 29,889 9,583 40,345 38,629 1,716 356 7,337 200,479 141,013 PERIOD 2 TOTALS 9,816 70,926 28,855 14,141 105,405 510,074 195,310 934,527 831,404 90,569 12,554 573,488 845 574 50,348,710 871,939 5,034,284 PERIOD 3b - Site Restoration Period 3b Direct Decommissioning Activities Demolition of Remaining Site Buildings 3b.1.1.1 *Reactor 6,798 1,430 8,228 8,228 67,914 3b. 1. 1.2 Administration 1,067 224 1,291 1,291 10,358 3b. 1. 1.3 Auxiliary 6,587 1,385 7,972 7,972 64,471 3b. 1. 1.4 Capital Additions 85-2004 4,359 917 5,276 5,276 47,403 3b.1.1.5 Chemical Storage 4 1 5 5 46 3b. 1. 1.6 Chlorination 9 2 11 11 99 3b. 1. 1.7 Circulating Water Tunnels 1,153 243 1,396 1,396 12,194 3b. 1. 1.8 Cold Machine Shop 396 83 479 479 3,785 3b.1.1.9 Communication 4 1 5 5 44 3b. 1. 1.10 Condensate PolishingrI'echnical Support 870 183 1,053 1,053 9,300 3b. 1. 1.11 Containment Penetration Area 686 144 830 830 6,565 3b. 1. 1.12 Discharge Structure 937 197 1,134 1,134 8,321 3b. 1. 1.13 Fabrication Shop 120 25 145 145 1,223 3b. 1. 1.14 Fire Pump House 5 1 6 6 55 3b.1.1.15 Hazardous Waste Storage Facility 39 8 48 48 430 3b. 1. 1.16 Intake Structure 5,309 1,116 6,425 6,425 46,364 3b. 1. 1.17 Maintenance Shop 365 77 442 442 3,444 3b.1.1.18 Miscellaneous Structures 64 13 77 77 673 3b. 1. 1.19 NPO Permanent Warehouse 1,367 287 1,654 1,654 14,093 3b. 1. 1.20 Ponds 2 0 2 2 24 3b.1.1.21 Portable Fire Pump & Fuel Cart 1 0 2 2 14 3b.1.1.22 Pretreatment 10 2 12 12 108 3b.1.1.23 Radwaste Storage 1,777 374 2,150 2,150 17,854 3b.1.1.24 Radwaste Storage Facility (Additional) 49 10 60 60 662 3b.1.1.25 Rotor Warehouse 847 178 1,025 1,025 9,938 3b.1.1.26 Security 344 72 417 417 3,944 3b. 1. 1.27 Security Buildings (additional) 53 11 65 65 722 TLG Services, Inc.

Diablo Canyon Power Plant Document POI-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 18 of 20 Table C-2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours Demolition of Remaining Site Buildings (continued) 3b.1.1.28 Simulator 413 87 500 500 4,191 3b.1.1.29 Steam Generator Storage Facility 909 191 1,100 1,100 8,888 3b.1.1.30 Telephone Terminal 3 1 3 3 28 3b.1.1.31 Turbine 5,538 1,165 6,703 6,703 57,744 3b.1.1.32 Turbine Pedestal 1,318 277 1,596 1,596 11,300 3b.1.1.33 Vehicle Maintenance 34 7 41 41 367 3b.1.1.34 Waste Water Holding & Treatment Facility 23 5 27 27 238 3b.1.1.35 Fuel Handling 1,858 391 2,248 2,248 16,750 3b.1.1 Totals 43,321 9,110 52,431 52,431 429,552 Site Closeout Activities 3b.1.2 Grade & landscape site 2,758 580 3,338 3,338 4,587 3b.1.3 Final report to NRC 98 21 119 119 668 3b.1 Subtotal Period 3b Activity Costs 46,079 98 9,711 55,888 119 55,769 434,139 668 Period 3b Additional Costs 3b.2.1 Backfill Structures & Remove Concrete Rubble 35,142 7,390 42,532 42,532 160,418 3b.2.2 Breakwater Demolition and Removal 41,893 14,684 56,577 56,577 128,379 46,649 3b.2.3 Cofferdam Construction and Teardown 478 101 579 579 4,004 3b.2.4 Concrete Crushing 9,113 5 1,917 11,035 11,035 37,775 3b.2.5 Disposal of Galbestos Siding 317 67 383 383 3b.2.6 Disposition of Mobile Barriers 1,318 277 1,595 1,595 4,362 3b.2.7 Soil/Sediment Control Plant Area 1,052 221 1,273 1,273 10,271 3b.2 Subtotal Period 3b Additional Costs 88,996 321 24,657 113,975 113,975 345,209 46,649 Period 3b Collateral Costs 3b.3.1 Small tool allowance 1,107 233 1,340 1,340 3b.3 Subtotal Period 3b Collateral Costs 1,107 233 1,340 1,340 Period 3b Period-Dependent Costs 3b.4.1 Insurance 525 74 598 598 3b.4.2 Property taxes 410 57 467 467 3b.4.3 Heavy equipment rental 7,347 1,545 8,892 8,892 3b.4.4 Plant energy budget 286 60 347 347 3b.4.5 NRC ISFSI Fees 348 49 397 397 3b.4.6 Emergency Planning Fees 885 124 1,010 1,010 3b.4.7 Spent Fuel Transfer - Pool or ISFSI to DOE 3,711 780 4,491 4,491 3b.4.8 ISFSI Operating Costs 111 23 134 134 3b.4.9 Security Staff Cost 5,569 1,171 6,740 5,459 1,281 102,023 3b.4.10 DOC Staff Cost 14,111 2,967 17,078 17,078 136,891 3b.4.11 Utility Staff Cost 7,357 1,547 8,904 1,781 7,123 87,197 3b.4 Subtotal Period 3b Period-Dependent Costs 7,347 33,312 8,399 49,058 14,338 34,721 326,112 3b.0 TOTAL PERIOD 3b COST 143,529 33,732 42,999 220,261 119 14,338 205,804 779,348 373,428 PERIOD 3c - Fuel Storage Operations/Shipping Period 3e Direct Decommissioning Activities Period 3e Period-Dependent Costs 3c.4.1 Insurance 3,099 434 3,534 3,534 3c.4.2 Property taxes 2,420 339 2,760 2,760 3e.4.3 Plant energy budget 3e.4.4 NRC ISFSI Fees 2,054 288 2,342 2,342 3e.4.5 Emergency Planning Fees 5,228 733 5,961 5,961 3e.4.6 Spent Fuel Transfer - Pool or ISFSI to DOE 21,995 4,625 26,620 26,620 3e.4.7 ISFSI Operating Costs 654 138 792 792 3e.4.8 Security Staff Cost 26,771 5,630 32,401 32,401 411,789 3e.4.9 Utility Staff Cost 8,802 1,851 10,654 10,654 103,100 3e.4 Subtotal Period 3e Period-Dependent Costs 71,024 14,039 85,063 85,063 514,888 3e.0 TOTAL PERIOD 3e COST 71,024 14,039 85,063 85,063 514,888 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 19 of 20 Table C-2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activit Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d.1.1.1 Vessel & Internals GTCC Disposal 2,500 9,179 2,281 13,960 13,960 1,785 350,510 3d.1.1 Totals 2,500 9,179 2,281 13,960 13,960 1,785 350,510 3d.1 Subtotal Period 3d Activity Costs 2,500 9,179 2,281 13,960 13,960 1,785 350,510 Period 3d Collateral Costs 3d.3 Subtotal Period 3d Collateral Costs Period 3d Period-Dependent Costs 3dA.1 Insurance 10 11 11 3dA.2 Property taxes 8 9 9 3dA.3 Plant energy budget 3dAA NRC ISFSI Fees 6 1 7 3dA.5 ISFSI Operating Costs 2 0 3 3dA.6 Security Staff Cost 85 18 103 103 1,311 3d.4.7 Utility Staff Cost 28 6 34 34 328 3d.4 Subtotal Period 3d Period-Dependent Costs 139 28 167 167 1,640 3d.0 TOTAL PERIOD 3d COST 2,500 9,179 139 2,308 14,127 13,960 167 1,785 350,510 1,640 PERIOD 3e - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 3e Additional Costs 3e.2.1 ISFSI License Termination 40 6 14 393 622 286 1,362 1,362 1,305 108,721 4,535 360 3e.2 Subtotal Period 3e Additional Costs 40 6 14 393 622 286 1,362 1,362 1,305 108,721 4,535 360 Period 3e Collateral Costs 3e.3.1 Small tool allowance 0 3e.3 Subtotal Period 3e Collateral Costs 0 Period 3e Period-Dependent Costs 3eA.1 Insurance 3e.4.2 Property taxes 55 8 63 63 3e.4.3 Heavy equipment rental 136 29 165 165 3eAA Plant energy budget 3eA.5 NRC ISFSI Fees 94 13 107 107 3eA.6 Security Staff Cost 61 13 74 74 1,901 3e.4.7 Utility Staff Cost 163 34 198 198 1,901 3e.4 Subtotal Period 3e Period-Dependent Costs 136 373 97 606 606 3,803 3e.0 TOTAL PERIOD 3e COST 177 6 14 393 995 383 1,968 1,968 1,305 108,721 4,535 4,163 PERIOD 3f - ISFSI Site Restoration Period 3f Direct Decommissioning Activities Period 3f Additional Costs 3f.2.1 ISFSI Demolition and Site Restoration 1,371 27 294 1,692 1,692 15,387 80 3f.2.2 ISFSI Area Soil I Sediment Control 16 3 20 20 2,568 3f.2 Subtotal Period 3f Additional Costs 1,387 27 297 1,712 1,712 17,955 80 Period 3f Collateral Costs 3f.3.1 Small tool allowance 20 4 24 24 3f.3 Subtotal Period 3f Collateral Costs 20 4 24 24 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 20 of 20 Table C-2 Diablo Canyon Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed _==-_""7"'"_...",.:B:;:;.u::;r::.:i=a::..I..:.V..::o.:,:lu~m=e:::..s""'_---.,=-=-=,....- Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contin enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours Period 3fPeriod-Dependent Costs 3f.4.1 Insurance 3f.4.2 Property taxes 28 4 32 32 3f.4.3 Heavy equipment rental 54 11 65 65 3f.4.4 Plant energy budget 3f.4.5 Security Staff Cost 11 2 14 14 349 3f.4.6 Utility Staff Cost 69 14 83 83 784 3f.4 Subtotal Period 3f Period-Dependent Costs 54 108 32 193 193 1,133 3f.O TOTAL PERIOD 3fCOST 1,461 134 333 1,928 1,928 17,955 1,213 PERIOD 3 TOTALS 145,167 2,506 14 9,572 106,024 60,063 323,347 14,079 103,464 205,804 1,305 1,785 459,231 801,837 895,332 TOTAL COST TO DECOMMISSION 13,073 218,618 31,702 14,580 124,490 768,430 292,711 1,463,605 1,036,573 207,854 219,179 586,268 1,732 574 1,785 51,548,980 1,686,102 6,887,098 TOTAL COST TO DECOMMISSION WITH 25% CONTINGENCY: $1,463,605 thousands of 2011 dollars TOTAL NRC LICENSE TERMINATION COST IS 70.82% OR: $1,036,573 thousands of 2011 dollars SPENT FUEL MANAGEMENT COST IS 14.2% OR: $207,854 thousands of 2011 dollars NON-NUCLEAR DEMOLITION COST IS 14.98% OR: $219,178 thousands of 2011 dollars TOTAL SCRAP METAL REMOVED: 77,728 Tons TOTAL CRAFT LABOR REQUIREMENTS: 1,686,102 Man-hours End Notes:

nJa - indicates that this activity not charged as decommissioning expense.

a - indicates that this activity performed by decommissioning staff.

0- indicates that this value is less than 0.5 but is non-zero.

a cell containing" - " indicates a zero value TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix D, Page 1 of 22 APPENDIXD DETAILED COST ANALYSIS SAFSTOR TLG Services, Inc.

Decommissioning Cost Analysis for the Diablo Canyon Power Plant, Appendix D Intentionally not included.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 1 of 28 APPENDIXE DETAILED COST ANALYSIS DECON - 20 YEAR LICENSE RENEWAL This Appendix contains the following Figures and Tables Figure E.l DECON Alternative - 20 Year License Renewal Decommissioning Timeline ................................................................................................ E-3 Table E-l DECON Alternative - 20 Year License Renewal Schedule of Total Annual Expenditures, Unit 1 ............................................................... E-4 Table E-2 DECON Alternative - 20 Year License Renewal Schedule of Total Annual Expenditures, Unit 2 ............................................................... E-6 Table E-3 DECON Alternative - 20 Year License Renewal Decommissioning Cost Elements, Unit 1. .......................................................................... E-8 Table E-4 DECON Alternative - 20 Year License Renewal Decommissioning Cost Elements, Unit 2 ........................................................................... E-9 Table E-5 DECON Alternative - 20 Year License Renewal Decommissioning Waste Summary, Unit 1 ..................................................................... E-I0 Table E-6 DECON Alternative - 20 Year License Renewal Decommissioning Waste Summary, Unit 1 ..................................................................... E-ll Table E-7 DECON Alternative - 20 Year License Renewal Decommissioning Cost Estimate, Unit 1 ......................................................................... E-12 Table E-8 DECON Alternative - 20 Year License Renewal Decommissioning Cost Estimate, Unit 2 ......................................................................... E-21 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 2 of 28 E.1 Background and Objective The DECON and SAFSTOR scenario estimates provided in the main body of this report are based on Diablo Canyon operating until the end of the current license, year 2024 and 2025 for Units 1 and 2, respectively. Alternate DECON scenario estimates have been prepared based on Diablo Canyon receiving a 20 year license renewal, and then operating until 2044 and 2045.

E.2 Estimating Approach The principal changes associated with this expanded period of operations that would impact the decommissioning estimate include the following:

  • Shut down dates are revised which delays decommissioning expenditures.
  • An additional 2,112 spent fuel assemblies are projected to be generated as a result of the extended period of operations. However, since the DOE is accepting spent fuel during much of this extended operating period, there is no need to construct additional ISFSI storage pads
  • The post-shutdown ISFSI operations schedule is revised to reflect the projected removal of all spent fuel from the ISFSI.
  • The reactor and internals will be subject to an additional 20 years of neutron activation which could impact waste packaging and disposal costs.

Since the estimate is developed in year* 20 11 constant dollars there are no other significant cost impacts to the decommissioning estimate other than those identified above.

E.3 Results Incorporating the impact of the changes associated with operating the Diablo Canyon station for an additional 20 years results in an estimated decommissioning cost of $2,624.4 million, including 25% contingency (2011 dollars). Similar to the figures and tables provided in the main body of this report, the following are provided in this appendix:

Decommissioning Timeline (Figure E-l)

Schedule of Total Annual Expenditures (Tables E-l and E-2)

Decommissioning Cost Elements (Tables E-3 and E-4)

Decommissioning Waste Summary (Tables E-5 and E-6)

DECON Decommissioning Cost Estimates (Tables E-7 and E-8)

TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 3 of 28 FIGURE E.I DECON ALTERNATIVE - 20 YEAR LICENSE RENEWAL DECOMMISSIONING TIMELINE (not to scale)

Unit I (Shutdown November 2, 2044)

Pool and ISFSI Operations ISFSIOperations Period 1 Period 2 Period 3 Transition and Site Preparations Decommissioning Restoration ISFSIOperations ISFSI D&D 11/2044 05/2046 11/2058 05/2061 12/2071 07/2072 Storage Pools Empty Unit 1 - 11/2056 Unit 2 - 08/2057 Unit 2 (Shutdown August 26, 2045)

Period 1 Period 2 Period 3 Transition and Site Prepara tions Decommissioning Restoration ISFSIOperations ISFSI D&D 08/2045 02/2047 11/2058 05/2061 12/2071 07/2072 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 4 of 28 TABLEE-1 DECON ALTERNATIVE- 20 YEAR LICENSE RENEWAL SCHEDULE OF TOTAL ANNUAL EXPENDITURES, UNIT 1 (thousands, 2011 dollars)

PG&E Equipment & Contractor LLRW Year Labor Materials Labor Disposal Other Total

-~~~~!f --~-~:-:~~-l------::::i:!!f- F-::~~~~~~~~:::f::---d~F:::--- 4-H~Ff=:=:::~~tf~FI i

2046 ' 49,746 : 24,695 l 40,117 36,644 19,220 I 170,423 I 2047 45,136 27,128 I 39,072 45,144 15,959' 172,438 2048 37,703 8,401 I 25,241 26,667 15,547 113,559 2049 37,600 8,378 25,172 26,595 15,504 113,249

. . . . . . . .?.9.Q.9.... . . . .,. . . . ?§.J.. 4.~.?.. . . . .1 ..........................................??..4.§..7.. ~, 593

""'fl.... ........................ . . . . . . . . .§.?.~.§.~.......... 9,991 I 56,522 I 2051 19,339 i 956 , 166 40 "'''''''''-'''~j'~i8'9'''l """2'7'~'6'96 ""'I

~952__l 19,392 i 958 I 167_,____4_Q___ 7,209 I 27,766 i 2053 19,339 956 I 166 40 7,189 I 27,690 2054 19,339 956 166 40 7,189 27,690 2059 2060 6,332 7,947 I 12,290 0 2,407! 28,977 2061 4,079 2,671 I 4,130 0 2,350 13,230

=_ _QT

!---------;----'---+-

_ +_

2062 2,943 i 0 I 0 i 0 2,324 5,267 I

___~Q§~____l ___ g,~:t~__

2064  ; 2,951 r::=:==___Q i _ 0, 0 O~J~~!l______§,g§Lj 0 2,330 5,281 I 2065 2,943 0 0 0 2,324 5,267 I 2066 2,943 0 0 0 2,324 5,267 I 2067 2,943 0 0 0 2,324 5,267 I 2068 2,951 0 I 0 0 2,330 5,281 I 2072 368 736 I 1,258 530 1,003 3,895 I L. Total i 454,197 118,058 246,033 163,672 239,761 1,221,721 TLG Services, Inc.

Diablo Canyon Power Plant Document PO 1-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 5 of 28 TABLE E-2 DECON ALTERNATIVE - 20 YEAR LICENSE RENEWAL SCHEDULE OF TOTAL ANNUAL EXPENDITURES, UNIT 2 (thousands, 2011 dollars)

PG&E Equipment & Contractor LLRW Labor Materials Labor Disposal Other Total

................................................+..............1. . 7

. . . ,'. .4. . . 4. . . .3. . . . . . . ,1. . * *. * . * *. . * . *. . * * . * *. ******2*:*i2*S*. *. * . r*: : *.: . ::*::*:::.*::§:::9.§i:::**:*i. . :.:*: :. :* *. *. *. . *. "1':.508  :*.:::::*.:*::::.:::*:*.*iQ*~::i§.§.:::*:. : *I:*.*: : . . . . . . . . . .4.~.~. ?~.?.  :".: \

49,741 1 ....*.. *............*........*............ 9*)2*4. . . . '1".. 23,417 i 8,819 43,204 I 134,206 I 46,707 27,199 I 38,391 41,766 13,607 I 167,670 I 46,039 24,695 I 38,808 41,195 13,534 I 164,270 I 45,033 9,703 I 32,012 25,732 14,826 I 127,307 I 45,033 9,703 32,012 25,732 14,826 I 127,307 I

. . . .28,733

. . . . . . . . . . . . . . . . . . ' .. . . . . . . . . . . . .2,342 . . . . . . . . . . . . . . . .+I 4,978 . .??..~..l.§......... 8,343 .*. . *. . . . . . *. . *. . . . . . . . . 1I

. . . . . . ]I. . . . . . . . . . . . . 48,312 r---_ _-+-_ 2_5",QJ2... 1,039 I 182 ' 45 7,213 I 34,390 I 25,841 I 1,036 I 182 45 7,193 34,297 I

- - -.. . . . . . . 5.!.......,8-4-1"'*"'*...;...- 1,036 I 182 45 7,193 34,297 I 25,841 1,036 I 182 45 7,193 34,297 4,075 14,803 I 11,930 0 2,400 I 33,208 I 2,940 0 I 0 0 2,321 I 5,261 2,940 0 I 0 0 2,321 I 5,261 2,940 I 0 I* 0 0 2,321 5,261 2,940 I 0 0 0 2,321 5,261 2,948 i 0 0 0 2,328 5,276 2,940 i 0 0 0 2,321 5,261

--~6~i---l- --~~{6-J

. *. . . *2()'7*2.. 368 : . . . *. . . *. . . . *. *. . *. *. *. *. . . . . .

2, 84~-------- --- ----ri--" --------------6----ii~-ji---f---::::!ii~~::1

~i3*5* . . . . r........ i,. 25.7. *. *. * *. . . . . . . *. . . . *. . . *. . *5*2*9*. * . . . . . . ."1')0'2.*. *. *]" 3,891 I

l. . . Total . . . ..1......4..~.Q.?§.?§.. . . ...1 .............................?...!.9.?..§.4..7.. . . ....l ...............?.Q.§.?..~.§..?. . . . . . . . . . . ..!.§..~.~. ~.?§ . . . . . . . . . . . . ?.?..?..?..9.~.§.. . . . . . . . . . . . . . . . .9.??.f?..~.7. . ...l TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 6 of 28 TABLE E-3 DECON ALTERNATIVE - 20 YEAR LICENSE RENEWAL DECOMMISSIONING COST ELEMENTS, UNIT 1 (thousands of 2011 dollars)

I Cost Element Total~rcentage Decontamination 17,212 1.4 I RllYn()val . ____1~2.1~Q.__ .._.._._-------- 10.6

~- -.-----~------~----_._-----_._-

i -n 1

!ring 40,158 3.3

~ransportation 18,014 1.5 Waste Disposal

_._-_ .._-_._-_._--_.._._--_.._._._--_._------._--_.__.._-_. __._. __. ______ 174, 7} 9 __.._._----------- 14.3 Program Management [1] 311,678 25.5 Security 263,946 21.6 Spent Fuel Pool Isolation 23,989 2.0 Spent Fuel Management [2] 103,865 8.5 I!!~.~~~!!.~_~. _~.!!~. .R~_K~!~~.Q~y_[~.~~__._._. _. _.__.____.____ .._.........._._._-.....__._._..._20,212 .._._._--- -~

1.7 Energy 10,306 0.8 Characterization and Licensing Surveys 21,286 1.7 i Property Taxes 5,222 0.4 Severance 74,095 6.1

)~~!~~~_g~.!!~g~~_. ~g.~.!P..~~!!.!. ._. __. . _. _.___. .._._. _________. __._._. . . ._. ._. ._.__. _. ._. . . . ___._. __7L§_~ --_._._--_.....__............_0.6 Total [3] 1,221,721 100.0

, Cost Element i Total Percentage I I

License Termination 997,101 ---_._-_._-_.._----- 81.6 Spent Fuel Management 151,162 12.4 Site Restoration I

'------_._----_. . _----_. _...__._. . _--_. _----_._.__.-------.j..........._----_._----- 1------_.._._..._ - -6.0 73,457 --

i I

I Total [3] I 1,221,721 100.0

[1] Includes engineering costs

[2] Excludes program management costs (staffing) but includes costs for spent fuel loading/transfer costs/spent fuel pool O&M and EP fees

[3] Columns may not add due to rounding TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 7 of 28 TABLEE-4 DECON ALTERNATIVE - 20 YEAR LICENSE RENEWAL DECOMMISSIONING COST ELEMENTS, UNIT 2 (thousands of 2011 dollars)

Cost Element Total Percentage Decontamination 20,362 1.5

~-

Removal

..-------.--.-------.-...----.-----.. -.~-.-~-.----.------_.

_._____..__..~~~2..~~Q._. ._._-_._._--_.----- 20.1 Packaging 39,723 2.8 Transportation 17,927 1.3

_~_~~~~_!?i~posaL_._.__. . ___.__. _____._______.___. ._.__ --------- 171,032 12.2 Program Management [1] 364,934 26.0 Security 249,060 17.8 Spent Fuel Pool Isolation 15,974 1.1 I Spent Fuel Management [2] 101,694 7.3

. _.l:g.~.~~~!?_~~_~ndJ~~~_~gu!~~.9._~yJf~.~.~_. . . ._. . . _. . . . . _. _. _. ___. _.__._..._--_.__.... .._.-.-.17,374 _ __.._---_._.. -_._.__..._._.__......__._..._-_._-._-- 1.2 Energy 10,069 0.7 Characterization and Licensing Surveys 24,682 1.8 Property Taxes 5,065 0.4 Severance 74,012 5.3

l. ._Mi~~~.!!~p.eo~~J~~.g.~!I?.!!?-_~.!?-..!_. .__._. _. . _. ._. . . . _. . . ._. . ._. . . . . ._. . _. __._. __. .__._____._._____.§L!Q!L ... ~.--.~-~.--

0.6 Total [3] 1,402,667 100.0 Cost Element Total Percent License Termination I 1,034,886 73.8

      • S--*~*~t-*F~~l"*M_;~;*-~~~~t---**---*----*-****---**-**--****--*_******-*-****-* . . *T*-**-*_*_*-..***--*-148:940 --..*--*-* -* ---** * -* * . **--i()"~6 Site Restoration

--~~~.--~-.-~--~---~~---.-.--------.-.---.--------"1-----.----

I 218,842 tal [3] 1,402,667

[1] Includes engineering costs

[2] Excludes program management costs (staffing) but includes costs for spent fuel loadingltransfer costs/spent fuel pool O&M and EP fees

[3] Columns may not add due to rounding TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 8 of 28 TABLE E-5 DECON ALTERNATIVE - 20 YEAR LICENSE RENEWAL DECOMMISSIONING WASTE

SUMMARY

, UNIT 1 I! Waste Volume Weight Waste  !

Cost Basis Class [1] (cubic feet) I (pounds)

I I

! I I!

Low -Level Radioactive I EnergySolutions Waste (near-surface I Large Component A 94,9591 7,860',384 disposal) EnergySolutions I I General A

-_._._-_._--- 147,369 I 9,579,584

-"-'---"-"-"---'--~-'---'-'l"'-'----'----'---'-'-_ ..._._._-

EnergySolutions  !

Bulk A 331,077 I 33,107,720 i!

I EnergySolutions  !

I IDAW A 14,017 I 288,673 I  !

Iwcs B 1,7321 197,501 Iwcs C 574\ 69,650 Greater than Class C I Spent Fuel (geologic repository) I Equivalent GTCC 1,7851 350,510 I

I

~

I!

! Ii I!

Total [2] i 591,5141 51,454,022

[1] Waste is classified according to the requirements as delineated in Title 10 CFR, Part 61.55

[2] Columns may not add due to rounding.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 9 of 28 TABLE E-6 DECON ALTERNATIVE - 20 YEAR LICENSE RENEWAL DECOMMISSIONING WASTE

SUMMARY

, UNIT 2 I Waste Volume I Weight Waste I I Cost Basis Class [1] (cubic feet) (pounds)

I I I Low-Level Radioactive I EnergySolutions Waste (near-surface I La~ge Component A 94,959 I 7,860,384 disposal) I EnergySolutions i I

I l_Q~~~~~-L. __--------.-.. . .. -~ .. A ..

--~>.-- ----.~.

138,015 I 9,004,003

~----'----'---""----'--'---"'-""!'----'-'---"'--_ ...._._._-_._..

I EnergySolutions I I Bulk A 337,395 I 33,739,520 I EnergySolutions

-.------..- - IDAW A 15,898 327,416 I WeB B 1,732 197,501 Iwcs C 574 I i 69,650 Greater than Class C I Spent Fuel (geologic repository) I Equivalent GTCC 1,785 I 350,510 i

I I I

I I I

  • Total [2] I 590,3591 51,548,984

[1] Waste is classified according to the requirements as delineated in Title 10 CFR, Part 61.55

[2] Columns may not add due to rounding.

TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 10 of 28 Table E-7 Diablo Canyon Unit 1 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours PERIOD la - Shutdown through Transition Period 1a Direct Decommissioning Activities 1a.1.1 Prepare preliminary decommissioning cost 191 40 231 231 1,300 1a.L2 Notification of Cessation of Operations a 1a.L3 Remove fuel & source material n1a la.L4 Notification of Permanent Defueling a la.L5 Deactivate plant systems & process waste a la.1.6 Prepare and submit PSDAR 294 62 356 356 2,000 la.L7 Review plant dwgs & specs. 676 142 818 818 4,600 la.L8 Perform detailed rad survey a 1a.L9 Estimate by.product inventory 147 31 178 178 1,000 la.1.10 End product description 147 31 178 178 1.000 1a.L11 Detailed by-product inventory 191 40 231 231 1,300 1a.L12 Define major work sequence 1,103 232 1,334 1,334 7,500 la.1.13 Perform SER and EA 456 96 551 551 3,100 1a.1.14 Perform Site-Specific Cost Study 735 154 889 889 5,000 1a.1.15 Prepare/submit License Termination Plan 602 126 729 729 4,096 la.l.16 Receive NRC approval of termination plan a Activity Specifications 1a.1.17.1 Plant & temporal'Y facilities 723 152 875 788 88 4,920 1a.1.17.2 Plant systems 613 129 741 667 74 4,167 la.L17.3 NSSS Decontamination Flush 74 15 89 89 500 1a.L17.4 Reactor internals 1,044 219 1,263 1,263 7,100 la.l.17.5 Reactor vessel 956 201 1,156 1,156 6,500 la.1.17.6 Biological shield 74 15 89 89 500 la.1.17.7 Steam generators 459 96 555 555 3,120 la.1.17.8 Reinforced concrete 235 49 285 142 142 1,600 1a.1.17.9 Main Turbine 59 12 71 71 400 1a.1.17.10 Main Condensers 59 12 71 71 400 la.L17.11 Plant structures & buildings 459 96 555 277 277 3,120 la.L17.12 Waste management 676 142 818 818 4,600 la.1.17.13 Facility & site closeout 132 28 160 80 80 900 la.1.17 Total 5,561 1,168 6,728 5,925 804 37,827 Planning & Site Preparations la.1.18 Prepare dismantling sequence 353 74 427 427 2,400 1a.L19 Plant prep. & temp. svces 2,800 588 3,388 3,388 1a.L20 Design water clean-up system 206 43 249 249 1,400 la.1.21 Rigging/Cont. Cntrl Envlps/tooling/etc. 2,200 462 2,662 2,662 la.L22 Procure caskslliners & containers 181 38 219 219 1,230 la.1 Subtotal Period 1a Activity Costs 15,842 3,327 19,168 18,365 804 73.753 Period 1a Additional Costs 1a.2.1 Spent Fuel Pool Isolation 19,825 4,163 23,989 23,989 la.2.2 Disposal of Contaminated Tools & Equipment 234 97 3,145 1,154 4,630 4,630 10,245 609,715 317 1a.2 Subtotal Period 1a Additional Costs 234 97 3,145 19,825 5,317 28,618 28,618 10,245 609,715 317 Period la Period-Dependent Costs 1a.4.1 Insurance 1,056 148 1,203 1,203 1a.4.2 Property taxes 165 23 189 189 1a.4.3 Health physics supplies 485 170 655 655 1a.4.4 Heavy equipment rental 480 101 580 580 1a.4.5 Disposal ofDAW generated 15 4 48 20 88 88 645 13.281 20 1a.4.6 Plant energy budget 1,156 243 1,399 1,399 1a.4.7 NRC Fees 1,177 165 1,342 1,342 1a.4.8 Emergency Planning Fees 1,001 140 1,142 1,142 1a.4.9 Spent Fuel Transfer - Pool or ISFSI to DOE 2,507 526 3,033 3,033 1a.4.10 Spent Fuel Pool O&M 763 160 923 923 1n.4.11 ISFSI Operating Costs 45 9 54 54 la.4.12 Severance Related Costs 35.456 7,446 42,901 42,901 1a.4.13 Security Staff Cost 14,837 3,116 17,953 17,953 229,429 la.4.14 Utility Staff Cost 33,000 6,930 39,930 39,930 423,400 la.4 Subtotal Period 1a Period*Dependent Costs 965 15 4 48 91,163 19,197 111,393 106,241 5.152 645 13,281 20 652,829 TLG SenJices, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 11 of 28 Table E-7 Diablo Canyon Unit 1 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours la.O TOTAL PERIOD la COST 965 249 101 3,193 126,830 27,841 159,180 153,224 5,152 804 10,890 622,996 337 726,581 PERIOD lb - Decommissioning Preparations Period Ib Direct Decommissioning Activities Detailed Work Procedures lb. 1. 1.l Plant systems 696 146 842 758 84 4,733 Ib.1.1.2 NSSS Decontamination Flush 147 31 178 178 1,000 Ib.U.3 Reactor internals 368 77 445 445 2,500 1b.1.1.4 Remaining buildings 198 42 240 60 180 1,350 1b.U.5 CRD cooling assembly 147 31 178 178 1,000 Ib.1.1.6 CRD housings & ICI tubes 147 31 178 178 1,000 1b.1.1.7 Incore instrumentation 147 31 178 178 1,000 Ib.1.1.8 Reactor vessel 534 112 646 646 3,630 Ib.1.1.9 Facility closeout 176 37 213 107 107 1,200 Ib.1.1.10 Missile shields 66 14 80 80 450 Ib.1.l.l1 Biological shield 176 37 213 213 1,200 lb. 1. 1.12 Steam generators 676 142 818 818 4,600 1b.1.1.13 Reinforced concrete 147 31 178 89 89 1,000 lb. 1. 1.14 Main Turbine 229 48 277 277 1,560 1b.1.1.15 Main Condensers 229 48 277 277 1,560 lb. 1. 1.16 Auxiliary building 401 84 486 437 49 2,730 lb. 1. 1.17 Reactor building 401 84 486 437 49 2,730 1b.1.l Total 4,887 1,026 5,913 4,801 1,112 33,243 lb. 1.2 Decon primary loop 750 525 1,276 1,276 1,067 1b.l Subtotal Period Ib Activity Costs 750 4,887 1,551 7,189 6,076 1,112 1,067 33,243 Period 1b Additional Costs 1b.2.1 Site Characterization 4,765 2,001 6,766 6,766 25,000 9,412 1b.2.2 Hazardous Waste Management 204 43 247 247 1b.2.3 Mixed Waste Management 270 57 327 327 Ib.2 Subtotal Period Ib Additional Costs 5,239 2,101 7,340 7,340 25,000 9,412 Period 1b Collateral Costs Ib.3.1 Decon equipment 931 195 1,126 1,126 Ib.3.2 DOC staff relocation expenses 1,415 297 1,712 1,712 Ib.3.3 Process decommissioning water waste 46 21 66 88 80 301 301 291 17,471 57 Ib.3.4 Process decommissioning chemical flush waste 2 63 256 6,210 2,237 8,767 8,767 887 94,531 166 Ib.3.5 Small tool allowance 3 1 3 3 Ib.3.6 Pipe cutting equipment 1,100 231 1,331 1,331 Ib.3.7 Decon rig 1,500 315 1,815 1,815 Ib.3 Subtotal Period 1b Collateral Costs 2,479 1,103 84 321 6,298 1,415 3,356 15,055 15,055 291 887 112,002 223 Period Ib Period-Dependent Costs Ib.4.1 Decon supplies 28 10 38 38 1b.4.2 Insurance 523 73 597 597 Ib.4.3 Property taxes 82 11 94 94 Ib.4.4 Health physics supplies 269 94 364 364 Ib.4.5 Heavy equipment rental 238 50 288 288 Ib.4.6 Disposal of DAW generated 9 3 28 12 51 51 375 7,718 12 Ib.4.7 Plant energy budget 1,147 241 1,388 1,388 Ib.4.8 NRC Fees 346 48 394 394 Ib.4.9 Emergency Planning Fees 497 70 566 566 Ib.4.l0 Spent Fuel Transfer - Pool or ISFSI to DOE 1,488 312 1,800 1,800 Ib.4.11 Spent Fuel Pool O&M 378 79 458 458 Ib.4.12 ISFSI Operating Costs 22 5 27 27 Ib.4.13 Severance Related Costs 5,351 1,124 6,475 6,475 Ib.4.14 Security Staff Cost 7,357 1,545 8,903 8,903 113,771 Ib.4.15 DOC Staff Cost 6,563 1,378 7,941 7,941 63,091 Ib.4.16 Utility Staff Cost 16,460 3,457 19,917 19,917 210,994 Ib.4 Subtotal Period 1b Period-Dependent Costs 28 507 9 3 28 40,214 8,509 49,299 46,448 2,851 375 7,718 12 387,857 Ib.O TOTAL PERIOD 1b COST 3,257 1,610 93 324 6,326 51,755 15,518 78,882 74,919 2,851 1,112 666 887 119,720 26,301 430,512 TLG Services, Inc.

Diablo Canyon Power Plant Document P01-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 12 of 28 Table E-7 Diablo Canyon Unit 1 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed __~__~__~B~u:r~i~a~I~V~o~lu~m~es~____~____ Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Descri tion Cost Cost Costs Costs . Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours PERIOD 1 TOTALS 3,257 2,575 342 425 9,519 178,585 43,358 238,062 228,143 8,003 1,916 11,556 887 742,716 26,638 1,157,093 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.1 Reactor Coolant Piping 370 354 52 40 1,342 868 3,026 3,026 2,276 260,153 10,138 2a.1.1.2 Pressurizer Quench Tank 39 35 8 6 189 108 385 385 329 36,557 1,073 2a. 1. 1.3 Reactor Coolant Pumps & Motors 118 126 103 185 1,443 685 2,660 2,660 4,701 774,960 4,185 100 2a. 1. 1. 4 Pressurizer 50 70 448 1Ho 750 409 1,841 1,841 2,443 286,592 2,365 938 2a.1.1.5 Steam Generators 477 4,206 3,368 1,922 12,807 7,163 29,942 29,942 41,712 3,350,761 27,047 1,750 2a. 1. 1.6 Retired Steam Generator Units 2,496 1,878 12,597 5,153 22,124 22,124 41,031 3,125,629 14,613 1,125 2a. 1. 1. 7 CRDMsIICIs/Service Structure Removal 196 112 262 37 444 376 1,428 1,428 3,881 86,025 4,285 2a. 1. 1.8 Reactor Vessel Internals 175 3,110 14,996 1,468 10,438 283 16,517 46,988 46,988 1,753 845 574 359,588 30,500 1,352 2a. 1. 1. 9 Reactor Vessel 122 5,226 2,439 742 2,651 283 8,601 20,065 20,065 8,794 957,382 30,500 1,352 2a.1.1 Totals 1,546 13,241 24,170 6,392 42,661 567 39,880 128,457 128,457 106,920 845 574 9,237,647 124,706 6,617 Removal of Major Equipment 2a.1. 2 Main Turbine/Generator 202 42 245 245 3,033 2a.1.3 Main Condensers 668 140 808 808 9,875 Cascading Costs from Clean Building Demolition 2a.1.4.1 *Reactor 1,194 251 1,444 1,444 11,895 2a.1. 4.2 Containment Penetration Area 73 15 89 89 704 2a.1.4.3 Fuel Handling 193 41 234 234 1,746 2a.1.4 Totals 1,460 307 1,767 1,767 14,345 Disposal of Plant Systems 2a.1. 5.1 Auxiliary Steam 148 31 179 179 2,310 2a.1.5.2 Auxiliary Steam (RCA) 277 61 19 652 338 1,347 1,347 2,054 126,415 3,758 2a.1.5.3 Condensate System 679 143 822 822 10,671 2a.1.5.4 Condensate System (Insulated) 281 59 341 341 4,367 2a.1.5.5 Containment Spray 249 167 53 1,786 747 3,001 3,001 5,631 346,093 3,734 2a.1.5.6 Extraction Steam & Heater Drip 263 55 318 318 4,152 2a.1.5.7 Feedwater System 46 10 55 55 706 2a.1.5.8 Feedwater System (Insulated) 168 35 204 204 2,655 2a.1.5.9 Feedwater System (RCA Insulated) 126 43 15 506 230 920 920 1,595 98,042 1,811 2a.1.5.10 Feedwater System (RCA) 6 2 1 27 12 48 48 84 5,160 87 2a.1.5.11 Lube Oil Distribution & Purification 115 24 139 139 1,817 2a.1.5.12 Nitrogen & Hydrogen 20 4 24 24 315 2a.1.5.13 Nitrogen & Hydrogen (Insulated) 1 o 1 17 2a.1.5.14 Nitrogen & Hydrogen (RCA Insulated) 6 1 o 5 4 16 16 17 1,040 78 2a.1.5.15 Nitrogen & Hydrogen (RCA) 110 12 3 102 77 304 304 320 19,767 1,478 2a.1.5.16 Oily Water Separator & TB Sump 37 12 5 157 71 281 281 494 30,347 480 2a.1.5.17 Saltwater System 190 40 230 230 2,926 2a.1.5.18 Turbine Steam Supply 759 159 918 918 11,955 2a.1.5.19 Turbine Steam Supply (RCA) 862 335 112 3,799 1,702 6,810 6,810 11,974 736,290 12,374 2a.1.5.20 Turbine and Generator 80 17 97 97 1,244 2a.1.5.21 Turbine and Generator (Insulated) 26 6 32 32 422 2a.1.5 Totals 4,450 633 207 7,034 3,763 16,087 12,727 3,360 22,169 1,363,155 67,355 2a.1.6 Scaffolding in support of decommissioning 2,465 9 5 113 905 3,497 3,497 369 32,791 16,818 2a.1 Subtotal Period 2a Activity Costs 1,546 22,486 24,812 6,604 49,808 567 45,037 150,861 146,448 4,413 129,458 845 574 10,633,590 236,132 6,617 Period 2a Additional Costs 2a.2.1 Retired Reactor Head 225 179 1,557 614 2,575 2,575 5,072 322,442 2,098 750 2a.2 Subtotal Period 2a Additional Costs 225 179 1,557 614 2,575 2,575 5,072 322,442 2,098 750 Period 2a Collateral Costs 2a.3.1 Process decommisSioning water waste 84 40 122 163 147 556 556 540 32,379 105 2a.3.2 Process decommissioning chemical flush waste 2a.3.3 Small tool allowance 287 60 347 313 35 2a.3 Subtotal Period 2a Collateral Costs 84 287 40 122 163 207 903 868 35 540 32,379 105 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 13 of 28 Table E-7*

Diablo Canyon Unit 1 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lhs. Manhours Manhours Period 2a Period-Dependent Costs 2a.4.1 Decon supplies 92 32 124 124 2a.4.2 Insurance 765 107 872 872 2a.4.3 Property taxes 267 37 304 274 30 2a.4.4 Health physics supplies 1,863 652 2,514 2,514 2a.4.5 Heavy equipment rental 3,362 706 4,068 4,068 2a.4.6 Disposal of DAW generated 96 27 300 124 548 548 4,010 82,574 124 2a.4.7 Plant energy budget 1,770 372 2,141 2,141 2a.4.8 NRC Fees 1,022 143 1,165 1,165 2a.4.9 Emergency Planning Fees 1,152 161 1,313 1,313 2a.4.10 Spent Fuel Transfer - Pool or ISFSI to DOE 4,833 1,015 5,848 5,848 2a.4.11 Spent Fuel Pool O&M 1,229 258 1,488 1,488 2a.4.12 ISFSI Operating Costs 72 15 87 87 2a.4.13 Severance Related Costs 3,173 666 3,839 3,839 2a.4.14 Security Staff Cost 23,902 5,019 28,921 28,921 369,600 2a.4.15 DOC Staff Cost 26,041 5,469 31,510 31,510 255,360 2a.4.16 Utility Staff Cost 36,803 7,729 44,532 44,532 467,141 2a.4 Subtotal Period 2a Period-Dependent Costs 92 5,224 96 27 300 101,028 22,506 129,273 120,507 8,736 30 4,010 82,574 124 1,092,101 2a.0 TOTAL PERIOD 2a COST 1,722 27,997 25,173 6,932 51,829 101,595 68,364 283,612 270,398 8,736 4,478 139,080 845 574 11,070,990 238,459 1,099,468 PERIOD 2b - Site Decontamination Period 2b Direct Decommissioning Activities Disposal of Plant Systems 2b.1.1.1 Capital Additions 85-2002 (clean) 182 38 220 220 2,830 2b.1.1.2 Capital Additions 85-2002 (contaminated) 485 54 19 635 404 1,597 1,597 2,017 123,100 6,781 2b.1.1.3 Chemical & Volume Control 875 1,229 197 67 2,277 1,881 6,526 6,526 7,273 441,322 27,754 2b.1.1.4 Chemical & Volume Control (Insulated) 324 465 50 14 466 562 1,879 1,879 1,463 90,248 10,807 2b.1.1.5 Component Cooling Water 196 41 237 237 3,078 2b.1.1.6 Component Cooling Water (RCA) 617 194 67 2,260 1,048 4,186 4,186 7,126 438,014 8,605 2b.1.1. 7 Compressed Air 174 37 211 211 2,744 2b.l.l.8 Compressed Air (Insulated) 6 1 7 7 98 2b.1.1.9 Compressed Air (RCA Insulated) 29 4 1 31 22 87 87 98 6,066 397 2b. 1. 1.10 Compressed Air (RCA) 534 67 18 595 408 1,621 1,621 1,868 115,262 7,278 2b. 1. 1. 11 Diesel Engine-Generator 179 38 217 217 2,760 2b.1.1.12 Diesel Engine-Generator (Insulated) 11 2 14 14 178 2b.1.1.13 Electrical (Clean) 2,130 447 2,578 2,578 32,770 2b.1.1.l4 Electrical (Contaminated) 633 91 38 1,275 689 2,726 2,726 4,028 247,187 8,649 2b.1.1.l5 Electrical (Decontaminated) 3,324 698 4,022 4,022 49,541 2b.1.1.16 Fire Protection 386 147 54 1,820 804 3,211 3,211 5,929 352,716 5,474 2b.l.l.17 Gaseous Radwaste 88 10 3 91 65 258 258 287 17,725 1,175 2b.l.l.18 HVAC (Clean Insulated) 29 6 35 35 475 2b.1.1.19 HVAC (Clean) 372 78 450 450 6,016 2b.1.1.20 HVAC (Contaminated Insulated) 309 55 22 733 377 1,496 1,496 2,315 142,139 4,107 2b.l.l.21 HVAC (Contaminated) 1,372 272 108 3,662 1,823 7,237 7,237 11,560 709,746 18,491 2b.1.1.22 Liquid Radwaste 582 785 116 38 1,283 1,155 3,958 3,958 4,1i6 248,609 18,831 2b.1.1.23 Liquid Radwaste (Insulated) 69 86 10 3 91 112 371 371 287 17,717 2,114 2b.1.1.24 Make*up Water 360 76 436 436 5,614 2b.1.1.25 Make-up Water (Insulated) 33 7 39 39 521 2b. 1. 1.26 Make-up Water (RCA Insulated) 44 8 2 81 46 181 181 255 15,691 602 2b.1.1.27 Make-up Water (RCA) 237 46 14 459 253 1,008 1,008 1,443 88,918 3,184 2b.1.1.28 Miscellaneous Reactor Coolant 21 137 17 5 155 120 453 453 491 30,030 2,172 2b.1.1.29 Nuclear Steam Supply Sampling 182 13 4 141 116 456 456 444 27,315 2,715 2b.1.1.30 Nuclear Steam Supply Sampling (Insulated 55 2 1 19 26 103 103 58 3,590 826 2b.1.1.31 Residual Heat Removal 319 336 165 55 1,873 1,031 3,779 3,779 5,901 363,036 6,105 2b.1.1.32 Safety Injection 128 22 7 245 135 537 537 784 47,397 1,860 2b.1.1.33 Safety Injection (Insulated) 6 1 0 11 6 24 24 33 2,043 90 2b.1.1.34 Safety Injection (RCA Insulated) 42 9 3 95 50 198 198 299 18,385 564 2b.1.1.35 Safety Injection (RCA) 350 80 25 854 438 1,747 1,747 2,689 165,467 4,712 2b.1.1.36 Service Cooling Water 118 25 142 142 1,856 2b.1.1.37 Service Cooling Water (RCA) 30 7 2 73 37 149 149 228 14,053 411 2b.1.1 Totals 2,188 15,679 1,635 567 19,225 13,100 52,395 43,787 8,607 60,992 3,725,778 252,189 2b.1.2 Scaffolding in support of decommissioning 3,081 12 6 141 1,131 4,371 4,371 462 40,989 21,023 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 14 of 28 Table E-7 Diablo Canyon Unit 1 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours Decontamination of Site Buildings 2b.1.3.1 *Reactor 958 2,483 1,120 5,645 26,011 11,986 48,204 48,204 331,897 33,045,180 43,301 2b.1.3.2 Capital Additions 85*2004 33 27 7 3 96 68 235 235 317 18,653 847 2b.1.3.3 Containment Penetration Area 327 213 26 28 379 446 1,419 1,419 2,121 172,739 7,351 2b.1.3 Totals 1,318 2,724 1,153 5,677 26,486 12,500 49,857 49,857 334,335 33,236,570 51,499 2b.1 Subtotal Period 2b Activity Costs 3,506 21,484 2,800 6,250 45,852 26,731 106,623 98,016 8,607 395,789 37,003,340 324,711 Period 2b Collateral Costs 2b.3.1 Process decommissioning water waste 133 65 199 266 237 901 901 881 52,880 172 2b.3.2 Process decommissioning chemical flush waste 3 103 420 782 379 1,687 1,687 1,459 155,522 273 2b.3.3 Small tool allowance 408 86 493 493 2b.3 Subtotal Period 2b Collateral Costs 136 408 168 620 1,048 702 3,082 3,082 2,341 208,402 445 Period 2b Period*Dependent Costs 2bA.1 Decon supplies 796 279 1,075 1,075 2bA.2 Insurance 1,138 159 1,298 1,298 2bA.3 Property taxes 397 56 452 452 2bAA Health physics supplies 2,527 885 3,412 3,412 2bA.5 Heavy equipment rental 4,962 1,042 6,004 6,004 2bA.6 Disposal ofDAW generated 104 29 325 134 593 593 4,338 89,346 134 2bA.7 Plant energy budget 2,079 437 2,516 2,516 2bA.8 NRC Fees 1,521 213 1,734 1,734 2bA.9 Emergency Planning Fees 1,714 240 1,954 1,954 2bA.10 Spent Fuel Transfer* Pool or ISFSI to DOE 7,184 1,509 8,692 8,692 2hA.11 Spent Fuel Pool O&M 1,829 384 2,214 2,214 2hA.12 Liquid Radwaste Processing Equipment/Services 465 98 562 562 2hA.13 ISFSI Operating Costs 107 23 130 130 2bA.14 Severance Related Costs 7,661 1,609 9,269 9,269 2bA.15 Security Staff Cost 35,568 7,469 43,037 43,037 550,000 2bA.16 DOC Staff Cost 26,233 5,509 31,741 31,741 270,000 2bA.17 Utility Staff Cost 38,925 8,174 47,100 47,100 502,500 2b.4 Subtotal Period 2b Period*Dependent Costs 796 7,490 104 29 325 124,820 28,218 161,783 148,793 12,990 4,338 89,346 134 1,322,500 2b.0 TOTAL PERIOD 2b COST 4,439 29,382 3,072 6,899 47,225 124,820 55,650 271,488 249,891 12,990 8,607 402,468 37,301,080 325,289 1,322,500 PERIOD 2c - Spent fuel delay prior to SFP decon Period 2c Direct Decommissioning Activities Period 2c Collateral Costs 2c.3.1 Spent Fuel Transfer* Pool to ISFSI 4,000 840 4,840 4,840 2c.3 Subtotal Period 2c Collateral Costs 4,000 840 4,840 4,840 Period 2c Period.Dependent Costs 2c.4.1 Insurance 3,475 486 3,961 3,961 2c.4.2 Property taxes 1,211 170 1,381 1,381 2cA.3 Health physics supplies 2,437 853 3,290 3,290 2cA.4 Disposal ofDAW generated 70 20 217 90 396 396 2,896 59,642 89 2cA.5 Plant energy budget 1,692 355 2,048 2,048 2cA.6 NRC Fees 2,671 374 3,045 3,045 2c.4.7 Emergency Planning Fees 5,232 733 5,965 5,965 2cA.8 Spent Fuel Transfer - Pool or ISFSI to DOE 19,638 4,124 23,763 23,763 2c.4.9 Spent Fuel Pool O&M 5,585 1,173 6,757 6,757 2cA.10 Liquid Radwaste Processing Equipment/Services 355 74 429 429 2cA.ll ISFSI Operating Costs 327 69 396 396 2c.4.12 Spent Fuel Storage Canisters/Overpacks 4,000 840 4,840 4,840 2cA.13 Security Staff Cost 108,574 22,801 131,374 131,374 1,678,914 2cA.14 Utility Staff Cost 8,384 1,761 10,145 10,145 114,471 2c.4 Subtotal Period 2c Period* Dependent Costs 2,437 70 20 217 161,144 33,902 197,788 156,068 41,721 2,896 59,642 89 1,793,386 2c.0 TOTAL PERIOD 2c COST 2,437 70 20 217 165,144 34,742 202,628 156,068 46,561 2,896 59,642 89 1,793,386 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 15 of 28 Table E-7 Diablo Canyon Unit 1 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Descri tion Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours PERIOD 2d - Decontamination Following Wet Fuel Storage Period 2d Direct Decommissioning Activities 2d.l.l Remove spent fuel racks 585 56 174 36 1,207 884 2,942 2,942 3,812 233,945 962 Disposal of Plant Systems 2d.1.2.1 Electrical (Contaminated)

  • FHB 184 14 6 194 136 534 534 614 37,673 2,491 2d.1.2.2 Electrical (Decontaminated) - FHB 1,165 133 53 1,781 1,061 4,192 4,192 5,623 345,118 15,061 2d.1.2.3 Fire Protection (RCA) 250 50 14 471 262 1,048 1,048 1,481 91,338 3,363 2d.1.2.4 HVAC (Contaminated)
  • FHB 326 64 25 838 422 1,674 1,674 2,644 162,353 4,383 2d.1.2.5 Spent Fuel Pit Cooling 94 65 21 706 293 1,179 1,179 2,223 136,855 1,433 2d.1.2.6 Spent Fuel Pit Cooling - FHB 130 70 23 764 328 1,315 1,315 2,405 148,051 1,959 2d.L2 Totals 2,150 396 140 4,754 2,501 9,942 9,942 14,990 921,389 28,690 Decontamination of Site Buildings 2d.1.3.1 Fuel Handling 811 859 63 41 637 1,109 3,519 3,519 3,443 251,129 23,547 2d.1.3 Totals 811 859 63 41 637 1,109 3,519 3,519 3,443 251,129 23,547 2d.1.4 Scaffolding in support of decommissioning 616 2 28 226 874 874 92 8,198 4,205 2d.1 Subtotal Period 2d Activity Costs 1,396 3,682 635 218 6,626 4,720 17,278 17,278 22,337 1,414,661 57,404 Period 2d Additional Costs 2d.2.1 License Termination Survey Planning 800 336 1,136 1,136 6,240 2d.2 Subtotal Period 2d Additional Costs 800 336 1,136 1,136 6,240 Period 2d Collateral Costs 2d.3.1 Process decommissioning water waste 34 19 58 77 66 254 254 257 15,400 50 2d.3.2 Process decommissioning chemical flush waste 2d.3.3 Small tool allowance 84 18 101 101 2d.3.4 Decommissioning Equipment Disposition 155 54 1,828 673 2,709 2,709 5,771 354,194 88 2d.3 Subtotal Period 2d Collateral Costs 34 84 174 112 1,905 756 3,064 3,064 6,028 369,594 138 Period 2d Period*Dependent Costs 2d.4.1 Decon supplies 209 73 282 282 2d.4.2 Insurance 219 31 249 249 2d.4.3 Property taxes 76 11 87 87 2d.4.4 Health physics supplies 443 155 598 598 2d.4.5 Heavy equipment rental 953 200 1,153 1,153 2d.4.6 Disposal of DAW genera ted 34 9 105 43 191 191 1,397 28,775 43 2d.4.7 Plant energy budget 213 45 258 258 2d.4.8 NRC Fees 250 35 285 285 2d.4.9 Emergency Planning Fees 165 23 188 188 2d.4.10 Spent Fuel Transfer* Pool or ISFSI to DOE 460 97 557 557 2d.4.11 Liquid Radwaste Processing Equipment/Services 178 37 216 216 2d.4.12 ISFSI Operating Costs 21 4 25 25 2d.4.13 Severance Related Costs 9,595 2,015 11,610 11,610 2d.4.14 Security Staff Cost 1,035 217 1,252 1,252 18,960 2d.4.15 DOC Staff Cost 3,363 706 4,069 4,069 35,040 2d.4.16 Utility Staff Cost 4,500 945 5,445 5,445 58,080 2d.4 Subtotal Period 2d Period.Dependent Costs 209 1,396 34 9 105 20,074 4,637 26,463 25,694 769 1,397 28,775 43 112,080 2d.0 TOTAL PERIOD 2d COST 1,639 5,161 842 339 8,636 20,873 10,449 47,941 47,171 769 29,762 1,813,030 57,585 118,320 PERIOD 2f - License Termination Period 2fDirect Decommissioning Activit.ies 2f.l.l ORISE confirmatory survey 178 75 253 253 2f.1.2 Terminate license a 2f.l Subtotal Period 2f Activity Costs 178 75 253 253 Period 2f Additional Costs 2f.2.1 License Termination Survey 9,248 3,884 13,132 13,132 126,393 3,120 2f.2 Subtotal Period 2f Additional Costs 9,248 3,884 13,132 13,132 126,393 3,120 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 16 of 28 Table E-7 Diablo Canyon Unit 1 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours Period 2f Collateral Costs 2f.3.1 DOC staff relocation expenses 1,415 297 1,712 1,712 2f.3 Subtotal Period 2f Collateral Costs 1,415 297 1,712 1,712 Period 2fPeriod-Dependent Costs 2f.4.1 Insurance 319 45 364 364 2f.4.2 Property taxes 125 17 142 142 2f.4.3 Health physics supplies 632 221 853 853 2f.4.4 Disposal ofDAW generated 9 2 27 11 49 49 356 7,337 11 2f.4.5 Plant energy budget 174 37 211 211 2f.4.6 NRC Fees 462 65 527 527 2f.4.7 Emergency Planning Fees 269 38 307 307 2f.4.8 Spent Fuel Transfer - Pool or ISFSI to DOE 753 158 912 912 2f.4.9 ISFSI Operating Costs 34 7 41 41 2f.4.10 Security Staff Cost 1,694 356 2,050 2,050 31,036 2f.4.11 DOC Staff Cost 4,689 985 5,674 5,674 46,750 2f.4.12 Utility Staff Cost 5,150 1,082 6,232 6,232 60,107 2f.4 Subtotal Period 2f Period-Dependent Costs 632 9 2 27 13,670 3,021 17,360 16,101 1,259 356 7,337 11 137,893 2f.0 TOTAL PERIOD 2f COST 632 9 2 27 24,510 7,276 32,456 31,197 1,259 356 7,337 126,404 141,013 PERIOD 2 TOTALS 7,800 65,609 29,166 14,192 107,933 436,943 176,482 838,125 754,724 70,315 13,086 574,562 845 574 50,252,080 747,827 4,474,686 PERIOD 3b - Site Restoration Period 3b Direct Decommissioning Activities Demolition of Remaining Site Buildings 3b.1.1.1 *Reactor 6,798 1,428 8,226 8,226 67,914 3b.1.1.2 Capital Additions 85-2004 302 63 365 365 3,572 3b.1.1.3 Containment Penetration Area 686 144 830 830 6,563 3b.1.1.4 Miscellaneous 28 6 34 34 249 3b.1.1.5 Turbine 3,659 768 4,428 4,428 38,603 3b. 1. 1.6 Turbine Pedestal 1,318 277 1,595 1,595 11,300 3b.1.1.7 Fuel Handling 1,858 390 2,248 2,248 16,750 3b.Ll Totals 14,650 3,076 17,726 17,726 144,951 Site Closeout Activities 3b.1.2 Grade & landscape site 2,758 579 3,337 3,337 4,587 3b.1.3 Final report to NRC 229 48 277 277 1,560 3b.1 Subtotal Period 3b Activity Costs 17,407 229 3,704 21,340 277 21,063 149,538 1,560 Period 3b Additional Costs 3b.2.1 Concrete Crushing 476 0 100 576 576 1,971 3b.2.2 Cofferdam Construction and Teardown 478 100 579 579 4,004 3b.2.3 Soil! Sediment Control Plant Area 1,052 221 1,273 1,273 10,271 3b.2 Subtotal Period 3b Additional Costs 2,006 0 421 2,427 2,427 16,247 Period 3b Collateral Costs 3b.3.1 Small tool allowance 210 44 254 254 3b.3 Subtotal Period 3b Collateral Costs 210 44 254 254 Period 3b Period-Dependent Costs 3b.4.1 Insurance 525 73 598 598 3b.4.2 Property taxes 410 57 467 467 3b.4.3 Heavy equipment rental 7,347 1,543 8,890 8,890 3b.4.4 Plant energy budget 286 60 347 347 3b.4.5 NRC ISFSI Fees 348 49 397 397 3b.4.6 Emergency Planning Fees 885 124 1,009 1,009 3b.4.7 Spent Fuel Transfer - Pool or ISFSI to DOE 2,474 520 2,994 2,994 3b.4.8 ISFSI Operating Costs 111 23 134 134 3b.4.9 Security Staff Cost 5,569 1,169 6,738 0 5,458 1,280 102,023 3b.4.10 DOC Staff Cost 14,111 2,963 17,074 17,074 136,891 3b.4.11 Utility Staff Cost 7,357 1,545 8,902 1,780 7,121 87,197 3b.4 Subtotal Period 3b Period-Dependent Costs 7,347 32,075 8,127 47,550 0 12,838 34,712 326,112 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 17 of 28 Table E-7 Diablo Canyon Unit 1 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Co'sts Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lhs. Manhours Manhours 3b.0 TOTAL PERIOD 3b COST 26,970 32,305 12,296 71,571 277 12,838 58,456 165,784 327,672 PERIOD 3c - Fuel Storage Operations/Shipping Period 3c Direct Decommissioning Activities Period 3c Period-Dependent Costs 3e.4.1 Insurance 2,251 315 2,566 2,566 3e.4.2 Property taxes 1,758 246 2,004 2,004 3e.4.3 Plant energy budget 3e.4.4 NRC ISFSI Fees 1,492 209 1,701 1.701 3e.4.5 Emergency Planning Fees 3,797 532 4,329 4,329 3e.4.6 Spent Fuel Transfer - Pool or ISFSI to DOE 11,163 2,344 13,507 13,507 3c.4.7 ISFSI Operating Costs 475 100 575 575 3e.4.8 Security Staff Cost 19,444 4,083 23,527 23,527 299,083 3e.4.9 Utility Staff Cost 6,393 1,343 7,736 7,736 74,881 3e.4 Subtotal Period 3c Period-Dependent Costs 46,773 9,172 55,945 55,945 373,964 3e.0 TOTAL PERIOD 3c COST 46,773 9,172 55,945 55,945 373,964 PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d.1.1.1 Vessel & Internals GTCC Disposal 2,500 9,179 2,278 13,957 13,957 1,785 350,510 3d.1.1 Totals 2,500 9,179 2,278 13,957 13,957 1,785 350,510 3d.1 Subtotal Period 3d Activity Costs 2,500 9,179 2,278 13,957 13,957 1,785 350,510 Period 3d Collateral Costs 3d.3 Subtotal Period 3d Collateral Costs Period 3d Period-Dependent Costs 3d.4.1 Insurance 10 11 11 3d.4.2 Property taxes 8 9 9 3d.4.3 Plant energy budget*

3d.4.4 NRC ISFSI Fees 6 1 7 7 3d.4.5 ISFSI Operating Costs 2 0 3 3 3d.4.6 Security Staff Cost 85 18 103 103 1,311 3d.4.7 Utility Staff Cost 28 6 34 34 328 3d.4 Subtotal Period 3d Period-Dependent Costs 139 28 167 167 1,640 3d.0 TOTAL PERIOD 3d COST 2,500 9,179 139 2,305 14,123 13,957 167 1,785 350,510 1,640 PERIOD 3e - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 3e Additional Costs 3e.2.1 ISFSI License Termination 40 6 14 393 622 286 1,361 1,361 1,305 108,721 4,535 360 3e.2 Subtotal Period 3e Additional Costs 40 6 14 393 622 286 1,361 1,361 1,305 108,721 4,535 360 Period 3e Collateral Costs 3e.3.1 Small tool allowance 1 0 3e.3 Subtotal Period 3e Collateral Costs 0 Period 3e Period-Dependent Costs 3e.4.1 Insurance 3e.4.2 Property taxes 55 8 63 63 3e.4.3 Heavy equipment rental 136 29 164 164 3e.4.4 Plant energy budget 3e.4.5 NRC ISFSI Fees 94 13 107 107 3e.4.6 Security Staff Cost 61 13 74 74 1.901 3e.4.7 Utility Staff Cost 163 34 198 198 1.901 3e.4 Subtotal Period 3e Period-Dependent Costs 136 373 96 605 605 3,803 3e.0 TOTAL PERIOD 3e COST 177 6 14 393 995 383 1,968 1,968 1,305 108,721 4,535 4,163 TLG Services, Inc.

Diablo Canyon Power Plant Document POI-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 18 of 28 Table E-7 Diablo Canyon Unit 1 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs ' Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours PERIOD 3f - ISFSI Site Restoration Period 3f Direct Decommissioning Activities Period 3f Additional Costs 3f,2,1 ISFSI Demolition and Site Restoration 1,371 27 294 1,691 1,691 15,387 80 3f.2.2 ISFSI Area Soil I Sediment Control 16 3 20 20 2,568 3f.2 Subtotal Period 3f Additional Costs 1,387 27 297 1,711 1,711 17.955 80 Period 3f Collateral Costs 3f.3.1 Small tool allowance 20 4 24 24 3f.3 Subtotal Period 3f Collateral Costs 20 4 24 24 Period 3f Period-Dependent Costs 3f.4.1 Insurance 3f.4.2 Property taxes 28 4 32 32 3f.4.3 Heavy equipment rental 54 11 65 65 3f.4.4 Plant energy budget 3f.4.5 Security Staff Cost 11 2 14 14 349 3f.4.6 Utility Staff Cost 69 14 83 83 784 3f.4 Subtotal Period 3fPeriod-Dependent Costs 54 108 32 193 193 1,133 3f.O TOTAL PERIOD 3f COST 1,461 134 333 1,928 1,928 17,955 1,213 PERIOD 3 TOTALS 28,607 2,506 14 9,572 80,347 24,488 145,535 14,234 72,845 58,456 1,305 1,785 459,231 188,274 708,651 TOTAL COST TO DECOMMISSION 11,057 96,791 32,014 14,632 127,024 695,875 244,329 1,221,721 997,101 151,163 73,457 587,422 1,732 574 1,785 51,454,030 962,738 6,340,431 TOTAL COST TO DECOMMISSION WITH 25% CONTINGENCY: $1,221,721 thousands of 2011 dollars TOTAL NRC LICENSE TERMINATION COST IS 81.61 % OR: $997,101 thousands of 2011 dollars SPENT FUEL MANAGEMENT COST IS 12.37% OR: $151,162 thousands of 2011 dollars NON-NUCLEAR DEMOLITION COST IS 6.01% OR: $73,457 thousands of 2011 dollars TOTAL SCRAP METAL REMOVED: 49,854 Tons TOTAL CRAFT LABOR REQUIREMENTS: 962,738 Man-hours End Notes:

nla - indicates that this activity not charged as decommissioning expense.

a - indicates that this activity performed by decommissioning staff.

0- indicates that this value is less than 0.5 but is non-zero.

a cell containing" - " indicates a zero value TLG Services, Inc.

Diablo Canyon Power Plant Document P01-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 19 of 28 Table E-8 Diablo Canyon Unit 2 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours PERIOD la - Shutdown through Transition Period 1a Direct Decommissioning Activities 1a.L1 Prepare preliminary decommissioning cost 82 17 99 99 556 1a.L2 Notification of Cessation of Operations a 1a.L3 Remove fuel & source material nJa 1a.L4 Notification of Permanent Defueling a 1a.L5 Deactivate plant systems & process waste a 1a.L6 Prepare and submit PSDAR 126 26 152 152 856 1a.L7 Review plant dwgs & specs. 289 60 350 350 1,969 1a.L8 Perform detailed rad survey a 1a.L9 Estimate by-product inventory 63 13 76 76 428 la.1.l0 End product description 63 13 76 76 428 1a.L11 Detailed by-product inventory 82 17 99 99 556 1a.1.12 Define major work sequence 472 98 570 570 3,210 1a.1.13 Perform SER and EA 195 41 236 236 1,327 1a.1.l4 Perform Site-Specific Cost Study 315 66 380 380 2,140 1a.1.15 Prepare/submit License Termination Plan 258 54 311 311 1,753 1a.l.l6 Receive NRC approval of termination plan a Activity Specifications 1a.L17.1 Plant & temporary facilities 310 65 374 337 37 2,106 1a.L17.2 Plant systems 262 55 317 285 32 1,783 1a.1.l7.3 NSSS Decontamination Flush 31 7 38 38 214 1a.1.17.4 Reactor internals 447 93 540 540 3,039 1a.1.l7.5 Reactor vessel 409 85 494 494 2,782 1a.1.17.6 Biological shield 31 7 38 38 214 1a.l.l7.7 Steam generators 196 41 237 237 1,335 1a.L17.8 Reinforced concrete 101 21 122 61 61 685 la.L17.9 Main Turbine 25 5 30 30 171 la.L17.10 Main Condensers 25 5 30 30 171 la.1.17.11 Plant structures & buildings 196 41 237 119 119 1,335 la.1.17.12 Waste management 289 60 350 350 1,969 la.1.17.13 Facility & site closeout 57 12 68 34 34 385 1a.l.l7 Total 2,380 497 2,876 2,533 344 16,190 Planning & Site Preparations 1a.L18 Prepare dismantling sequence 151 32 183 183 1,027 la.l.19 Plant prep. & temp. svces 2,800 584 3,384 3,384 la.l.20 Design water clean-up system 88 18 106 106 599 la.L21 Rigging/Cant. Cntrl Envlpsftoolingfetc. 2,200 459 2,659 2,659 la.l.22 Procure casksfliners & containers 77 16 94 94 526 la.1 Subtotal Period 1a Activity Costs 9,640 2,011 11,652 11,308 344 31,566 Period 1a Additional Costs la.2.1 Spent Fuel Pool Isolation 13,217 2,758 15,974 15,974 la.2.2 Disposal of Contaminated Tools & Equipment 234 97 3,145 1,146 4,622 4,622 10,245 609,715 317 la.2 Subtotal Period 1a Additional Costs 234 97 3,145 13,217 3,904 20,597 20,597 10,245 609,715 317 Period 1a Period-Dependent Costs la.4.1 Insurance 1,056 147 1,202 1,202 la.4.2 Property taxes 165 23 189 189 la.4.3 Health physics supplies 457 159 615 615 la.4.4 Heavy equipment rental 480 100 580 580 la.4.5 Disposal ofDAW generated 14 4 45 19 82 82 598 12,310 18 la.4.6 Plant energy budget 1,156 241 1,398 1,398 la.4.7 NRC Fees 838 117 954 954 la.4.8 Emergency Planning Fees 1,001 139 1,141 1,141 la.4.9 Spent Fuel Transfer - Pool or ISFSI to DOE 4,123 860 4,984 4,984 la.4.10 Spent Fuel Pool O&M 763 159 922 922 laA.ll ISFSI Operating Costs 45 9 54 54 laA.12 Severance Related Costs 38,503 8,034 46,537 46,537 la.4.13 Security Staff Cost 14,837 3,096 17,933 17,933 229,429 la.4.14 Utility Staff Cost 26,317 5,491 31,808 31,808 346,229 laA Subtotal Period la Period-Dependent Cost,s 936 14 4 45 88,804 18,594 108,398 101,297 7,101 598 12,310 18 575,657 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 20 of 28 Table E-8 Diablo Canyon Unit 2 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours 1a.0 TOTAL PERIOD 1a COST 936 248 101 3,190 111,661 24,509 140,647 133,202 7,101 344 10,843 622,025 336 607,223 PERIOD Ib - Deconunissioning Preparations Period 1b Direct Decommissioning Activities Detailed Work Procedures 1b.l.l.l Plant systems 298 62 360 324 36 2,026 1b.l.1.2 NSSS Decontamination Flush 63 13 76 76 428 1b.l.1.3 Reactor internals 157 33 190 190 1,070 1b.l.l.4 Remaining buildings 85 18 103 26 77 578 1b.Ll.5 CRD cooling assembly 63 13 76 76 428 Ib.l.1.6 CRD housings & ICI tubes 63 13 76 76 428 1b.1.l.7 Incore instrumentation 63 13 76 76 428 1b.l.l.8 Reactor vessel 228 48 276 276 1,554 lb.L1.9 Facility closeout 75 16 91 46 46 514 lb. 1. 1.10 Missile shields 28 6 34 34 193 lb. 1. l.l 1 Biological shield 75 16 91 91 514 lb. 1. 1.12 Steam generators 289 60 350 350 1,969 lb. l. 1. 13 Reinforced concrete 63 13 76 38 38 428 lb. 1. 1.14 Main Turbine 98 20 119 119 668 lb. 1. 1.15 Main Condensers 98 20 119 119 668 lb. 1. 1.16 Auxiliary building 172 36 208 187 21 1,168 lb. 1. 1.17 Reactor building 172 36 208 187 21 1,168 1b.Ll Total 2,092 436 2,528 2,053 475 14,228 1b.1.2 Decon primary loop 750 522 1,272 1,272 1,067 1b.l Subtotal Period Ib Activity Costs 750 2,092 958 3,800 3,325 475 1,067 14,228 Period 1b Additional Costs 1b.2.1 Site Characterization 2,038 850 2,888 2,888 10,690 4,024 lb.2.2 Hazardous Waste Management 204 43 247 247 1b.2.3 Mixed Waste Management 270 56 326 326 Ib.2 Subtotal Period Ib Additional Costs 2,512 949 3,461 3,461 10,690 4,024 Period Ib Collateral Costs Ib.3.1 Decon equipment 931 194 1,125 1,125 1b.3.2 DOC staff relocation expenses 1,415 295 1,710 1,710 Ib.3.3 Process decommissioning water waste 46 21 66 88 79 300 300 291 17,471 57 1b.3A Process decommissioning chemical flush waste 2 63 256 6,210 2,223 8,752 8,752 887 94,531 166 1b.3.5 Small tool allowance 3 1 3 3 1b.3.6 Pipe cutting equipment 1,100 230 1,330 1,330 lb.3.7 Decon rig 1,500 313 1,813 1,813 1b.3 Subtotal Period Ib Collateral Costs 2,479 1,103 84 321 6,298 1,415 3,334 15,033 15,033 291 887 112,002 223 Period 1b Period-Dependent Costs 1bA.l Decon supplies 28 10 38 38 1bA.2 Insurance 523 73 596 596 1bA.3 Property taxes 82 11 93 93 1bAA Health physics supplies 249 86 335 335 1bA.5 Heavy equipment rental 238 50 287 287 1bA.6 Disposal ofDAW generated 8 2 26 11 47 47 341 7,016 11 1bA.7 Plant energy budget 1,147 239 1,386 1,386 1bA.8 NRC Fees 237 33 270 270 1bA.9 Emergency Planning Fees 497 69 566 566 1bA.10 Spent Fuel Transfer - Pool or ISFSI to DOE 1,240 259 1,498 1,498 1b.4.11 Spent Fuel Pool O&M 378 79 457 457 1bA.12 ISFSI Operating Costs 22 5 27 27 1bA.13 Severance Related Costs 2,018 421 2,439 2,439 1bA.14 Security Staff Cost 7,357 1,535 8,893 8,893 113,771 IbA.15 DOC Staff Cost 4,664 973 5,637 5,637 46,543 IbA.16 Utility Staff Cost 13,050 2,723 15,773 15,773 171,691 IbA Subtotal Period 1b Period-Dependent Costs 28 487 8 2 26 31,216 6,577 38,343 35,795 2,548 341 7,016 11 332,006 1b.0 TOTAL PERIOD 1b COST 3,257 1,589 92 324 6,323 37,233 11,818 60,637 57,614 2,548 475 632 887 119,017 11,990 350,258 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 DecoJnmissioning Cost Analysis Appendix E, Page 21 of 28 Table E-8 Diablo Canyon Unit 2 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial f Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours PERIOD 1 TOTALS 3,257 2,525 341 425 9,514 148,895 36,328 201,284 190,816 9,649 819 11,475 887 741,042 12,325 957,482 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.1 Reactor Coolant Piping 370 354 52 40 1,342 863 3,021 3,021 2,276 260,153 10,138 2a.1.1.2 Pressurizer Quench Tank 39 35 8 6 189 107 385 385 329 36,557 1,073 2a.1.1.3 Reactor Coolant Pumps & Motors 118 126 103 185 1,443 680 2,656 2,656 4,701 774,960 4,185 100 2a. 1. 1.4 Pressurizer 50 70 448 114 750 406 1,838 1,838 2,443 286,592 2,365 938 2a.1.1.5 Steam Generators 477 4,206 3,368 1,922 12,807 7,117 29,895 29,895 41,712 3,350,761 27,047 1,750 2a.1.1.6 Retired Steam Generator Units 2,496 1,878 12,597 5,120 22,091 22,091 41,031 3,125,629 14,613 1,125 2a. 1. 1. 7 CRDMsflCls/Service Structure Removal 196 112 262 37 444 374 1,425 1,425 3,881 86,025 4,285 2a. 1: 1.8 Reactor Vessel Internals 163 3,064 14,919 1,413 10,366 278 16,257 46,459 46,459 1,502 845 574 352,188 29,833 1,325 2a. 1. 1.9 Reactor Vessel 122 5,180 2,387 742 2,651 278 8,478 19,838 19,838 8,794 957,382 29,833 1,325 2a.1.1 Totals 1,534 13,148 24,042 6,336 42,589 556 39,403 127,607 127,607 106,670 845 574 9,230,247 123,373 6,564 Removal of Major Equipment 2a.1.2 Main Turbine/Generator 202 42 245 245 3,033 2a.1.3 Main Condensers 668 139 807 807 9,875 Cascading Costs from Clean Building Demolition 2a.1.4.1 *Reactor 1,194 249 1,443 1,443 11,895 2a.1.4.2 Auxiliary 719 150 869 869 7,054 2a.1.4.3 Containment Penetration Area 73 15 89 89 704 2a.1.4.4 Radwaste Storage 91 19 110 110 918 2a.1.4.5 Fuel Handling 193 40 233 233 1,746 2a.1.4 Totals 2,270 474 2,744 2,744 22,317 Disposal of Plant Systems 2a.1.5.1 Auxiliary Steam 76 16 91 91 1,179 2a.1.5.2 Auxiliary Steam (RCA) 141 32 9 319 167 669 669 1,004 61,868 1,935 2a.1.5.3 Building Services (Non-Power Block) 7 1 8 8 106 2a.1.5.4 Condensate System 619 129 748 748 9,716 2a.1.5.5 Condensate System (Insulated) 274 57 332 332 4,253 2a.1.5.6 Containment Spray 235 161 51 1,719 713 2,879 2,879 5,421 333,235 3,521 2a.1.5.7 Extraction Steam & Heater Drip 230 48 278 278 3,625 2a.1.5.8 Feedwater System 67 14 81 81 1,038 2a.1.5.9 Feedwater System (Insulated) 162 34 195 195 2,547 2a.1.5.10 Feedwater System (RCA Insulated) 119 42 15 497 223 895 895 1,567 96,264 1,710 2a.1.5.11 Feedwater System (RCA) 6 2 1 26 12 46 46 82 5,067 82 2a.1.5.12 NSSS Sampling 159 9 3 100 92 363 363 315 19,386 2,404 2a.1.5.13 NSSS Sampling (Insulated) 47 0 10 20 78 78 31 1,903 712 2a.1.5.14 Nitrogen & Hydrogen 19 4 23 23 309 2a.1.5.15 Nitrogen & Hydrogen (Insulated) 1 0 1 1 16 2a.1.5.16 Nitrogen & Hydrogen (RCA Insulated) 5 0 5 4 15 15 15 937 74 2a.1.5.17 Nitrogen & Hydrogen (RCA) 103 11 3 92 70 279 279 288 17,804 1,405 2a.1.5.18 Oily Water Separator & TB Sump 29 11 3 102 48 192 192 319 19,671 410 2a.1.5.19 Saltwater System 181 38 218 218 2,779 2a.1.5.20 Turbine Steam Supply 762 159 921 921 12,007 2a.1.5.21 Turbine Steam Supply (RCA) 878 345 117 3,961 1,755 7,056 7,056 12,485 767,598 12,605 2a.1.5.22 Turbine and Generator 81 17 98 98 1,250 2a.1.5.23 Turbine and Generator (Insulated) 24 5 29 29 378 2a.1.5 . Totals 4,226 614 201 6,830 3,624 15,496 12,472 3,025 21,528 1,323,732 64,060 2a.1.6 Scaffolding in support of decommissioning 4,785 21 11 251 1,756 6,824 6,824 818 72,662 35,763 2a.l Subtotal Period 2a Activity Costs 1,534 25,300 24,677 6,548 49,671 556 45,438 153,724 149,647 4,077 129,016 845 574 10,626,640 258,421 6,564 Period 2a Additional Costs 2a.2.1 Retired Reactor Head 225 179 1,557 610 2,571 2,571 5,072 322,442 2,098 750 2a.2 Subtotal Period 2a Additional Costs 225 179 1,557 610 2,571 2,571 5,072 322,442 2,098 750 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 22 of 28 Table E-8 Diablo Canyon Unit 2 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours Period 2a Collateral Costs 2a.3.1 Process decommissioning water waste 85 40 123 165 148 561 561 545 32,727 106 2a.3.2 Process decommissioning chemical flush waste 2a.3.3 Small tool allowance 315 66 381 343 38 2a.3 Subtotal Period 2a Collateral Costs 85 315 40 123 165 213 941 903 38 545 32,727 106 Period 2a Period-Dependent Costs 2a.4.1 Decon supplies 92 32 124 124 2a.4.2 Insurance 768 107 874 874 2a.4.3 Property taxes 268 37 305 274 30 2a.4.4 Health physics supplies 1,968 684 2,653 2,653 2a.4.5 Heavy equipment rental 3,373 704 4,077 4,077 2a.4.6 Disposal ofDAW gcncrated 110 31 349 143 633 633 4,593 94,597 142 2a.4.7 Plant energy budget 1,776 370 2,146 2,146 2a.4.8 NRC Fees 724 101 825 825 2a.4.9 Emergency Planning Fees 1,156 161 1,317 1,317 2a.4.10 Spent Fuel Transfer* Pool or ISFSI to DOE 4,036 842 4,878 4,878 2a.4.11 Spent Fuel Pool O&M 1,234 257 1,491 1,491 2a.4.12 ISFSI Operating Costs 72 15 87 87 2a.4.13 Severance Related Costs 494 103 597 597 2a.4.14 Security Staff Cost 23,983 5,004 28,987 28,987 370,857 2a.4.15 DOC Staff Cost 26,130 5,452 31,582 31,582 256,229 2a.4.16 Utility Staff Cost 37,794 7,886 45,679 45,679 477,057 2a.4 Subtotal Period 2a Period*Dependent Costs 92 5,341 110 31 349 98,433 21,899 126,256 118,452 7,773 30 4,593 94,597 142 1,104,143 2a.0 TOTAL PERIOD 2a COST 1,711 30,956 25,052 6,881 51,741 98,989 68,161 283,491 271,573 7,773 4,145 139,227 845 574 11,076,410 260,767 1,111,457 PERIOD 2b - Site Decontamination Period 2b Direct Decommissioning Activities Disposal of Plant Systems 2b.1.1.1 Capital Additions 85*2002 (Clean) 450 94 544 544 7,040 2b.1.1.2 Capital Additions 85*2002 (contaminated) 483 61 24 797 459 1,823 1,823 2,532 154,520 6,606 2b.1.1.3 Chemical & Volume Control 809 1,066 172 58 1,966 1,653 5,723 5,723 6,290 380,935 24,738 2b.1.1.4 Chemical & Volume Control (Insulated) 294 432 47 13 438 516 1,740 1,740 1,376 84,904 9,960 2b.1.1.5 Component Cooling Water 190 40 230 230 2,984 2b.1.1.6 Component Cooling Water (RCA) 595 191 66 2,245 1,028 4,125 4,125 7,077 435,000 8,301 2b.1.1.7 Compressed Air 118 25 143 143 1,881 2b.1.1.8 Compressed Air (Insulated) 6 1 8 8 99 2b.1.1.9 Compressed Air (RCA Insulated) 29 4 1 33 22 89 89 104 6,415 404 2b.1.1.10 Compressed Air (RCA) 531 69 19 629 417 1,663 1,663 1,976 121,884 7,315 2b. 1. 1. 11 Diesel Engine-Generator 137 29 165 165 2,089 2b.1.1.12 Diesel Engine-Generator (Insulated) 3 1 4 4 48 2b.1.1.13 Electrical (Clean) 3,115 650 3,765 3,765 47,918 2b. 1. 1.14 Electrical (Contaminated) 360 44 18 613 348 1,384 1,384 1,936 118,833 4,901 2b.1.1.15 Electrical (RCA) 1,875 391 2,266 2,266 27,955 2b. 1. 1. 16 Fire Protection 364 148 53 1,792 781 3,138 3,138 5,838 347,206 5,173 2b. 1. 1.17 Gaseous Radwaste 133 20 6 217 126 501 501 690 41,995 1,842 2b.1.1.18 HVAC (Clean Insulated) 40 8 48 48 662 2b.1.1.19 HVAC (Clean) 428 89 518 518 7,019 2b. 1. 1.20 HVAC (Contaminated Insulated) 232 37 15 506 265 1,055 1,055 1,598 98,113 3,075 2b.1.1.21 HVAC (Contaminated) 1,033 185 76 2,563 1,292 5,149 5,149 8,091 496,626 13,890 2b. 1. 1.22 Liquid Radwaste 362 447 74 25 862 722 2,493 2,493 2,791 166,964 11,333 2b. 1. 1.23 Liquid Radwaste (Insulated) 29 44 5 45 52 177 177 142 8,780 1,007 2b.1.1.24 Lube Oil Distribution & Purification 126 26 152 152 1,964 2b. 1. 1.25 Make-up Water 244 51 295 295 3,794 2b.1.1.26 Make-up Water (Insulated) 24 5 29 29 376 2b.1.1.27 Make.up Water (RCA Insulated) 32 7 2 67 36 144 144 210 12,938 448 2b.1.1.28 Make*up Water (RCA) 164 39 11 378 196 788 788 1,190 73,314 2,245 2b. 1. 1.29 Mechanical Department Equipment 1 0 1 19 2b.1.1.30 Miscellaneous Reactor Coolant 21 141 17 5 158 122 463 463 500 30,589 2,240 2b.1.1.31 Nuclear Steam Supply Sampling 21 2 1 21 15 61 61 66 4,072 282 2b. 1. 1.32 Nuclear Steam Supply Sampling (Insulated 9 1 0 9 7 26 26 28 1,745 121 2b.1.1.33 Residual Heat Removal 307 305 162 54 1,845 995 3,668 3,668 5,811 357,510 5,524 2b. 1. 1.34 Safety Injection 124 21 7 242 132 526 526 776 46,891 1,799 2b.1.1.35 Safety Injection (Insulated) 5 0 10 6 23 23 32 1,987 76 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 23 of 28 Table E-8 Diablo Canyon Unit 2 DECON 60 Year Decommissioning Cost Estimate (Thousands of2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours Disposal of Plant Systems (continued) 2b. 1. 1.36 Safety Injection (RCA Insulated) 38 8 3 92 47 189 189 291 17,880 522 2b. 1. 1.37 Safety Injection (RCA) 322 76 24 830 416 1,669 1,669 2,616 160,916 4,326 2b.1.1.38 Service Cooling Water 138 29 167 167 2,186 2b.1.1.39 Service Cooling Water (RCA) 37 9 3 96 48 194 194 303 18,679 513 2b.1.1.40 Sewer System Expansion 47 10 57 57 746 2b.1.1 Totals 1,821 13,893 1,400 485 16,454 11,150 45,202 36,810 8,392 52,266 3,188,694 223,417 2b.1.2 Scaffolding in support of decommissioning 5,982 26 14 313 2,196 8,530 8,530 1,023 90,828 44,703 Decontamination of Site Buildings 2b.1.3.1 *Reactor 959 2,483 1,120 5,645 26,011 11,909 48,127 48,127 331,897 33,045,180 43,302 2b.1.3.2 Auxiliary 1,325 739 65 98 927 1,530 4,683 4,683 6,943 585,598 28,092 2b.1.3.3 Capital Additions 85-2004 423 168 10 20 151 411 1,184 1,184 1,331 117,734 8,113 2b.1.3.4 Containment Penetration Area 327 213 26 28 379 443 1,416 1,416 2,121 172,739 7,351 2b.1.3.5 Radwaste Storage 8 62 4 9 59 50 193 193 627 55,654 867 2b.1.3 Totals 3,042 3,666 1,224 5,801 27,526 14,343 55,603 55,603 342,918 33,976,900 87,726 2b.1 Subtotal Period 2b Activity Costs 4,863 23,541 2,650 6,300 44,293 27,689 109,335 100,943 8,392 396,208 37,256,420 355,847 Period 2b Collateral Costs 2b.3.1 Process decommissioning water waste 143 69 213 284 252 962 962 942 56,542 184 2b.3.2 Process decommissioning chemical flush waste 3 90 369 687 330 1,479 1,479 1,281 136,538 240 2b.3.3 Small tool allowance 445 93 538 538 2b.3 Subtotal Period 2b Collateral Costs 145 445 160 582 971 675 2,979 2,979 2,224 193,081 424 Period 2b Period-Dependent Costs 2b.4.1 Decon supplies 1,456 506 1,962 1,962 2b.4.2 Insurance 1,136 158 1,294 1,294 2b.4.3 Property taxes 396 55 451 451 2b.4.4 Health physics supplies 2,764 961 3,725 3,725 2b.4.5 Heavy equipment rental 4,951 1,033 5,984 5,984 2bA.6 Disposal of DAW generated 127 36 401 165 729 729 5,286 108,867 163 2hA.7 Plant energy hudget 2,074 433 2,507 2,507 2bA.8 NRC Fees 1,072 149 1,221 1,221 2bA.9 Emergency Planning Fees 1,710 238 1,948 1,948 2hA.10 Spent Fuel Transfer - Pool or ISFSI to DOE 5,978 1,247 7,225 7,225 2bA.11 Spent Fuel Pool O&M 1,825 381 2,206 2,206 2bA.12 Liquid Radwaste Processing Equipment/Services 463 97 560 560 2bA.13 ISFSI Operating Costs 107 22 129 129 2hA.14 Severance Related Costs 7,908 1,650 9,558 9,558 2bA.15 Security Staff Cost 35,487 7,404 42,891 42,891 548,743 2bA.16 DOC Staff Cost 37,206 7,763 44,968 44,968 364,166 2hA.17 Utility Staff Cost 53,628 11,189 64,817 64,817 675,951 2hA Subtotal Period 2h Period-Dependent Costs 1,456 7,715 127 36 401 148,989 33,452 192,175 180,666 11,509 5,286 108,867 163 1,588,860 2b.0 TOTAL PERIOD 2b COST 6,464 31,701 2,936 6,918 45,666 148,989 61,816 304,489 284,589 11,509 8,392 403,718 37,558,370 356,433 1,588,860 PERIOD 2c - Spent fuel delay prior to SFP decon Period 2c Direct Decommissioning Activities Period 2c Collateral Costs 2c.3.1 Spent Fuel Transfer - Pool to ISFSI 3,896 813 4,709 4,709 2c.3 Subtotal Period 2c Collateral Costs 3,896 813 4,709 4,709 Period 2c Period-Dependent Costs 2cA.1 Insurance 3,088 430 3,518 3,518 2cA.2 Property taxes 1,076 150 1,226 1,226 2cA.3 Health physics supplies 2,326 809 3,135 3,135 2cA.4 Disposal of DAW generated 68 19 216 88 392 392 2,839 58,472 88 2cA.5 Plant energy budget 1,504 314 1,818 1,818 2cA.6 NRC Fees 2,000 278 2,279 2,279 2cA.7 Emergency Planning Fees 4,651 647 5,297 5,297 2cA.8 Spent Fuel Transfer - Pool or ISFSI to DOE 15,422 3,218 18,640 18,640 2cA.9 Spent Fuel Pool O&M 4,964 1,036 5,999 5,999 2cA.10 Liquid Radwaste Processing Equipment/Services 315 66 381 381 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 24 of 28 Table E-8 Diablo Canyon Unit 2 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours Period 2c Period* Dependent Costs (continued) 2c.4.11 ISFSI Operating Costs 291 61 352 352 2c.4.12 Spent Fuel Storage Canisters/Overpacks 6.000 1.252 7.252 7.252 2c.4.13 Security Staff Cost 96.501 20.135 116,636 116,636 1,492.229 2c.4.14 Utility Staff Cost 42.556 8,879 51,436 51,436 535,846 2c.4 Subtotal Period 2c Period*Dependent Costs 2.326 68 19 216 178.368 37,362 218,360 180.820 37.540 2.839 58.472 88 2.028.074 2c.O TOTAL PERIOD 2c COST 2,326 68 19 216 182,264 38,175 223,068 180,820 42,248 2,839 58.472 88 2,028.074 PERIOD 2d - Decontamination Following Wet Fuel Storage Period 2d Direct Decommissioning Activities 2d.1.l Remove spent fuel racks 585 56 174 36 1,207 878 2,936 2,936 3.812 233,945 962 Disposal of Plant Systems 2d.1.2.1 Electrical (Contaminated). FHB 111 8 3 115 80 317 317 362 22,201 1,497 2d.1.2.2 Electrical (RCA).FHB 690 78 31 1,042 619 2,459 2,459 3,290 201,925 8.926 2d.1.2.3 Fire Protection (RCA) 264 67 18 613 318 1.281 1,281 1,925 118.758 3.614 2d.1.2.4 . HVAC (Contaminated)

  • FHB 231 39 16 542 277 1.105 1,105 1,711 104.999 3,086 2d.1.2.5 Spent Fuel Pit Cooling 94 65 21 712 294 1.187 1,187 2,243 138.063 1.442 2d.1.2.6 Spent Fuel Pit Cooling* FHB 130 71 23 772 328 1.324 1,324 2,430 149,602 1.956 2d.1.2 Totals 1.520 328 112 3,795 1,917 7.673 7,673 11,961 735.547 20.523 Decontamination of Site Buildings 2d.1.3.1 FuelHandling 811 859 63 41 637 1,101 3.512 3,512 3.443 251,129 23,547 2d.1.3 Totals 811 859 63 41 637 1.101 3.512 3,512 3,443 251,129 23.547 2d.1.4 Scaffolding in support of decommissioning 1,196 5 3 63 439 1,706 1.706 205 18.166 8,941 2d.1 Subtotal Period 2d Activity Costs 1,396 3.632 570 191 5,702 4,336 15,827 15,827 19,420 1,238,787 53.973 Period 2d Additional Costs 2d.2.1 License Termination Survey Planning 800 334 1,133 1,133 6.240 2d.2 Subtotal Period 2d Additional Costs 800 334 1.133 1,133 6,240 Period 2d Collateral Costs 2d.3.1 Process decommissioning water waste 37 20 62 82 70 270 270 272 16,319 53 2d.3.2 Process decommissioning chemical flush waste 2d.3.3 Small tool allowance 79 16 95 95 2d.3.4 Decommissioning Equipment Disposition 155 54 1,828 668 2,705 2,705 5,771 354,194 88 2d.3.5 Spent Fuel Transfer* Pool to ISFSI 2,104 439 2.543 2,543 2d.3 Subtotal Period 2d Collateral Costs 37 79 175 115 1,910 2.104 1.194 5,613 3,070 2.543 6,043 370,513 141 Period 2d Period* Dependent Costs 2d.4.1 Decon supplies 209 73 282 282 2d.4.2 Insurance 219 30 249 249 2d.4.3 Property taxes 76 11 87 87 2d.4.4 Health physics supplies 445 155 599 599 2d.4.5 Heavy equipment rental 953 199 1,152 1,152 2d.4.6 Disposal of DAW generated 45 13 143 59 260 260 1,885 38.817 58 2d.4.7 Plant energy budget 213 44 257 257 2d.4.8 NRC Fees 175 24 199 199 2d.4.9 Emergency Planning Fees 165 23 187 187 2d.4.10 Spent Fuel Transfer* Pool or ISFSI to DOE 811 169 980 980 2d.4.11 Liquid Radwaste Processing Equipment/Services 178 37 216 216 2d.4.12 ISFSI Operating Costs 21 4 25 25 2d.4.13 Severance Related Costs 12,313 2,569 14,882 14,882 2d.4.14 Security Staff Cost 1,035 216 1,251 1.251 18,960 2d.4.15 DOC Staff Cost 4.884 1.019 5,903 5,903 48.000 2d.4.16 Utility Staff Cost 7,532 1,572 9,104 9,104 91,680 2d.4 Subtotal Period 2d Period*Dependent Costs 209 1,398 45 13 143 27,621 6.204 35.633 34.440 1,192 1.885 38.817 58 158,640 2d.0 TOTAL PERIOD 2d COST 1,642 5,108 790 319 7,755 30.525 12,067 58.207 54,471 3,736 27,348 1,648,117 54,172 164,880 PERIOD 2f - License Termination TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 25 of 28 Table E-8 Diablo Canyon Unit 2 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours Period 2f Direct Decommissioning Activities 2f.1.1 ORISE confirmatory survey 178 74 252 252 2f.1.2 Terminate license a 2f.l Subtotal Period 2f Activity Costs 178 74 252 252 Period 2f Additional Costs 2f.2.1 License Termination Survey 14,399 6,009 20,408 20,408 200,468 3,120 2f.2 Subtotal Period 2f Additional Costs 14,399 6,009 20,408 20,408 200,468 3,120 Period 2f Collateral Costs 2f.3.1 DOC staff relocation expenses 1,415 295 1,710 1,710 2f.3 Subtotal Period 2f Collateral Costs 1,415 295 1,710 1,710 Period 2f Period* Dependent Costs 2f.4.1 Insurance 319 44 364 364 2f.4.2 Property taxes 125 17 142 142 2f.4.3 Health physics supplies 834 290 1,124 1,124 2f.4.4 Disposal of DAW generated 9 2 27 11 49 49 356 7,337 11 2f.4.5 Plant energy budget 174 36 211 211 2f.4.6 NRC Fees 312 43 356 356 2f.4.7 Emergency Planning Fees 269 37 307 307 2f.4.8 Spent Fuel Transfer* Pool or ISFSI to DOE 753 157 911 911 2f.4.9 ISFSI Operating Costs 34 7 41 41 2f.4.10 Security Staff Cost 1,694 353 2,048 2,048 31,036 2f.4.11 DOC Staff Cost 4,689 978 5,668 5,668 46,750 2f.4.12 Utility Staff Cost 5,150 1,075 6,225 6,225 60,107 2f.4 Subtotal Period 2fPeriod-Dependent Costs 834 9 2 27 13,521 3,051 17,444 16,186 1,258 356 7,337 11 137,893 2f.O TOTAL PERIOD 2f COST 834 9 2 27 29,513 9,429 39,814 38,556 1,258 356 7,337 200,479 141,013 PERIOD 2 TOTALS 9,816 70,926 28,855 14,141 105,405 490,279 189,648 909,070 830,009 66,524 12,537 573,488 845 574 50,348,710 871,939 5,034,284 PERIOD 3b - Site Restoration Period 3b Direct Decommissioning Activities Demolition of Remaining Site Buildings 3b.1.1.1 *Reactor 6,798 1,418 8,216 8,216 67,914 3b.1.1.2 Administration 1,067 223 1,289 1,289 10,358 3b.Ll.3 Auxiliary 6,587 1,374 7,961 7,961 64,471 3b.1.1.4 Capital Additions 85*2004 4,359 910 5,269 5,269 47,403 3b.Ll.5 Chemical Storage 4 1 5 5 46 3b.1.1.6 Chlorination 9 2 11 11 99 3b.1.1.7 Circulating Water Tunnels 1,153 241 1,394 1,394 12,194 3b.1.1.8 Cold Machine Shop 396 83 479 479 3,785 3b.1.1.9 Communication 4 1 5 5 44 3b.1.1.10 Condensate Polishingtrechnical Support 870 182 1,052 1,052 9,300 3b. 1. 1. 11 Containment Penetration Area 686 143 829 829 6,565 3b. 1. 1.12 Discharge Structure 937 196 1,133 1,133 8,321 3b.1.1.13 Fabrication Shop 120 25 145 145 1,223 3b. 1. 1.14 Fire Pump House 5 1 6 6 55 3b. 1.1. 15 Hazardous Waste Storage Facility 39 8 48 48 430 3b. 1. 1. 16 Intake Structure 5,309 1,108 6,416 6,416 46,364 3b. 1. 1.17 Maintenance Shop 365 76 441 441 3,444 3b. 1. 1. 18 Miscellaneous Structures 64 13 77 77 673 3b. 1. 1. 19 NPO Permanent Warehouse 1,367 285 1,652 1,652 14,093 3b.1.1.20 Ponds 2 0 2 2 24 3b.1.1.21 Portable Fire Pump & Fuel Cart 1 0 2 2 14 3b.1.1.22 Pretreatment 10 2 12 12 108 3b. 1. 1.23 Radwaste Storage 1,777 371 2,147 2,147 17,854 3b. 1. 1.24 Radwaste Storage Facility (Additional) 49 10 59 59 662 3b.1.1.25 Rotor Warehouse 847 177 1,024 1,024 9,938 3b.l.L26 Security 344 72 416 416 3,944 3b.l.L27 Security Buildings (additional) 53 11 65 65 722 3b.l.L28 Simulator 413 86 499 499 4,191 3b.1. L29 Steam Generator Storage Facility 909 190 1,099 1,099 8,888 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 26 of 28 Table E-8 Diablo Canyon Unit 2 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume -C::::-I:-a-s-s-:A---:C:::':I::..a;::;ss:.:B:::::-..:....::;":'C::::la:::sc:.s::..C:::---:G~T=C:::-:::C;-- Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours Demolition of Remaining Site Buildings (continued) 3b.1.1.30 Telephone Terminal 3 1 3 3 28 3b.1.l.31 Turbine 5,538 1,156 6,694 6,694 57,744 3b.1.1.32 Turbine Pedestal 1,318 275 1,594 1,594 11,300 3b.1.1.33 Vehicle Maintenance 34 7 41 41 367 3b.l.l.34 Waste Water Holding & Treatment Facility 23 5 27 27 238 3b.1.1.35 Fuel Handling 1,858 388 2,245 2,245 16,750 3b.L1 Totals 43,321 9,039 52,360 52,360 429,552 Site Closeout Activities 3b.1.2 Grade & landscape site 2,758 575 3,333 3,333 4,587 3b.1.3 Final report to NRC 98 20 119 119 668 3b.l Subtotal Period 3b Activity Costs 46,079 98 9,635 55,812 119 55,693 434,139 668 Period 3b Additional Costs 3b.2.1 Backfill Structures & Remove Concrete Rubble 35,142 7,332 42,474 42,474 160,418 3b.2.2 Breakwater Demolition and Removal 41,893 14,568 56,461 56,461 128,379 46,649 3b.2.3 Cofferdam Construction and Teardown 478 100 578 578 4,004 3b.2A Concrete Crushing 9,113 5 1,902 11,020 11,020 37,775 3b.2.5 Disposal of Galbestos Siding 317 66 383 383 3b.2.6 Disposition of Mobile Barriers 1,318 275 1,593 1,593 4,362 3b.2.7 Soil/ Sediment Control Plant Area 1,052 219 1,272 1,272 10,271 3b.2 Subtotal Period 3b Additional Costs 88,996 321 24,463 113,781 113,781 345,209 46,649 Period 3b Collateral Costs 3b.3.1 Small tool allowance 1,107 231 1,338 1,338 3b.3 Subtotal Period 3b Collateral Costs 1,107 231 1,338 1.338 Period 3b Period*Dependent Costs 3bA.1 Insurance 525 73 598 598 3bA.2 Property taxes 410 57 467 467 3bA.3 Heavy equipment rental 7,347 1,533 8,880 8,880 3bA,4 Plant energy budget 286 60 346 346 3bA.5 NRC ISFSI Fees 348 48 396 396 3bA.6 Emergency Planning Fees 885 123 1,009 1,009 3bA.7 Spent Fuel Transfer* Pool or ISFSI to DOE 2,474 516 2,990 2,990 3bA.8 ISFSI Operating Costs 111 23 134 134 3bA.9 Security Staff Cost 5,569 1,162 6,731 0 5,452 1,279 102,023 3bA.10 DOC Staff Cost 14,111 2,944 17,055 17,055 136,891 3bA.ll Utility Staff Cost 7,357 1,535 8,892 1,778 7,113 87,197 3bA Subtotal Period 3b Period*Dependent Costs 7,347 32,075 8,075 47,497 0 12,824 34,673 326,112 3b.0 TOTAL PERIOD 3b COST 143,529 32,495 42,404 218,428 119 12,824 20(j,485 779,348 373,428 PERIOD 3c - Fuel Storage Operations/Shipping Period 3c Direct Decommissioning Activities Period 3c Period*Dependent Costs 3cA.1 Insurance 2,251 313 2,564 2,564 3cA.2 Property taxes 1,758 245 2,002 2,002 3cA.3 Plant energy budget 3cAA NRC ISFSI Fees 1,492 208 1,700 1,700 3cA.5 Emergency Planning Fees 3,797 528 4,326 4,326 3cA.6 Spent Fuel Transfer* Pool or ISFSI to DOE 11,163 2,329 13,492 13,492 3cA.7 ISFSI Operating Costs 475 99 574 574 3cA.8 Security Staff Cost 19,444 4,057 23,501 23,501 299,083 3eA.9 Utility Staff Cost 6,393 1,334 7,727 7,727 74,881 3eA Subtotal Period 3c Period*Dependent Costs 46,773 9,113 55,886 55,886 373,964 3c.0 TOTAL PERIOD 3c COST 46,773 9,113 55,886 55,886 373,964 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 27 of 28 Table E-8 Diablo Canyon Unit 2 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d. 1. 1.1 Vessel & Internals GTCC Disposal 2,500 9,179 2,263 13,942 13,942 1,785 350,510 3d. 1.1 Totals 2,500 9,179 2,263 13,942 13,942 1,785 350,510 3d.1 Subtotal Period 3d Activity Costs 2,500 9,179 2,263 13,942 13,942 1,785 350,510 Period 3d Period-Dependent Costs 3d.4.1 Insurance 10 11 11 3d.4.2 Property taxes 8 9 9 3d.4.3 Plant energy budget 3d.4.4 NRC ISFSI Fees 6 1 7 7 3d.4.5 ISFSI Operating Costs 2 0 3 3 3d.4.6 Security Staff Cost 85 18 103 103 1,311 3d.4.7 Utility Staff Cost 28 6 34 34 328 3d.4 Subtotal Period 3d Period-Dependent Costs 139 27 167 167 1,640 3d.0 TOTAL PERIOD 3d COST 2,500 9,179 139 2,290 14,109 13,942 167 1,785 350,510 1,640 PERIOD 3e - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 3e Additional Costs 3e.2.1 ISFSI License Termination 40 6 14 393 622 284 1,359 1,359 1,305 108,721 4,535 360 3e.2 Subtotal Period 3e Additional Costs 40 6 14 393 622 284 1,359 1,359 1,305 108,721 4,535 360 Period 3e Collateral Costs 3e.3.1 Small tool allowance 0 3e.3 Subtotal Period 3e Collateral Costs 0 Period 3e Period-Dependent Costs 3e.4.1 Insurance 3e.4.2 Property taxes 55 8 62 62 3e.4.3 Heavy equipment rental 136 28 164 164 3e.4.4 Plant energy budget 3e.4.5 NRC ISFSI Fees 94 13 107 107 3e.4.6 Security Staff Cost 61 13 74 74 1,901 3e.4.7 Utility Staff Cost 163 34 197 197 1,901 3e.4 Subtotal Period 3e Period-Dependent Costs 136 373 96 605 605 3,803 3e.0 TOTAL PERIOD 3e COST 177 6 14 393 995 380 1,965 1,965 1,305 108,721 4,535 4,163 PERIOD 3f - ISFSI Site Restoration Period 3f Direct Decommissioning Activities Period 3f Additional Costs 3£.2.1 ISFSI Demolition and Site Restoration 1,371 27 292 1,689 1,689 15,387 80 3£.2.2 ISFSI Area Soil f Sediment Control 16 3 20 20 2,568 3£.2 Subtotal Period 3f Additional Costs 1,387 27 295 1,709 1,709 17,955 80 Period 3f Collateral Costs 3£.3.1 Small tool allowance 20 4 24 24 3£.3 Subtotal Period 3£ Collateral Costs 20 4 24 24 Period 3f Period-Dependent Costs 3£.4.1 Insurance 3£.4.2 Property taxes 28 4 32 32 3f.4.3 Heavy equip;nent rental 54 11 65 65 3£.4.4 Plant energy budget 3£.4.5 Security Staff Cost 11 2 14 14 349 3£.4.6 Utility Staff Cost 69 14 83 83 784 3f.4 Subtotal Period 3f Period-Dependent Costs 54 108 32 193 193 1,133 TLG Services, Inc.

Diablo Canyon Power Plant Document POl-1648-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 28 of 28 Table E-8 Diablo Canyon Unit 2 DECON 60 Year Decommissioning Cost Estimate (Thousands of 2011 Dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial! Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt.,Lbs. Manhours Manhours 3f.0 TOTAL PERIOD 3f COST 1,461 134 331 1,926 1,926 17,955 1,213 PERIOD 3 TOTALS 145,167 2,506 14 9,572 80,537 54,518 292,313 14,061 72,767 205,485 1,305 1,785 459,231 801,837 754,408 TOTAL COST TO DECOMMISSION 13,073 218,618 31,702 14,580 124,490 719,711 280,493 1,402,667 1,034,886 148,940 218,842 586,268 1,732 574 1,785 51,548,980 1,686,102 6,746,173 TOTAL COST TO DECOMMISSION WITH 25% CONTINGENCY: $1,402,667 thousands of 2011 dollars TOTAL NRC LICENSE TERMINATION COST IS 73.78% OR: $1,034,886 thousands of 2011 dollars SPENT FUEL MANAGEMENT COST IS 10.62% OR: $148,940 thousands of 2011 dollars NON-NUCLEAR DEMOLITION COST IS 15.6% OR: $218,842 thousands of 2011 dollars TOTAL SCRAP METAL REMOVED: 77,728 Tons TOTAL CRAFT LABOR REQUIREMENTS: 1,686102 Man-hours End Notes:

nla - indicates that this activity not charged as decommissioning expense.

a - indicates that this activity performed by decommissioning staff.

0- indicates that this value is less than 0.5 but is non-zero.

a cell containing" - " indicates a zero value TLG Services, Inc.

OUTGOING CORRESPONDENCE SCREEN (Remove prior to NRC submittal)

Document: PG&E Letter DCL-13-033

Subject:

. Decommissioning Funding Report for Diablo Canyon Power Plant Units 1 and 2 File Location: S:\RS\CLERICAL\DCLS - FINAL\2013 DECOMMISSIONING FUNDING REPORT\DCL-13-033.DOCX FSAR Update Review Utilizing the guidance in XI3.ID2, does the FSAR Update need to be revised? Yes [] No [X]

If "Yes", submit an FSAR Update Change Request in accordance with X13.ID2 (or if this is an LAR, process in accordance with WG-9)

Commitment #1 Statement of Commitment: None Clarification: None ARorNCR AEorACT Tracking Document:

NAME ORGANIZA TION CODE Assigned To:

FIRM OR TARGET DUE DATE:

Commitment Type:

YES OR NO IF YES, WHICH? (E.G., 2R9, 1R10, ETC.)

Outage Commitment?

YES OR NO IF YES, LIST THE IMPLEMENTING DOCUMENTS (IF KNOWN)

PCD Commitment?

YES OR NO IF YES, LIST PCD NUMBER (e.g., T35905, etc.)

Duplicate of New NCR Commitment in PCD?

YES OR NO 1. IF YES, LIST PCD NUMBER, AND

2. CLARIFY TO CLERICAL HOW COMMITMENT TO BE REVISED Old PCD Commitment being changed?

Target Submittal Date: -------------------

Firm Submittal Date: N/AD

~tL ... &oex.

Date

1. References & bases identified for factual information.
2. Statements requiring verification identified in form RS-3. N/A W
3. Licensing Submittal Compliance Map (RS-13) completed. N/A~
4. Outgoing Correspondence Screen (RS-2) completed & commitments captured per XI4.ID1.
5. RS Manager's concurrence for release obtained and Phase 1 of RS-16 completed.
6. Record of Review Checklist completed & signed per X11.ID1 and Phase 2 of RS-16 completed.
7. Clerical reviews completed. Draft # - ' - - {!b.i I~

Draft # _ _ _1_ _- Final (on signatory letterhead) ~

8. Peer Review Checklist (RS-4) completed.
9. 'PSRC Review and Signoff. Meeting # _ _ _ _ _ _ _ _ __ N/A }l1
10. Provide this checklist, the final letter & enclosures, Record of Review Checklist, &

Outgoing Correspondence Screen to signatory. -4'~

  • For FIRM submittals, was 2 days met? Yes ~ No D N/A D ~
11. Will entire submittal, including enclosures, be placed in RS & ACTS libraries and

. FileNet? Yes~ No D .

If NO, complete form RS-1A, indicating where the enclosures, etc. will be maintained.

12. Indicate RMS access level. Check one box only.

flXI Reg Regular

[ ] "D'! Proprietary (Ref. 10 CFR 2.390)

[ ] "8" Personnel Record or Security Related (Access Level S in SUPNO)

[ ] "A" Security Safeguards Information (SSI)

  • RMS folder name _ _ _ _ _ _ _ _ _ _ _ _ _ _ __

(Le., LAR, LER, etc.)

  • Put in envelope with a copy of this form attached on outside and put in SSI safe in RS Manager's office.
13. Scan and place a .pdf copy of this checklist (including RS-1A, if applicable), the submittal & enclosures, Record of Review Checklist, & the Outgoing Correspondence Screen as one document in RMS E-Docs (or the SSI safe, if applicable).
14. Deliver this checklist (including RS-1A, if applicable), original of signed submittal &

enclosures, Outgoing Correspondence Screen, & Record of Review Checklist to RS I Admin. Staff. <f , 1J

15. Tracking documents have been updated for submittal completion N/A;W-
16. Verify commitment entry on SAP within 15 days. _ _ _ 1--_ _-1 RS-1 Rev. 3 - 1/22/13

SUBMITTAL PROCESSING CHECKLIST - Supplement Identify the enclosures, etc. (e.g., proprietary, personal, or SSI) that will NOT be filed in the RS and ACTS libraries, or EDMS, and where the. actual documents will be maintained.

Examples: . NRC 396 forms are retained by Learning Services and the DCPP (Personal information) Medical Facility. The diskettes are maintained by Radiation Protection.

(Diskette)

Entire Document The complete proprietary version of this document is available in the PG&E Law Department in San Francisco.

Item Location RS-1A

Statements Requiring Verification PG&E Letter:

Subject:

[Title]

The purpose of this form .is to document departmental concurrence regarding the accuracy and completeness of information provided for PG&E submittals to the Re.

X11.ID1 requires that all statements requiring verification be verified for submi al completeness and accuracy.

As defined in XI3.ID1, "Facility License Change Process," a statement r uJrlng verification is a regulatory submittal statement that is not contained in quality document and in which the statement is:

1) ' Central to the issue.
2) Could influence a reviewer in the conduct 0
3) Is intended to have a net positive effect.
4) Is not speculative or opinionated.

Reviewer Name St tem Requiring Verification SAPN-T~Sk Department/Group Docume ting (Print) ement or SAPN-Task)

Verificat on RS-3 Rev. 0

Guidelines for Identifying Verifiable Statements

1) The lead licensing engineer should evaluate the content of the submittal remembering the definition of a verifiable statement and make a judgment as to the materiality of each statement.

Statements which should be verified will usually meet the following criteria:

a) The statement is central to the issue.

b) The statement could influence a reviewer in the conduct of regulatory responsibilities.

c) The statement is intended to have a net positive effect.

d) The statement is not speculative or opinionated.

2) The lead licensing engineer should annotate (e.g., underline, high-light, bold text, uniquely number, etc.) "verifiable statements" in the submittal. The lead licensing engineer must be careful to distinguish between a factual statement and a verifiable statement. For instance, it is usual for submittals to contain an introductory section describing the history of the issue in order to place the submittal in context for the reader. While the historical perspective is factual, it is usually not material and could be omitted without affecting the purpose of the submittal. The lead licensing engineer should make an effort to identify the core of the PG&E's position that a regulatory reviewer would use to decide an issue.
3) Certain statements, while factual, may also be excluded from the verification process. These include:

a) Statements describing intermediate steps of logical progression if the endpoint must depend on the preceding steps for instance, "PG&E submitted a request to change the TS governing operation with DGs out-of-service. The changes were approved in Amendment 5 to the operating license." In this case the submittal of a TS change request must occur in order to obtain an amended TS. It is NOT necessary to verify the TS change request submittal. Only the endpoint (the newTS) should be verified.

b) Statements of opinion for instance, "Based on the preceding discussion, PG&E believes that..."

While opinions may be important to the resolution of an issue, they are a matter of interpretation.'

The key supporting facts leading to the opinion, however, may require verification.

c) Statements that simply reiterate statements contained in NRC documents.

d) Statements of planned actions, although material, do not have to be verified when a separately controlled commitment tracking process is in place.

4) A paragraph that has more than one material aspect may be broken down to ensure that each individual aspect is verified. Several verification references may be required to address a single paragraph.

RS-3 Rev. 0

Licensing Submittal Compliance Map

'G&E Letter:

Subject:

{Title]

The purpose of this form is to document compliance mapping to all aspects of the current licensing basis All compliance mapping and technical information providectto licensing for use in the LAR shall be verified or accuracy by the nuclear generation section providing the information.

  • XI3.ID1, "Facility License Cha e Process," contains the procedural requirements for this form.

Licensing Licensing Means of Establishing Complia ce

  • SAPN-Task Source Requirement Compliance to Imple nting Document Licensin Re uirement . Do ment Rev. 0

DCPP Form 69-20996 (06/25/12) XI1.1D1 Attachment 2 Page 1 of 1 Regu latory Submittal - Record of Review Checklist D N/A Primary Reviewers Comments Resolved Yes No Yes No

~

1 Lead Technical Reviewer: ~ D D 1

Lead Technical Manager: D D D D Director Review: 1, 2 ~ D ~ D 1

Submittal Lead Management: ~ D ~ D 1

Independent Technical Reviewer: 12 D ~ D Cross Discipline R'eviewer(s): D D D D D Operations: D D D D D Maintenance: D D D D D Engineering: D D D D D Site Services: D D D D D Quality: D D D D

~ D ~ D D D D D D D D D D D D M ~ D ~ D

~ ~ D ~ D m Ikr D H D Secondary Reviewers Comments Resolved Yes No Yes No g ~~8 StnieS ~

D D

D

~

D D

D D D D D D D D D D D D D D D D D D D D D D D D D D I have reviewed and verified that all statements of fact in the submittal are correct.

(Mark N/A and attach a copy of e-mail if documentation of ITR is electronic.)3 $'N/A Independent Technical Reviewer(s): Se.e., cxtlnc1e&. emC1\' ) fuM Date: ~

r,R. ~ 3J~?h'3 e. 11:13 Date: ~

r I Concurrence has been received from prim ry reviewers. Technical comments have been resolved.

The independent tech reviewer has rev.Y..,I;*Il:i"'YoIIS~'C\~ (n - ditorial) changes to the sUbmitta~ I Lead Licensing Engineer: --~~~~~iilCi~~ '-..IooL..._________ Date: ~?jI3 These reviewers are considered to be the minimum required primary reviewers for submittals not containing an oath or affirmation or requiring PSRC review. Regulatory Services Manager approval is required to not obtain the review from any of these reviewers.

2 Director review is satisfied if the submittal undergoes a review by the PSRC.

Attach a table of "statements requiring verification" and ITR approvals.

69-20996.DOC 0625.1421

Landreth, Will From: Winterton, Brooke Sent: Wednesday, March 27, 2013 11 :23 AM To: Landreth, Will Cc: Kapus, Robert

Subject:

RE: Phase 2 Review: Decommissioning Funding Report for DCPP Units 1 & 2

Will, I have reviewed and verified that all statements of fact in the submittal are correct for the DCPP Units 1 & 2 Report.
Thanks, Brooke From: Landreth, Will Sent: Tuesday, March 26, 2013 3:46 PM To: Summy, Jeff; Corippo, Peter; Baldwin, Thomas (DCPP); Padovan, Mark; Post, Jennifer (Law); Winterton, Brooke; Kapus, Robert Cc: Sokolsky, David

Subject:

Phase 2 Review: Decommissioning Funding Report for DCPP Units 1 & 2

All, lAW X11.1D1, Section 5.2.7, please participate in this Phase 2 Review by reviewing the attached documents and providing your comments back to me no later than 1600, tomorrow, Wednesday, March 27, 2013. This Decommissioning Funding Report is due to the NRC on April 1, 2013 in accordance with 10 CFR 50.75(f).

Please provide your comments or state that you have no comments.

Brooke, Please perform an ITR (contact me with any questions about this role). Once complete and you are satisfied with the technical content of this submittal, please simply reply with the following statement if you have no comments: "I have reviewed and verified that all statements of fact in the submittal are correct." Otherwise, please reply with your comments.

Lead Technical Reviewer:

Bob Kapus Lead Technical Manager:

Tom Baldwin Independent Technical Reviewer:

Brooke Winterton Primary Reviewers:

Jeff Summy Tom Baldwin 1

Mark Padovan Jennifer Post Peter Corippo Secondary Reviewers:

David Sokolsky Will Landreth Thank you all very much for your time and support for the 2013 DCPP Decommissioning Funding Report!

Will Landreth Regulatory Services Engineer Pacific Gas & Electric Company Diablo Canyon Power Plant PO Box 56, Mailstop 104j5j23A Avila Beach, CA 93424 Phone: 805-545-6980 Email: wrl8@pge.com 2

PEER REVIEW CHECKLIST LICENSING SUBMITTAL (To be performed on final draft only.)

  • 1 PG&E letter No. (e.g.,Oel, Oil, etc.) peL 033 ITEM DESCRIPTION INITIALS*

Cover Letter Correct signatory letterhead (Ref. X11.1D2)

Names spelled correctly and agree with attachments; Full names used for signatory & cc list; right people listed Title correct I'

Letter number verified against outgoing correspondence log Letter number appears on all pages Enclosure(s) - the word is correctly placed on the cover letter if required.

All pages numbered, except first page Date correct and appears on all pages (month, day, and year)

Address and docket number(s) correct Text reviewed for obvious errors TS and/or 10 CFR references correct If affidavit required or NOV response, verify Law Department has reviewed All Submittals T ext reviewed for obvious errors Revision bars included (if applicable)

TS and/or 10 CFR references correct References to other documents correct (e.g., DCLs, FSAR, etc.)

Submittal addresses the specific regulation requirements Enclosures labeled and signed as appropriate Outgoing Letter number and title correct Corres pondence FSAR Update Review - one box checked.

Screen (RS-2) Commitment implemented before or after LA receipt (LARs/RAls only)

Commitment(s) quoted verbatim (& clarifications made if needed)

Tracking Document - SAPN / Task / Order / Operation ,I Assigned To - Name & Organization Code Commitment Type - Firm or Target & Due Date I Outage Commitment - Y or N indicator & Applicable Outage PCD Commitment - Y or N indicator & Implementing Documents tV LER Forms LER number correct; consistent with cover letter (NRC Form 366) LER number & docket number(s) on first & remaining pages (NRC Form 366a) Title consistent with cover letter & Outgoing Correspondence Screen (RS-2) .

Dates correct on first page header (month, day, & year)

Dates & times consistent with 10 CFR 50.72 ENS reports made Dates & times consistent with other source documents I I

Dates & times consistent between abstract and narrative Page numbers correct & all pages accounted for Abstract word count lAW NRC Form 366 IEEE 803 codes entered and correct " V Procedure Submittals Procedure revision numbers current using EDMS (e.g., EPIP)

Filing Instructions Filing instructions clear (Per RS-1 A, if applicable)

ROR Checklist Record of Review Checklist completed and signed Final Draft All discrepancies resolved with Lead Licensing Engineer

  • Enter N/A where not applicable.

I have reviewed this submittal for t e items initialed above. This submittal is ready for the signatory.

(}1/ZS/;)

Date RS-4

OUTGOING CORRESPONDENCE SCREEN (Remove prior to NRC submittal)

Document: PG&E Letter DCL-13-0XX

Subject:

Decommissioning Funding Report for Diablo Canyon Power Plant Units 1 and 2 File Location: S:\RS\CLERICAL\DCLS - DRAFn2013 DECOMMISSIONING FUNDING REPORT\DCL-13-0XX, DECOMMISSIONING FUNDING REPORT.DOCX FSAR Update Review Utilizing the guidance in XI3.ID2, does the FSAR Update need to be revised? Yes [] No [X]

If "Yes", submit an FSAR Update Change Request in accordance with X13.ID2 (or if this is an LAR, process in accordance with WG-9)

Commitment #1 Statement of Commitment: None Clarification: None ARorNCR AEorACT Tracking Document:

NAME ORGANIZA TlON CODE Assigned To:

FIRM OR TARGET DUE DATE:

Commitment Type:

YES OR NO IF YES, WHICH? (E.G.,2R9, 1R10, ETC.)

Outage Commitment?

YES OR NO IF YES, LIST THE IMPLEMENTING DOCUMENTS (IF KNOWN)

PCD Commitment?

YES OR NO IF YES, LIST PCD NUMBER (e.g., T35905, etc.)

Duplicate of New NCR Commitment in PCD?

YES OR NO 1. IF YES, LIST PCD NUMBER, AND

2. CLARIFY TO CLERICAL HOW COMMITMENT TO BE REVISED Old PCD Commitment being changed?
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