DCL-09-021, Submittal of Decommissioning Funding Report
| ML090990542 | |
| Person / Time | |
|---|---|
| Site: | Diablo Canyon  |
| Issue date: | 03/31/2009 |
| From: | Becker J Pacific Gas & Electric Co |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| DCL-09-021 | |
| Download: ML090990542 (34) | |
Text
Pacific Gas and Electric Company James R. Becker Diablo Canyon Power Plant Site Vice President Mail Code 104/5/601 P. 0. Box 56 Avila Beach, CA 93424 805.545.3462 Internal: 691.3462 March 31, 2009 Fax: 805.545.6445 PG&E Letter DCL-09-021 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Docket No. 50-275, OL-DPR-80 Docket No. 50-323, OL-DPR-82 Diablo Canyon Units 1 and 2 Decommissioning Funding Report for Diablo Canyon Power Plant Units 1 and 2
Dear Commissioners and Staff:
PG&E is submitting the decommissioning fund report for Diablo Canyon Power Plant (DCPP) Units 1 and 2, pursuant to the requirements of 10 CFR 50.75(f).
Diablo Canyon Units 1 and 2 At the end of calendar year 2008, the market value of the DCPP Units 1 (3411 MWt) and 2 (3411 MWt) decommissioning trust fund Market value was $612.5 million and
$843.6 million respectively. Based on the site-specific decommissioning cost estimate prepared by TLG Services, Inc. and adjusted per the Nuclear Decommissioning Cost Triennial Proceeding (NDCTP) Decision 07-01-003 from the California Public Utilities Commission (CPUC), PG&E is confident that the DCPP Units 1 and 2 decommissioning trust fund balance in 2024 and 2025 will meet the minimum NRC decommissioning amount of $540.8 million (2009 dollars) for each unit that was calculated pursuant to the requirements specified in 10 CFR 50.75(c).
Supportinq Cost Estimates Based on site-specific cost estimates prepared by TLG Services, Inc., and adjustments as a result of the NDCTP Decision 07-01-003, PG&E has estimated that the decommissioning costs are approximately $679.5 million for DCPP Unit 1 and
$720.9 million for Unit 2 in 2009 dollars. These costs do not include site restoration of the facilities ($256.4 million) nor spent fuel management costs after shutdown of Units 1 and 2 ($261.0 million).
To assure that sufficient funds will be available for decommissioning, PG&E has established separate external sinking trust fund accounts for DCPP Units 1 and 2.
A member of the STARS (Strategic Teaming and Resource Sharing) Alliance Callaway
- Comanche Peak
- Diablo Canyon -
Palo Verde
- San Onofre South Texas Project
- Wolf Creek
Document Control Desk PG&E Letter DCL-09-021
~
March 31, 2009 6
Page 2 Supporting Enclosures Supporting documentation for this report is included as Enclosures 1 through 3. provides decommissioning funding status information in a format suggested by NEI and the NRC. provides information on the escalation of the required decommissioning funding amounts from 1986 dollars to 2009 dollars. As required by 10 CFR 50.75(c)(2),
and using NUREG 1577, "Standard Review Plan on Power Reactor Licensee Financial Qualifications and Decommissioning Funding Assurance," Revision 1 and NUREG 1307, "Report on Waste Burial Charges," Revision 13, the information includes escalation factors for energy, labor, and waste burial costs. provides the TLG Services, Inc. decommissioning cost estimate report prepared in August 2005 for PG&E for DCPP Units 1 and 2. The TLG Services, Inc.
cost estimate has then been adjusted to reflect the costs in 2009 dollars per CPUC Decision 07-01-003 by applying the escalation factors; adjusting the burial costs of Class A Low Level Radioactive Waste to $248 per cubic foot; and the contingency to 35 percent. The report provides cost estimates for decommissioning of both nuclear and non-nuclear facilities, including the Independent Spent Fuel Storage Installation.
There are no Regulatory commitments in this letter. Should you have any questions in regard to this document pies feel free to call Robert Kapus at (707) 444-0810.
SSinc* rely, James R. Becker Site Vice President Enclosures cc/enc:
Elmo E. Collins, Regional Administrator, NRC Region IV Michael A. Dusaniwskyj, US NRC Headquarters Michael S. Peck, NRC Senior Resident Inspector Alan B. Wang, NRC Project Manager Diablo Distribution INPO A member of the STARS (Strategic Teaming and Resource Sharing) Alliance Callaway
- Comanche Peak
- Diablo Canyon
- Palo Verde o San Onofre
- South Texas Project
- Wolf Creek PG&E Letter DCL-09-021 NRC Decommissioning Funding Status Report Diablo Canyon Power Plant - Units 1 (3411 MWt) & 2 (3411 MWt)
As provided in 10 CFR 50.75(f)(1), each power reactor licensee is required to report to the NRC on a calendar year basis, beginning on March 31, 1999, and every 2 years thereafter, on the status of its decommissioning funding for each reactor or share of reactor it owns.
- 1. The minimum decommissioning fund estimate, pursuant to 10 CFR 50.75 (b) and (c)1
$ in Millions Value in January 2009 dollars Unit 1 $ 540.8 Unit 2 $ 540.8
- 2. The amount accumulated at the end of the calendar year preceding the date of the report for items included in 10 CFR 50.75 (b) and (c). (Alternatively, the total amount accumulated at the end of the calendar year preceding the date of the report can be reported here if the cover letter transmitting the report provides the total estimate and indicates what portion of that estimate is for items not included in 10 CFR 50.75'(b) and (c)).
Market Value (December 2008 dollars)
Unit 1 $
612.5 Unit2 $
843.6
- 3. A schedule of the annual amounts remaining to be collected; for items in 10 CFR 50.75 (b) and (c). (Alternatively, the annual amounts remaining to be collected can include items beyond those required in 10 CFR 50.75 (b) and (c) if the cover letter transmitting the report provides a total cost estimate and indicates what portion of that estimate is for items that are not included in 10 CFR 50.75 (b) and (c). (See item 6 of this enclosure describing the collection of additional funds)
Unit 1 amount remaining
$ 5.5
($1.8 million for 3 years beginning 2007)
Unit 2 amount remaining
$0 The NRC formulas in section 10 CFR 50.75(c) include only those decommissioning costs incurred by licensees to remove a facility or site safely from service and reduce residual radioactivity to levels that permit: (1) release of the property for unrestricted use and termination of the license; or (2) release of the property under restricted conditions and termination of the license. The cost of dismantling or demolishing nonradiological systems and structures is not included in the NRC decommissioning cost estimates. The costs of managing and storing spent fuel on site until transfer to DOE are not included in the cost formulas.
PG&E Letter DCL-09-021
- 4. The assumptions used regarding escalation in decommissioning cost, rates of earnings on decommissioning funds (anticipates that the portfolio of each trust will be gradually converted to a more conservative all income portfolio beginning in 2020 for Unit 1 and Unit 2), and rates of other factors used in funding projections; Escalation in decommissioning costs Rate of Return on Qualified Trust Unit 1 2006 Rate of Return on Qualified Trust Unit 1 2007 Rate of Return on Qualified Trust Unit 1 2008 Rate of Return on Qualified Trust Unit 1 2009 Rate of Return on Qualified Trust Unit 1 2010 Rate of Return on Qualified Trust Unit 1 2011 Rate of Return on Qualified Trust Unit 1 2012 Rate of Return on Qualified Trust Unit 1 2013 Rate of Return on Qualified Trust Unit 1 2014 Rate of Return on Qualified Trust Unit 1 2015 Rate of Return on Qualified Trust Unit 1 2016 Rate of Return on Qualified Trust Unit 1 2017 Rate of Return on Qualified Trust Unit 1 2018 Rate of Return on Qualified Trust Unit 1 2019 Rate of Return on Qualified Trust Unit 1 2020 Rate of Return on Qualified Trust Unit 1 2021 Rate of Return on Qualified Trust Unit 1 2022 Rate of Return on Qualified Trust Unit 1 2023 Rate of Return on Qualified Trust Unit 1 2024 Rate of Return on Qualified Trust Unit 1 (Post 2025)
Rate of Return on Qualified Trust Unit 2 2006 Rate of Return on Qualified Trust Unit 2 2007 Rate of Return on Qualified Trust Unit 2 2008 Rate of Return on Qualified Trust Unit 2 2009 Rate of Return on Qualified Trust Unit 2 2010 Rate of Return on Qualified Trust Unit 2 2011 Rate of Return on Qualified Trust Unit 2 2012 Rate of Return on Qualified Trust Unit 2 2013 Rate of Return on Qualified Trust Unit 2 2014 Rate of Return on Qualified Trust Unit 2 2015 Rate of Return on Qualified Trust Unit 2 2016 Rate of Return on Qualified Trust Unit 2 2017 Rate of Return on Qualified Trust Unit 2 2018 Rate of Return on Qualified Trust Unit 2 2019 Rate of Return on Qualified Trust Unit 2 2020 Rate of Return on Qualified Trust Unit 2 2021 Rate of Return on Qualified Trust Unit 2 2022 Rate of Return on Qualified Trust Unit 2 2023 4.50 percent 6.02 percent 5.85 percent 5.73 percent 5.64 percent 5.57 percent 5.53 percent 5.49 percent 5.47 percent 5.45 percent 5.44 percent 5.43 percent 5.42 percent 5.41 percent 5.41 percent 5.18 percent 4.86 percent 4.59 percent 4.38 percent 4.23 percent 4.13 percent 6.02 percent 5.85 percent 5.73 percent 5.64 percent 5.57 percent 5.52 percent 5.49 percent 5.46 percent 5.45 percent 5.43 percent 5.42 percent 5.42 percent 5.41 percent 5.41 percent 5.17 percent 4.86 percent 4.59 percent 4.38 percent PG&E Letter DCL-09-021 Rate of Return on Qualified Trust Unit 2 2024 Rate of Return on Qualified Trust Unit 2 (Post 2025) 4.23 percent 4.13 percent
- 5. Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v).
NONE
- 6. Any modifications to a licensee's current method providing financial assurance occurring since the last submitted report.
NONE
- 7. Any material changes to trust agreements.
NONE
- 8. CPUC Submittal in 2009 Dollars in Millions Total Unit 1 (Decommission 2024)
Scope Excluded from NRC calculations Total NRC Decommissioning Costs Total Unit 2 (Decommission 2025)
Scope Excluded from NRC calculations Total NRC Decommissioning Costs 865.0 185.5 679.5
$1,052.8 331.9 720.9
2009 Decommisioning Estimate Ul Nuclear Regulatory Commission Estimate of Decommission Costs for PWR DCPP Unit 1 in 2009 DCPP PWR (millions)
Jan 1986 Estimate 105 PG Letter DCL-09-021 Escalated to 1999 Escalated to 2000 Escalated to 2001 Escalated to 2002 Escalated to 2003 Escalated to 2004 Escalated to 2005 Escalated to 2006 Escalated to 2007 Escalated to 2008 Escalated to 2009
$118.2 (Table 2.1 in NUREG 1307 Rev 10 has no value for 1999 Burial)
(No Submittal Required)
$387.2 ($396.7 in 2001 Submittal)
(No Submittal Required)
$405.6 ($404.8 in 2003 Submittal)
(No Submittal Required)
$467.3 ($427.2 in 2005 Submittal)
(No Submittal Required)
$495.8 ($494.8 in 2007 Submittal)
(No Submittal Required)
$540.8 Jan 1986 based on 10 CFR 50.75 (c) Table of minimum amounts BWR based on minimum 1, 200 MWt = ($.104 + (.009xMWt)) million per unit Jan 1986 based on 10 CFR 50.75 (c) Table of minimum amounts PWR Greater than or equal to 3400 MWt = $105 million per unit between 1200 MWt and 3400 MWt (for PWR less than 1200 MWt, use P=1200MWt $75+0.0088P)
Page 1
2009 Decommissiong Estimate U2 PG&E Letter DCL-09-021 Nuclear Regulatory Commission Estimate of Decommission Costs for PWR DCPP Unit 2 in 2009 DCPP PWR (millions)
Jan 1986 Estimate 105 Escalated to 1999 Escalated to 2000 Escalated to 2001 Escalated to 2002 Escalated to 2003 Escalated to 2004 Escalated to 2005 Escalated to 2006 Escalated to 2007 Escalated to 2008 Escalated to 2009
$118.2 (Table 2.1 in NUREG1307 Rev 10 has no value for 1999 Burial)
(No Submittal Required)
$387.2 ($396.7 in 2001 Submittal)
(No Submittal Required)
$405.6 ($404.8 in 2003 Submittal)
(No Submittal Required)
$467.3 ($427.2 in 2005 Submittal)
(No Submittal Required)
$495.8 ($494.8 in 2007 Submittal)
(No Submittal Required)
$540.8 Jan 1986 based on 10 CFR 50.75 (c) Table of minimum amounts BWR based on minimum 1, 200 MWt =. ($104 + (.009xMWt)) million per unit Jan 1986 based on 10 CFR 50.75 (c) Table of minimum amounts PWR Greater than or equal to 3400 MWt = $105 million per unit between 1200 MWt and 3400 MWt (for PWR less than 1200 MWt, use P=1200MWt $75+0.0088P)
Composite Escalation PG&E Letter DCL-09-021 Calculating Overall Escalation Rate PWR L (Labor)
E (Energy)
B (Burial)
Jan-86 Jan-99 Jan-00 Jan-01 Jan-02 Jan-03 Jan-14 Jan-05 Jan-0B Jan-B7 Jan-08 Jan-09 Weight (1) 1.0000 1.5624 1.6370 1.7183 1.7862 1.8630 1.9521 2.02g0 2.0724 2.1465 2.2207 2.2557 0.65 1.0000 0.8499 1.0297 1.1850 0
S9909 1.2027 1.2164 1.4656 1.8306 1.795B 2.3262 1.7B40 0.13 1.0000 0.0000 10.8039 10.9840 11.1633 11.3430 13.0733 13.3951 13.7247 14.0626 15.0364 15.6922 0.22 PWR Combined Escalation Rate for:
Jan-86 Jan-99 Jan-0S Jan-01 Jan-02 Jan-03 Jan-04 Jan-S5 Jan-OS Jan-07 Jan-S8 Jan-09 1.0000 1.1260 3.5748 3.6874 3.7458 3.8628 4.3031 4.4505 4.6044 4.7224 5.0538 5.1504 (1) from NUREG 1307 Revision 12, Report on Waste Burial Charges, Section 2 Summary, Page 3... where A, B, and C are the fractions ofthe total 19t6 dollar costs that are attributable to labor (0.65), energy (0.13), and burial (0.22), respectively, and sum to 1.5.
(2) Jan-01, Jan-03, Jan-05 and Jan-07 B (Burial) value in this table see calculation notes in Development of B Component spreadsheet Page 1
Development of E Component Calculation of Energy Escalation Factor - REFERENCE NUREG-1307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)
REBASED TO 1986 = 100 PPI for Fuels &
PPI for Light PPI for Fuels &
PPI for Light Related Products Fuel Oils Related Products Fuel Oils (1982 = 100)
(1982=100)
(1986 = 100)
(1986=100)
(P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils PWR wt =
0.58 PWR wt =
0.42 PG&E Letter DCL-09-021 Jan-86 Feb-86 Mar-86 Apr-86 May-86 Jun-86 Jul-86 Aug-86 Sep-86 Oct-86 Nov-86 Dec-86 Jan-87 Feb-87 Mar-87 Apr-87 May-87 Jun-87 Jul-87 Aug-87 Sep-87 Oct-87 Nov-87 Dec-87 Jan-88 Feb-88 Mar-88 Apr-88 May-88 Jun-88 Jul-88 Aug-88 Sep-88 Oct-88 Nov-88 Dec-88 Jan-89 Feb-89 Mar-89 Apr-89 May-89 Jun-89 Jul-89 Aug-89 Sep-89 Oct-89 114.2 115.0 114.4 113.7 114.1 115.3 116.2 116.3 116.3 113.0 112.7 112.3 110.3 109.8 110.2 109.9 111.8 113.9 116.2 115.7 115.5 111.0 109.2 109.6 108.8 109.0 109.0 109.1 108.9 117.2 118.2 118.3 118.5 114.2 109.2 110.5 112.0 112.0 112.3 112.4 113.6 119.8 122.2 122.4 122.5 117.2 82.0 62.4 51.3 49.8 47.0 44.7 36.4 40.1 46.3 43.1 43.5 45.6 51.4 53.1 49.7 52.0 53.3 55.1 56.3 59.4 56.8 59.3 61.2 58.1 54.8 51.5 49.7 53.3 54.3 50.6 46.9 46.8 45.9 42.3 47.2 50.6 54.9 54.0 57.3 61.5 57.5 53.3 52.7 53.5 59.3 64.0 1.0000 1.0070 1.0018 0.9956 0.9991 1.0096 1.0175 1.0184 1.0184 0.9895 0.9869 0.9834 0.9658 0.9615 0.9650 0.9623 0.9790 0.9974 1.0175 1.0131 1.0114 0.9720 0.9562 0.9597 0.9527 0.9545 0.9545 0.9553 0.9536 1.0263 1.0350 1.0359 1.0377 1.0000 0.9562 0.9676 0.9807 0.9807 0.9834 0.9842 0.9947 1.0490 1.0701 1.0718 1.0727 1.0263 1.0000 0.7610 0.6256 0.6073 0.5732 0.5451 0.4439 0.4890 0.5646 0.5256 0.5305 0.5561 0.6268 0.6476 0.6061 0.6341 0.6500 0.6720 0.6866 0.7244.
0.6927 0.7232 0.7463 0.7085 0.6683 0.6280 0.6061 0.6500 0.6622 0.6171 0.5720 0.5707 0.5598 0.5159 0.5756 0.6171 0.6695 0.6585 0.6988 0.7500 0.7012 0.6500 0.6427 0.6524 0.7232 0.7805 Energy Escalation Factor (E) for PWR (Diablo Canyon) 1.0000 0.9037 0.8438 0.8325 0.8202 0.8145 0.7766 0.7961 0.8278 0.7947 0.7952 0.8039 0.8235 0.8296 0.8142 0.8245 0.8408 0.8607 0.8785 0.8919 0.8775 0.8675 0.8681 0.8542 0.8333 0;8174 0.8082 0.8271 0.8312 0.8544 0.8405 0.8405 0.8369 0.7967 0.7964 0.8204 0.8500 0.8454 0.8638 0.8859 0.8715 0.8814 0.8906 0.8957 0.9259 0.9230 Page 1
Development of E Component Calculation of Energy Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)
REBASED TO 1986 = 100 PPI for Fuels &
PPI for Light PPI for Fuels &
PPI for Light Related Products Fuel Oils Related Products Fuel Oils (1982 = 100)
(1982=100)
(1986 = 100)
(1986=100)
(P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils Nov-89 113.5 64.4 0.9939 0.7854 Dec-89 114.2 68.1 1.0000 0.8305 Jan-90 114.9 85.3 1.0061 1.0402 Feb-90 115.0 59.4 1.0070 0.7244 Mar-90 115.4 60.4 1.0105 0.7366 Apr-90 115.1 61.0 1.0079 0.7439 May-90 117.0 58.4 1.0245 0.7122 Jun-90 123.9 53.0 1.0849 0.6463 Jul-90 124.4 51.6 1.0893 0.6293 Aug-90 124.6 72.3 1.0911 0.8817 Sep-90 125.0 87.3 1.0946 1.0646 Oct-90 121.2 104.8 1.0613 1.2780 Nov-90 120.2 98.9 1.0525 1.2061 Dec-90 118.9 89.3 1.0412 1.0890 Jan-91 124.2 82.9 1.0876 1.0110 Feb-91 124.3 74.3 1.0884 0.9061 Mar-91 124.3 61.6 1.0884 0.7512 Apr-91 124.7 60.0 1.0919 0.7317 May-91 128.2 59.6 1.1226 0.7268 Jun-91 132.6 57.6 1.1611 0.7024 Jul-91 134.5 58.1 1.1778 0.7085 Aug-91 133.8 62.1 1.1716 0.7573 Sep-91 133.8 65.4 1.1716 0.7976 Oct-91 128.3 67.6 1.1235 0.8244 Nov-91 123.1 71.0 1.0779 0.8659 Dec-91 125.1 62.2 1.0954 0.7585 Jan-92 125.9 54.4 1.1025 0.6634 Feb-92 125.3 57.3 1.0972 0.6988 Mar-92 125.8 56.0 1.1016 0.6829 Apr-92 124.8 59.0 1.0928 0.7195 May-92 128.5 62.1 1.1252 0.7573 Jun-92 134.8 65.4 1.1804 0.7976 Jul-92 135.6 64.6 1.1874 0.7878 Aug-92 135.1 63.3 1.1830 0.7720 Sep-92 135.9 65.6 1.1900 0.8000 Oct-92 131.2 68.2 1.1489 0.8317 Nov-92 125.5 64.2 1.0989 0.7829 Dec-92 126.7 59.4 1.1095 0.7244 Jan-93 127.1 59.0 1.1130 0.7195 Feb-93 126.4 60.4 1.1068 0.7366 Mar-93 126.7 63.2 1.1095 0.7707 Apr-93 126.8 62.4 1.1103 0.7610 May-93 127.5 62.6 1.1165 0.7634 Jun-93 136.9 60.8 1.1988 0.7415 Jul-93 137.1 57.0 1.2005 0.6951 Aug-93 137.2 54.4 1.2014 0.6634 Sep-93 137.6 59.3 1.2049 0.7232 Oct-93 131.9 65.4 1.1550 0.7976 PG&E Letter DCL-09-021 Energy Escalation Factor (E) for PWR (Diablo Canyon) 0.9063 0.9288 1.0205 0.8883 0.8955 0.8970 0.8933 0.9007 0.8961 1.0031 1.0820 1.1523 1.1170 1.0613 1.0554 1.0119 0.9468 0.9406 0.9564 0.9685 0.9807 0.9976 1.0145 0.9979 0.9889 0.9539 0.9181 0.9299 0.9257 0.9360 0.9707 1.0196 1.0196 1.0104 1.0262 1.0157 0.9662 0.9477 0.9477 0.9513 0.9672 0.9636 0.9682 1.0067 0.9883 0.9754 1.0026 1.0049 Page 2
Development of E Component Calculation of Energy Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)
REBASED TO 1986 = 100 PPI for Fuels &
PPI for Light PPI for Fuels &
PPI for Light Related Products Fuel Oils Related Products Fuel Oils (1982 = 100)
(1982=100)
(1986 = 100)
(1986=100)
(P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils Nov-93 126.3 61.6 1.1060 0.7512 Dec-93 126.0 51.4 1.1033 0.6268 Jan-94 126.2 51.5 1.1051 0.6280 Feb-94 125.9 57.5 1.1025 0.7012 Mar-94 125.8 56.2 1.1016 0.6854 Apr-94 125.4 54.7 1.0981 0.6671 May-94 126.0 54.7 1.1033 0.6671 Jun-94 133.5 54.1 1.1690 0.6598 Jul-94 134.5 56.3 1.1778 0.6866 Aug-94 134.5 57.5 1.1778 0.7012 Sep-94 134.9 57.7 1.1813 0.7037 Oct-94 129.1 57.7 1.1305 0.7037 Nov-94 127.0 58.8 1.1121 0.7171 Dec-94 127.4 54.7 1.1156 0.6671 Jan-95 127.6 54.7 1.1173 0.6671 Feb-95 128.0 53.3 1.1208 0.6500 Mar-95 128.3 54.3 1.1235 0.6622 Apr-95 126.4 57.1 1.1068 0.6963 May-95 130.2 59.1 1.1401 0.7207 Jun-95 135.3 55.8 1.1848 0.6805 Jul-95 136.6 53.5 1.1961 0.6524 Aug-95 136.5 55.6 1.1953 0.6780 Sep-95 133.7 58.2 1.1708 0.7098 Oct-95 131.4 57.8 1.1506 0.7049 Nov-95 127.6 59.5 1.1173 0.7256 Dec-95 127.7 60.6 1.1182 0.7390 Jan-96 127.9 62.6 1.1200 0.7634 Feb-96 127.1 59.7 1.1130 0.7280 Mar-96 127.8 63.5 1.1191 0.7744 Apr-96 129.-1 74.7 1.1305 0.9110 May-96 135.0 72.0 1.1821 0.8780 Jun-96 137.5 62.8 1.2040 0.7659 Jul-96 136.0 64.3 1.1909 0.7841 Aug-96 136.2 66.5 1.1926 0.8110 Sep-96 136.2 73.4 1.1926 0.8951 Oct-96 131.2 79.7 1.1489 0.9720 Nov-96 127.1 76.5 1.1130 0.9329 Dec-96.
127.7 76.1 1.1182 0.9280 Jan-97 128.3 73.7 1.1235 0.8988 Feb-97 128.1 72.3 1.1217 0.8817 Mar-97 128.2 65.2 1.1226 0.7951 Apr-97 127.3 65.3 1.1147 0.7963 May-97 129.7 64.2 1.1357 0.7829 Jun-97 135.1 60.8 1.1830 0.7415 Jul-97 135.9 57.8 1.1900 0.7049 Aug-97 134.7 61.5 1.1795 0.7500 Sep-97 136.0 60.4 1.1909 0.7366 Oct-97 130.1 64.8 1.1392 0.7902 PG&E Letter DCL-09-021 Energy Escalation Factor (E) for PWR (Diablo Canyon) 0.9570 0.9032 0.9047 0.9339 0.9268 0.9171
'0.9201 0.9551 0.9715 0.9776 0.9807 0.9512 0.9462 0.9272 0.9282 0.9231 0.9297 0.9344 0.9640 0.9730 0.9678 0.9780 0.9771 0.9634 0.9528 0.9590 0.9702 0.9513 0.9743 1.0383 1.0544 1.0200 1.0201 1.0323 1.0677 1.0746 1.0373 1.0383 1.0291 1.0209 0.9851 0.9810 0.9876 0.9976 0.9863 0.9991 1.0001 0.9927 Page 3
Development of E Component Calculation of Energy Escalation Factor-REFERENCE NUREG-1307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)
REBASED TO 1986 = 100 PPI for Fuels &
PPI for Light PPI for Fuels &
PPI for Light
.Related Products Fuel Oils Related Products Fuel Oils (1982 = 100)
(1982=100)
(1986 = 100)
(1986=100)
(P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils Nov-97 127.9 65.8 1.1200 0.8024 Dec-97 128.3 59.4 1.1235 0.7244 Jan-98 127.4 54.1 1,1156 0.6598 Feb-98 127.2 52.0 1.1138 0.6341 Mar-98 126.7 48.3 1.1095 0.5890 Apr-98 126.4 50.2 1.1068 0.6122 May-98 129.2 50.0 1.1313 0.6098 Jun-98 133.8 46.3 1.1716 0.5646 Jul-98 134.8 45.0 1.1804 0.5488 Aug-98 135.2 44.0 1.1839 0.5366
.Sep-98 135.2 48.3 1.1839 0.5890 Oct-98 130.4 47.4 1.1419 0.5780 Nov-98 127.6 46.2 1.1173 0.5634 Dec-98 126.6 38.8 1.1086 0.4732 Jan-99 126.1 40.9 1.1042 0.4988 Feb-99 125.5 38.2 1.0989 0.4659 Mar-99 125.5 42.8 1.0989 0.5220 Apr-99 125.2 52.5 1.0963 0.6402 May-99 127.4 52.6 1.1156 0.6415 Jun-99 131.0 52.4 1.1471 0.6390 Jul-99 133.9 58.7 1.1725 0.7159 Aug-99 133.9 63 1.1725 0.7683 Sep-99 134.1 67.6 1.1743 0.8244 Oct-99
.129.5 65.5 1.1340 0.7988 Nov-99 127.5 71.3 1.1165 0.8695 Dec-99 126.5 72.9 1.1077 0.8890 Jan-00 126.8 75.3 1.1103 0.9183 Feb-00 126.7 87.9 1.1095 1.0720 Mar-00 126.7 89.7 1.1095 1.0939 Apr-00 126.8 83.1 1.1103 1.0134 May-00 128.6 82.9 1.1261, 1.0110 Jun-00 133.6 86.2 1.1699 1.0512 Jul-00 136.2 88.7 1.1926 1.0817 Aug-00 137.4 91.6 1.2032 1.1171 Sep-00 137.8 110.1 1.2067 1.3427 Oct-00 134.1 108.6, 1.1743 1.3244 Nov-00 130.9 108.4 1.1462 1.3220 Dec-00 132.7 100.6 1.1620 1.2268 Jan-01 136.4 96.1 1.1944 1.1720 Feb-01 136.4 91.6 1.1944 1.1171 Mar-01 136.5 83.1 1.1953 1.0134 Apr-01 135.1 86.2 1.1830 1.0512 May-01 136.2 94.2 1.1926 1.1488 Jun-01 148.4 90.2 1.2995 1.1000 Jul-01 149.5 81.3 1.3091 0.9915 Aug-01 148.9 83.2 1.3039 1.0146 Sep-01 148.2 93 1.2977 1.1341 Oct-01 143.8 76.8 1.2592 0.9366 PG&E Letter DCL-09-021 Energy Escalation Factor (E) for PWR (Diablo Canyon) 0.9866 0.9559 0.9241 0.9124 0.8909 0.8991 0.9123 0.9167 0.9151 0.9120 0.9340 0.9051 0.8847 0.8417 0.8499 0.8330 0.8566 0.9048 0.9165 0.9337 0.9807 1.0027 1.0273 0.9932 1.0127 1.0159 1.0297 1.0937 1.1029 1.0696 1.0777 1.1200 1.1461 1.1670 1.2638 1.2373 1.2200 1.1892 1.1850 1.1619 1.1189 1.1277 1.1742 1.2157 1.1757 1.1824 1.2290 1.1237 C,
Page 4
Development of E Component Calculation of Energy Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)
REBASED TO 1986 = 100 PPI for Fuels &
PPI for Light PPI for Fuels &
PPI for Light Related Products Fuel Oils Related Products Fuel Oils (1982 = 100)
(1982=100)
(1986 = 100)
(1986=100)
(P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils Nov-01 137.3 70.5 1.2023 0.8598 Dec-01 136.9 56.6 1.1988 0.6902 Jan-02 136.3 58.3 1.1935 0.7110 Feb-02 135.4 59.6 1.1856 0.7268 Mar-02 135.7 69.1 1.1883 0.8427 Apr-02 135.4.
76.4 1.1856 0.9317 May-02 137.9 75 1.2075 0.9146 Jun-02 143.6 71.4 1.2574 0.8707 Jul-02 144.9 75.5 1.2688 0.9207 Aug-02 145.0 77.9 1.2697 0.9500 Sep-02 145.8 89.5 1.2767 1.0915 Oct-02 140.0 95.1 1.2259 1.1598 Nov-02 139.5 82.8 1.2215 1.0098 Dec-02 139.6 84.6 1.2224 1.0317 Jan-03 140.3 95.7 1.2285 1.1671 Feb-03 140.6 120.4 1.2312 1.4683 Mar-03 143.3 128.9 1.2548 1.5720 Apr-03 144.3 98.3 1.2636 1.1988 May-03 145.1 85.5 1.2706 1.0427 Jun-03 148.3 87.2 1.2986 1.0634 Jul-03 151.6 90.1 1.3275 1.0988 Aug-03 151.3 94.1 1.3249 1.1476 Sep-03 152.0 88.2 1.3310 1.0756 Oct-03 147.4 97.8 1.2907 1.1927 Nov-03 142.7 93.0 1.2496 1.1341 Dec-03 142.9 95.8 1.2513 1.1683 Jan-04 143.1 106.8 1.2531 1.3024 Feb-04 143.1 100.8 1.2531 1.2293 Mar-04 143.1 107.8 1.2531 1.3146 Apr-04 143.1 115.2 1.2531 1.4049 May-04 144.2 116 1.2627 1.4146 Jun-04 152.4 111.5 1.3345 1.3598 Jul-04 152.2 119.3 1.3327 1.4549 Aug-04 154.0 131.1 1.3485 1.5988 Sep-04 154.0 136.8 1.3485 1.6683 Oct-04 145.8 161.7 1.2767 1.9720 Nov-04 144.9 153.6 1.2688 1.8732 Dec-04 146.2 133.8 1.2802 1.6317 Jan-g5 148.9 138.5 1.3039 1.6890 Feb-05 148.0 146 1.2960 1.7805 Mar-05 148.1 169.4 1.2968 2.0659 Apr-05 148.7 170.9 1.3021 2.0841 May-05 151.1 165.3 1.3231 2.0159 Jun-05 159.7 180.6 1.3984 2.2024 Jul-05 162.1 186.2 1.4194 2.2707 Aug-05 162.5 194.5 1.4229 2.3720 Sep-05 162.8 209.9 1.4256 2.5598 Oct-05 159.5 252.0 1.3967 3.0732 PG&E Letter DCL-09-021 Energy Escalation Factor (E) for PWR (Diablo Canyon) 1.0584 0.9852 0.9909 0.9929 1.0431 1.0790 1.0845 1.0950 1.1226 1.1354 1.1989 1.1981 1.1326 1.1423 1.2027 1.3308 1.3880 1.2364 1.1749 1.1998 1.2314 1.2504 1.2237 1.2495 1.2011 1.2164 1.2738 1.2431 1.2789 1.3168 1.3265 1.3451 1.3840 1.4536 1.4828 1.5687 1.5227 1.4278 1.4656 1.4995 1.6198 1.6306 1.6141 1.7361 1.7770 1.8215 1.9019 2.1008 Page 5
Development of E Component Calculation of Energy Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.2 Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 03/06/09) and WPU0543 Industrial Electric Power (as of 03/06/09)
REBASED TO 1986 = 100 PPI for Fuels &
PPI for Light PPI for Fuels &
PPI for Light Related Products Fuel Oils Related Products Fuel Oils (1982 = 100)
(1982=100)
(1986 = 100)
(1986=100)
(P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils Nov-05 161.1 1991 1.4107 2.4280 Dec-05 161.4 193.6 1.4133 2.3610 Jan-06 167.0 191.8 1.4623 2.3390 Feb-06 168.6 190.0 1.4764 2.3171 Mar-06 167.4 199.2 1.4658 2.4293 Apr-06 169.6 221.9 1.4851 2.7061 May-06 170.8 231.4 1.4956 2.8220 Jun-06 181.2 238.1 1.5867 2.9037 Jul-06 181.9 231.6 1.5928 2.8244 Aug-06 180.2 241.4 1.5779 2.9439 Sep-06 181.0 203.1 1.5849 2.4768 Oct-06 171.2 198.1 1.4991 2.4159 Nov-06 167.2 198.2 1.4641 2.4171 Dec-06 167.8 200.4 1.4694 2.4439 Jan-07 171.9 180.0 1.5053 2.1951 Feb-07 175.7 191.5 1.5385 2.3354 Mar-07 172.1 215.1 1.5070 2.6232 Apr-07 173.1 231.8 1.5158 2.8268 May-07 179.2 225.3 1.5692 2.7476 Jun-07 186.7 222.4 1.6349 2.7122 Jul-07 187.0 237.8 1.6375 2.9000 Aug-07 187.6 225.5 1.6427 2.7500 Sep-07 188.4 238.9 1.6497 2.9134 Oct-07 182.7 243.3 1.5998 2.9671 Nov-07 180.3 288.2 1.5788 3.5146 Dec-07 180.0 266.7 1.5762 3.2524 Jan-08 181.9 273.8 1.5928 3.3390 Feb-08 180.0 280.2 1.5762 3.4171 Mar-08 183.1 339.6 1.6033 4.1415 Apr-08 185.2 352.5 1.6217 4.2988 May-08 189.5 384.9 1.6594 4.6939 Jun-08 191.9 410.5 1.6804 5.0061 Jul-08 196.1 423.8 1.7172 5.1683 Aug-08 197.1 343.9 1.7259 4.1939 Sep-08 195.9 335.1 1.7154 4.0866 Oct-08 191.6 282.4 1.6778 3.4439 Nov-08 189.4 220.2 1.6585 2.6854 Dec-08 190.6 165.5 1.6690 2.0183 Jan-09 188.9 161.0 1.6541 1.9634 PG&E Letter DCL-09-021 Energy Escalation Factor (E) for PWR (Diablo Canyon) 1.8380 1.8113 1.8306 1.8295 1.8705 1.9979 2.0527 2.1398 2.1101 2.1516 1.9595 1.8842 1.8643 1.8787 1.7950 1.8732 1.9758 2.0664 2.0641 2.0873 2.1677 2.1078 2.1805 2.1741 2.3919 2.2802 2.3262 2.3494 2.6693 2.7461 2.9339 3.0772 3.1666 2.7625 2.7113 2.4195 2.0898 1.8157 1.7840 Oct 08 through Jan 09 are Preliminary Values from PPI Indices Page 6
Development of L Component PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor-REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)
Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)
Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.
Employment Cost Indust West Region Labor Private Industry Escalation (1989=100)
Factor Jan-86 89.8 1.00000 Feb-86 Mar-86 Apr-86 90.8 1.01114 May-86 Jun-86 Jul-86 91.2 1.01559 Aug-86 Sep-86 Oct-86 91.6 1.02004 Nov-86 Dec-86 Jan-87 92.5 1.03007 Feb-87 Mar-87 Apr-87 92.6 1.03118 May-87 Jun-87 Jul-87 93.7 1.04343 Aug-87 Sep-87 Oct-87 94.1 1.04788 Nov-87 Dec-87 Jan-88 95.4 1.06236 Feb-88 Mar-88 Apr-88 96.3 1.07238 May-88 Jun-88 Jul-88 97 1.08018 Aug-88 Sep-88 Oct-88 97.7 1.08797 Nov-88 Dec-88 Jan-89 98.8 1.10022 Feb-89 Mar-89 Apr-89 100 1.11359 May-89 Jun-89 Jul-89 101 1.12472 Aug-89 Page 1
Development of L Component PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CLU20100000002401 (as of 03/06/09)
Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)
Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.
Employment Cost Indust West Region Labor Private Industry Escalation (1989=100)
Factor Sep-89 Oct-89 101.8 1.13363 Nov-89 Dec-89 Jan-90 103.3 1.15033 Feb-90 Mar-90 Apr-90 104.5 1.16370 May-90 Jun-90 Jul-90 105.6 1.17595 Aug-90 Sep-90 Oct-90 106.3 1.18374 Nov-90 Dec-90 Jan-91 107.5 1.19710 Feb-91 Mar-91 Apr-91 108.9 1.21269 May-91 Jun-91 Jul-91 110 1.22494.
Aug-91 Sep-91 Oct-91 110.9 1.23497 Nov-91 Dec-91 Jan-92 111.9 1.24610 Feb-92 Mar-92 Apr-92 112.9 1.25724 May-92 Jun-92 Jul-92 114.1 1.27060 Aug-92 Sep-92 Oct-92 114.9 1.27951 Nov-92 Dec-92 Jan-93 116.2 1.29399 Feb-93 Mar-93 Apr-93 116.4 1.29621 Page 2
Development of L Component PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)
Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)
Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.
Employment Cost Indust West Region Labor Private Industry Escalation (1 989=1 00)
Factor May-93 Jun-93 Jul-93 117.8 1.31180 Aug-93 Sep-93 Oct-93 118.1 1.31514 Nov-93 Dec-93 Jan-94 119.4 1.32962 Feb-94 Mar-94 Apr-94 120.5 1.34187 May-94 Jun-94 Jul-94 121.3 1.35078 Aug-94 Sep-94 Oct-94 121.7 1.35523 Nov-94 Dec-94 Jan-95 122.6 1.36526 Feb-95 Mar-95 Apr-95 123.4 1.37416 May-95 Jun-95 Jul-95 123:9 1.37973 Aug-95 Sep-95 Oct-95 125 1.39198 Nov-95 Dec-95 Jan-96 125.9 1.40200 Feb-96 Mar-96 Apr-96 127.3 1.41759 May-96 Jun-96 Jul-96 128.3 1.42873 Aug-96 Sep-96 Oct-96 128.9 1.43541 Nov-96 Dec-96 Page 3
Development of L Component PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor-REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)
Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)
Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.
Employment Cost Indust West Region Labor Private Industry Escalation (1989=100)
Factor Jan-97 130.3 1.45100 Feb-97 Mar-97 Apr-97 131.4 1.46325 May-97 Jun-97 Jul-97 132.5 1.47550 Aug-97 Sep-97 Oct-97 133.4 1.48552 Nov-97 Dec-97 Jan-98 135.2 1.50557 Feb-98 Mar-98 Apr-98 136.6 1.52116 May-98 Jun-98 Jul-98 138.5 1.54232 Aug-98 Sep-98 Oct-98 140 1.55902 Nov-98 Dec-98 Jan-99 140.3 1.56236 Feb-99 Mar-99 Apr-99 142.1 1.58241 May-99 Jun-99 Jul-99 143.3 1.59577 Aug-99 Sep-99 Oct-99 144.7 1.61136 Nov-99 Dec-99 Jan-00 147 1.63697 Feb-00 Mar-00 Apr-00 148.8 1.65702 May-00 Jun-00 Jul-00 150.8 1.67929 Aug-00 Page 4
Development of L Component PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)
Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)
Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.
Employment Cost Indust West Region Labor Private Industry Escalation (1989=100)
Factor Sep-00 Oct-00 151.8 1.69042 Nov-00 Dec-00 Jan-01 154.3 1.71826 Feb-01 Mar-01 Apr-01 156 1.73719 May-01 Jun-01 Jul-01 157.6 1.75501 Aug-01 Sep-01 Oct-01 159.4 1.77506 Nov-01 Dec-01 Jan-02 160.4 1.78619 Feb-02 Feb-02 Mar-02 Apr-02 162.9 1.81403 May-02 Jun-02 Jul-02 163.8 1.82405 Aug-02 Sep-02 Oct-02 165 1.83742 Nov-02 Dec-02 Jan-03 167.3 1.86303 Feb-03 Mar-03 Apr-03 169.5 1.88753 May-03 Jun-03 Jul-03 171.4 1.90869 Aug-03 Sep-03 Oct-03 172.2 1.91759 Nov-03 Dec-03 Jan-04 175.3 1.95212 Feb-04 Mar-04 Page 5
Development of L Component PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor - REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)
Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)
Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.
Employment Cost Indust West Region Labor Private Industry Escalation (1989=100)
Factor Apr-04 176.8 1.96882 May-04 Jun-04 Jul-04 178.1 1.98330 Aug-04 Sep-04 Oct-04 179.0 1.99332 Nov-04 Dec-04 Jan-05 181.4 2.02004 Feb-05 Mar-05 Apr-05 183.3 2.04120 May-05 Jun-05 Jul-05 184 2.04900 Aug-05 Sep-05 Oct-05 (Note 1) 100 2.06000 Nov-05 Dec-05 Jan-06 100.6 2.07236 Feb-06 Mar-06 Apr-06 101.8 2.09708 May-06 Jun-06 Jul-06 102.5 2.11150 Aug-06 Sep-06 Oct-06 103 2.12180 Nov-06 Dec-06 Jan-07 104.2 2.14652 Feb-07 Mar-07 Apr-07 104.9 2.16094 May-07 Jun-07 Jul-07 105.7 2.17742 Aug-07 Sep-07 Oct-07 106.5 2.19390 Nov-07 Page 6
Development of L Component PG&E Letter DCL-09-021 Calculation of Labor Escalation Factor-REFERENCE NUREG-1 307, REVISION 13, SECTION 3.1 Using Regional Indices SERIES ID: CIU20100000002401 (as of 03/06/09)
Jan '86 adjusted to reflect NUREG 1307 Rev 13 Scaling Factor for West Labor (Pg 7)
Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.
Employment Cost Indust West Region Labor Private Industry Escalation (1989=100)
Factor Dec-07 Jan-08 Feb-08 Mar-08 Apr-08 May-08 Jun-08 Jul-08 Aug-08 Sep-08 Oct-08 Nov-08 Dec-08 Jan-09 107.8
.108.4 109.3 109.4 109.5 2.22068 2.23304 2.25158 2.25364 2.25570 Jan-07 is an estimate based on the difference between Jul-06 and Oct-06 added to Oct-06 Page 7
Development of B Component PG&E Letter DCL-09-021 Development of Burial Escalation Developed from NUREG-1307 Revision 13 Table 2.1 "VALUES OF B SUB-X AS A FUNCTION OF LLW BURIAL SITE, WASTE VENDOR, AND YEAR" (Summary for non-Atlantic Compact)
Revised to Bx Values for Generic LLW Disposal Site (Assumed to be same as that provided for the Atlantic Compact for lack of a better alternative at this time.
PWR Burial Costs (South Carolina) 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 1.678 2.007 2.494 11.408 11.873 12.824 12.771 15.852 15.886 18.129 18.732 19.034 21.937 22.477 23.030 23.597 25.231 26.332 PWR Restated to 1986 = 100 1.0000 1.1961 1.4863 6.7986 7.0757 7.6424 7.6108 9.4470 9.4672 0.0000 10.8039 0.0000 11.1633 11.3430 13.0733 13.3951 13.7247 14.0626 15.0364 15.6922 Table 2.1 Note ('c) From 7/1/95 through 6/30/2000 access was allowed for all states except North Carolina. Effective 7/1/2000 rates are based on whether a waste generator is or is not a member of the Atlantic Compact.
2001 has no information in NUREG-1307 Rev 12. 2001 is an estimate that is calculated by applying the average % change between 2000 and 2002 and adding to the 2000 base 2003 has no information in NUREG-1307 Rev 12. 2003 is an estimate that is calculated by applying the average % change between 2002 and 2004 and adding to the 2002 base 2005 has no information in NUREG-1307 Rev 12. 2005 is an estimate that is calculated by applying the average % change between 2004 and 2006 and adding to the 2004 base.
2007 has no information in NUREG-1307 Rev 12. 2007 is an estimate that is calculated by applying the average.% change between 2004 and 2006 and adding to the 2006 base.
2009 has no information in NUREG-1 307 Rev 13. 2009 is an estimate that is calculated by applying the average % change between 2006 and 2008 and adding to the 2008 base.
Page 1
NOTE: Toatls oay not sout de to rounding Eýnosure 3 PG&E Letter DCL-09m-oo TABLE C-2 TABLE C-2 DIABLO CANYON POWER PLANT UNIT 2 DIABLO CANYON POWER PLANT UNIT I DECON DECOKM0ISSIONING COST ESTIMATE DECON DECO]THISSIONING COST ESTIMATE fTlouo.ode of D000 eolff)
(Thooanod. of 20M0 Dt1oa-)
Off-Site LoRjw Off-Site LLRW
-Dte a
Tr...or Prui Disosl Other Cortin~0 Totl eA CleFnR'oe P-cteoetoe Tr-aosport Psooceete.
I-tspoet]
Other-Coonttnoen Torel PEROtD Ela -Shlootootl TrasZle211112't Period la Siredt Secormlsslonino Aebrto 1o.t.1 Preoar erelimlnary decomm sionino 1 cost ta.t 2 Notiation of Cessaoon of Operetione le.. 3 Remoefunte rce meaerial 1 e1. 4 N oalion ot Parterranent efuelnin-te.t.5 Deactivate otant sosfer & oroesasott-e tat.l Preoareend u.mitt P-OAR la.1.7 Reew olant oos & secs.
Ia.t.8 Perform detailed rd surve ta.1.9 Estimate c-oroduct Inventorv oar1.10 End orodut description a,
Detailed!
b-orodoo Inventoro 1a.1.12 Defineraror wortoeeoueroo let112 Perfo-SER and EA eIa.14 Perforrn Site-So*edriCost Study la.1.15 ProJseubItL Ucense Temnrutoon Plan 1at,1,,
Receie NRC aeoeroal of lenetmireo Plan Aioillty SNeeifieations fat.17.t Plant & temeoreno faides fa,.t17.2 Plant svesterr
,1.a1, 7.3 NSSS DSaontrnlnaoton Fluos ta 1.17.4 Reacor intemaso Ia.1.17.5 Rea7to Fi eoss
,e..17.6 liotliooal slield re.t.17.7 Steam oeratom ea.f
,7.8 Reinforced corcrete la.1.17.9 Main ToobN fea1.17.10 Main Condenners la.1.17.11 Plan'trstreS es
& dldinos te.1.07.12 Waste mna nrerrt to.t.17.13 F1eilit&sRoe closertd ta.1.17 Totol Plannn o & Site Prewaratoes Oa.10 PreoarediSmantlineoserooeno Oa.59 Plant erep.
& teme. svcs to 1O sDIosn
-ater clear,-u scostem at.121 RiooclnaContCntd Eo.d.osernoleto.
toa1.
2 Prure -Wsioolners
& otainers fa.,
Subtotal Period fo Amct Costs Pedod to Additioto Costs 1:.2.1 Soent Fuel Pool tilation 1a.2 Subtotal Period la Actotv Coste Perod la Pertod-Deeoenet Cots 1::44:1 In
-~ac ta,2 Prooeroretes I a.4o3 Heath ohrdsossuolles a,.44 Heam e-io*nent rental 1 a.45 DSslosal of DAW oeneartd ae4d6 Plan teenoubodot 1a.4.7 NRC ISFSI Fees l..4 8 NRC Fee la.4.9 Emeroenoo Plaoios Fe a.4.t0 Senor Foal Pool O&M la.4.11 f
SFS1 ODeoano Costs 1,.4.12 ISFSl Fxe'd COT la.4.13 Scuoto Staff Cosl 1,.4.14 UtiNity Steff Coot 1a.4 Suioteta 1a.4 Perlod-Seveodent Costs 1a.0 TOTAL PERIOD t a COST Period 1b Direct Deoommlssaionb ActSMis Detailed Wook ProeedUres 51.1t.1 Poant vstems 1b.1.I.2 NSSS Decontamination Flush b t.t.3 Reactor iternoals Ib,1,1,4 Rmonaenis buildinds tbtt.1,S CRDcoooinaasoemlbo lbi,1,6 CRD) houinqs & ICl tubes tt1.t7 Cncore on ostmmntooaon I
1.t.8 Reomoroossol 1b.1.f 9 Fac61ty Oloeout Sb.1.1
.0 Missoe helds lb.1.1.11 Bft 8o1cal sheld lb.1.1.12 Steameatooo 1bA.,113 Reinforced conorete lb.1.1.14 Maln Turbine 1b.1,.115 Main Cof'Klrse 55 8
63 0
4 2
e 150 9
210 3
a2*2 42 6
24O2 55 a
6 316 47 343 27130 20 t15 r
210 32 242 0:,
X3/4 17f 26 198 M7 31 m9 '
175 26
-02 21 3
2,742 99 9t45 273 41 31 2,142 3J7 2,455 130 20 15t
-0>
000 m 7
3 091-o,0 0
07 3
07 13 20 151t S
9`1 29 2
38 6
- 59l 235 l83.705 O
15 11t 2,14101 363 2.782 -
0 0
u 4 ~0 t 0 -~
5" lO0 2,048 3.7 2.35514 jT(0>0 o
6 52 0
w1
-7,59 1t135 81705 5225 784 60. 0 09 >>
A$g*
5.225 704 WADS~
0 1.S3t 13 0.644 88 9
970
§*:1tt 164 42 2f54[
W5 125 125 265 27 m
1.097 110 1,26 12 193 1
l!5()
37 217 2,267 340 07[
2 6D7 20600 3.103 237oo 000 104 2.268 4.244 33.354 es o
j 4
164 41.063 6.163 48.068,
35 42 6
Q 405 16 121 57 109 472 6
48f 42 6
48 42 S
Q8 153 23 76 19 3
22 194 29 2
42 0
48 Si 10 75 66 10 75*
w w
64 22 86 98 34 132 225 79 308
'49 17 66 49 17 66 64 22 8l 367 12m 496 151 53 204 2244 85 329 200 70 270 241 84 325 203 71 274 24 9
33 347
- 12.
469 317 111.
428 24 9
33 152 53 205 78 27 1OS 20 7
27 20 7
27 152 53 2D5 225 79 3044 44 15 O0 1.849 647 2,496 117 41 158 2.. 811 984 3.794 69 24 93 2.380 833 3.212
-6 21 82 8,7N4 3.078 11.872 287 383
-5 2
E70 5
2 70 5
2 333 445 778 778 6.071 2.125 8,106
-6.071 2.125 8.196 1,779 623 2,401 102 36 138 117 450 156 601 6
33 48 187 1.127 394 1.522 145 145 I306 10 416
- 1.25 446 1.721 1.0t W
352 1.325 145 51 196 290 102 3m 0
2.634 922 3.556 24.M37
- 8. 413 32,450 6
3 130 32.845 11f817 45.578 6
3 130 47.711 17.020 65,648 231 81 312 49 17 (66 471 165 635 w6 23 89 w54 192 740 49 17 66 49 17 66 178 62 240 58 2m 78 22 8
30 58" 20 78 225 79 304 49 17
-66 77 27 104 77 27 104
NOTE: Toto mS y not sone due to rounding Ese 3
P59E Leter DCL.9-Wo TABLE C-2 DIABLO CANYON POWER PLANT UNIT 2 DECON DECOMMISSIONING COST ESTIMATE (Th.o.ad. of 2004 Doll.a.)
TABLE C-2 DIABLO CANYON POWER PLANT UNIT 2 DECON DECOMMISSIONING COST ESTIMATE (Thoouod. of 2009 Dotter.)
IDRot)ct DOf-Site ILEW Off-Sot.
bIsw Nootn Atot 0D ito Do Reoone Pocketing T-aosport P*ooe..lg Disposal Other Cotiogency Total A CF BCP C C TCC D-e Reron.e Poklott Tronoport Poroasieg Disposol Ott-r Contilogency Tote) 1b"A.I Auii
-ulin 132 34 47 w8 lbt1.1.1 Autliarobuildino 1tS t7 132 bflOima t
134 47 tO 1b.1.
Tote)al 1
i39i 2t0 1~
- ~
608
-t
- 1. 624 565 2.193 101.2 09000 orio935tWD 1,339 6 70 2.0919 1.0 t
556 545 2.t02 10.1 Sutootol Pe.o I.btActb Costs 1.339 1.398 879 3,67 1.55-1.624 1.11t3 42 Pe dodb Additionat Co*l.4 tboi SitCharaotd foern 936 281 1.216
-".---1.088 t
1,468 tO.2.2 Coltetooooain loroi-tortndacTeotdooo 353 53
- 405, 410-----t454 10,2.3 Htordots Westa Manoatnt 577 87 163
-,-670 235 905 tb.Z4 Mbetd Wase Manaooenent 577 87 663 670 235 166 1b.2 SulbotalPereod lb A1 Costs 353 2.099 W07 2.990 410 2427 993 3.130 Period 1t ColteraI Cogts bb, 3-1 Deo eaui, en 10.22 DOC sta relocation e99etos 10b33 Proces liouid wste 1b.3.4 Soall toalowance 1b.35 P.e outino eouIoowt 10,3.6 Deco0 6
10b3 Subtotal Peold 00, Coleatar Costs Pasted 00 Perod-Deoendent Costs 104.1 Deoen -U01im 10.4.2 1r61703c0 10.4.3 Proertvtaoes 1 b.4.4 Heath ohsics suoples 1 b.45 Hea-eauiomente ental 1 b046 Dooosol of DAW oreratod 1 b.47 Pont energy budoot 1 b. 4 a NRC ISFSI Fee 1b.49 NRC Fees 1b.4.)0 Errteron Plannina Fees 1b.4, t Soent Fuel Pool O&M 1 b.4.12 ISFSI Ooetino C.st 0b.4.13 ISFSI Fed Cost 1 b.4.14 Se"urty Staff C09 I b14.15 DOC StafI C09 lb.4.16 U06 Sotal Co0t 0b.4 Subtota Perieod Ib Perod-Deondent Costs 1b.0 TOTAL PERIOD tO COST PERIOD 1
TOTALS PERIOD 2a -Larse Ceetooauoo Rennreal Period I DOuect DeOonorssioeieo Actbtaes Nucler Ste-m S-ooI, SvoltM Reeo1a 2a.1.11 Rates Coolant Pinna 29.1.12 Pre-ssszer Quenoh Tank 2a.1.1.3 Reactor Coolnt Puos= & Motos 2a.1.1.4 Pressurtzer 2a..t.S Sitm I,
ooerators 2e.1.1.6 Rebred Steam Generaton Unts 2o.1.1.7 CRfIs/CIslSenlol e StructureRerooal 2a.1.1.6 Reacto Vassal lnternats 2a.1.19 Reotot Ve*soo 2a.1.1 Totals R oval of Maior Eausoient 2a 1.2 MWn Turbine/Genetetor 2a.1.3 Main Condensers Cascadino Costs born Clean Buildina DSentoboo 2o 1.4.1 Reacto, 2e.1.4.2 AUoxdltv 2351.43 Containteont Penenrato Aras 2a1.4 4 Rattasste Staseo 23.1.4.5 Fuel Handltno 2a.1.4 Totals Dispees oel Plent Svote 29.1.5.1 Au9*41a Stiam 2a.1.5.2 Aoiav Stae- (RCA) 231 5.3 Buikdjin Seias (No-Po.r BlOck) 2e51.5.4 Coardem.ae SWs-ee 23515.5 Cotdoeranue sostoe msubted) 2a.1.5.6 Corntonerot Sor*
2e31.5.7 E StbonmSteam
& H-aDer.rio 23.1.5.8 FPerdoten Sosteot 816 59 1.243 2.118 4
961 214 192 25 406 39493.
1.719 3.403 2.389 o
123 M39 w
0 1.961 153 174 [
501 6099 4.103 3.452 7.21 93 0
100 5 1<1 j
3 1.112 186 0
430 1.444 561 605 5.103 1.021 2.99 t2.427
- 731 24t 1.117 o
6 31 1 291 718 77 9441.
0 -
54 2W249 29 2212 3
8 69 23 110
- 1.
972 146 1.119) 1w 13 141[3 0
56 55 1
125 19 14-1.136 17 W7 3.157 4704 361331 10.371 1.15
.9270 9 9 17.916 2.702 21.0401 29 472 564 66 9.192 22.325 6,144 40.033 IO 573T1 4047 1.997 5W9 6RIS 9.356 63,388 11.307 88.101 563 5.7301 4047 2.776 25 w9 1.377 532 323M 21 32925 4
Z9 S'
322 329 30 V
43 41 119 4.301 1.172 59W21 5.(M) 113 92 423 61 567 M2 1353 1902 3W 3.236 606 2.23 6.495 112 3263 136544 31162 1.824 659 2.255 6.495 112 2266
- 13604, 17.342-101 32 267 133 6
- 2.
8 4.578 636 6.029 194 5640 19 1,502',
845 574 1
127 2.267 1290 474
.540 194 7.506 213724 6419 2379 "9
4,219 01532 2,613 4.657 34.260 612 20,995 83.9101 55.092 3234 0 574
,165
.6069 213 6w 7589 1.1 527 301-1 2443
-498 1905 64 IRI WE M62 3.4Q21 1.973 1
1.Z33 247 222 26 23 97 79 32 41 3.36 3.152 74 5a 1909 1.917 81 3.631 1.SO3 9.131 652 WE 652 869 532 31.26 1.186 415 162 5,890 2618 10,097 2
0 3B9 15..o 595 1W 7.32 13186 4.764 8:3674 I
-O0 10 39 892 312 1.20x 0150.
'18 69 87 336 0-76 301 3
70 26 102 1.129 395 1.525 73 26 99 155 54
.2(9 639 234 2
63 504 176 681 73 6
99 145 t
96 1.320 A4629Th.
1.782 00668 0 2 ' 1299 4,952 12.00 42183 16,29 3
0 128 20.700 7.467 28.801 655 870 0
7396 25.939 14.317 55.222 661 874 7.526 7361 31337 120.872 29 55 0
1.35 0
695 2.W1 5
9 183 S9.
342 50 50 171 4.72 0
1.624 7036 493 as 0
293 33W 13
.3 2.598 3.27 4.190 1
5324.
20.536 2.119 946 3.237 4.307 130 3.759 14.498 117 49 1.014 0
466 1799 5.319 913 0
.221 225 59.91 23994 1.508 68W Z0.40 225 5 W 23M13 12.237 32751 6.6w 33.252 711 23.944.
.92,356 247 86 1.W W8 0
979M 3777 122 92 869 702
.- 1.112 4.289 O 0 0439 IWE8 244 943 S21 82 26 102 57 20 784 3,026 3
17 N70
- 142 549 9
126 82 317
-2 6
57 316 4.W8
.2,139
.. 252 19 105 1.591 723zi 2.789 9
99 738 336 1.297 14 79 1.29 579 2.233 12 65 986 402 1.549 420 1.199 0
yt 1.071 65 149 1,929 100 S4 302 303 1 42 3M3 73 161 1.2323 0
60 6
92 10 75; 0
21 1611 0
299 2.2019[
1.244 608 76 163
-2.241 116 352 99
,3
-49 12 10 12 188 6
as 22D 3.349 73 1.199 U4 514 55 642 45 6W7 55 3
9 0
0 0
35 2161 741 51 i
2511 19 7
0 232 1.42 0
0 129 943
NOTE: Totals may not sum due to rouning Erlosute 3 PG&E Lttter DCLt-Sm TABLE C-2 DIABLO CANYON POWER PLANT UNIT 2 DECON DECOMMISSIONING COST ESTIMATE Ilthoooaaada of 2004 D.11a)
TABLE C-2 DIABLO CANYON POWER PLANT UNIT 2 DECON DECOMMISSIONING COST ESTIMIATE (Thtoosada of 2009 Dollal)
ID
- Borial site"a Off-SlIe LLRW I
Off-SlIe LLRW Nober At Desotatin De-n Re-moo P.ekatdng Traspeort -
P)oaesiag Dlsposot Othar Cootioeory Totat I
Ap C.B "i
(lt 0
,CF OýTCCI Dao RIIoo~
Paokhaeoe Tasorat Peooiag aioe ispostl Other Cottingenoy Total
-umber 2a,. 5.9 Feeoooater System frtsutatad) 2a.t.5.rO Feottoster Sstem (RCA lrcaat edl 2a,1.5,11 Featetoor Sostem (RCA) 2a1.5.12 NSSS SamolinSystem 2a: 15.13 NSSSSami*io Soste W Insulated) 2a.t.5,14 Nircea & Hodrtoen 2at.5.15 Nitro
& Hroden tIIlts ed) 2t.S.56 Nirrooen
& Hodroaen (RCA Itnulated) 2a1.5.17 IrON Hoderoten (RCAi 2a.1.5.18 OI, Water Searator & I Sump 2a.1.5.19 S aitmater System 2a.1.S.20 Torbinr Steam Suoolo 2a.1.5.21 Tutnone Steam Suotly (RCA) 2a.t.5,22 Turbaine ad Gaerator 2a.1t5,23 Turbine atd aenerart tnosuloated 2a1.S Totas 2a.1.6 Saffotodfo In sutto.. o. decommissionorr 2a.o Subtotal Period 2N Actrt" Costs Period 2a Cotueral Coas 2,2.1 Cure Surchama 2a22 Old RPV Held 2a 2 Subtbto Period 2S Addiloatal Costs Period a CCollateral 23.3.1.
Pmoessliku:Aoste 2.3.2 Small tool e*ae 2a.3 Subleoa Period 2a Colateral Costs Period 2a Petlod-DOeendent CRots 2N41 DSeon suoooe N.4.2 Insurance..
2a.43 Proocrto toots N.4 4 Healfth ehnsas su.oties 2N.4 5 HScw esuitment rentol 2.4 6 Dlsoosot ot DAW aenerled 2a.4.7 Plt enem budoaet 2a408 NRC ISFSI Pes 2a.4.9 NRC Fees,,
2a041 0 Ememeene Plannon FPes 2a.4.11 Stont Fuel Pool O&M 2a:412 ISFSI Oooratta Costs 2a.4.13 ISFS1 Fxed Coats 2ao 44 Surllv Staff Cost 2a.4.15 DOC Staff Coat 2..4.16 U tId" Staff Coalt.
2N.4 Subtotol Period 2a Peiod-Deaeardert Coats 2a.0 TOTAL PERIOD 2a COSTS PERIOD Nb
-Site DecSlortstrniot Period 2b Direat Decoma nioe ASbrias DOoosal of Pnt Systems 2b.1.1.1 Catltal Additions i6-202ideal 2bS1.1.2 Caotal Addoats 85-2002 lcortamltatedt 21,.1.3 Cherr..oto S Volume Cotro 20.1.4 Chemiool S
&Vomo Coa tlr eda 2A.1.15 CortrCoot Wa er 20.1.1.
Com nerta Coolto Water SCAI 2b.1.1.7 Comerssead Air
- 2. l1.8 Corressad onr At Itfted 20.11.S Conmeotssod AlsrCA Irutataedl 2b.1.l.10 Comotessoed Alrl RCA 2M.1..111 Diesel Eroi.o-erttor 2b.1.1.12 Diesel Etmian-Geterae tlnsulatedt 201.1.13 Electrou IClenIt 2bt.114 Elec"l' ICtCooomltat en 21,.1.15 Elatrial (RCAl 2b.1.1.16 Fire Proteotion 20b.1.17 Gaseos Radoaste 21,.,1.18 HVAC Clean _InWlte 2b.,11.9. HVAC (Clen)I 2b 1.1.20 HVAC (Contamiated Insolated) 201.1.21 HVAC Contamlnatedl 20 1.1.22 Ltiuld Radoasta 2MI.1.23 Lould Radoaste Itnsultted) 2b1.1.24 Ltoo Oil Dslsbtdbo S& Pudurifiatio I 20 A.1.25 Malkt-s Water 2bt,1,.2 MIaI-uo War ll rtsouatedt 20t1,I27 MoWt-so Water RCA Insulated) 20.t.1.2 Maae-so War (RCA) 201.1.2b Ma12 charioat Delsartero Eot omeS 106 72 29 1 3 3
63 18 020 634 3.549 1.003 20116 11 91 91 254 1.623 2.996 9
41
-16 1211 2
10 147 42 273M I
5 2
14 2
3 7
w 46 2
t 9
10 491 2
25 2O 0
10!1/2>
2 31 10 162 15 1381 64 285 4.380
-47 9
6 2642 77 1.172 321 2.1171 3
16 238 62
- 412, 1
3 44
-1 97 102 04 12,829 87 3.057 20O 7
0'%tI 2
16 8
111 34 915 4.6341 76
.058 3.592 1896) 36.385 612 2641 118.212[ 059793 1;5 274 124 44 1.064 14 645 2
0- 2' 124 44 2.160 14 919 3.351 1 20-34 05 4 31 164 7069G-~.-'
34 as 431 M22 1.052 19 95!,
952 65 1.053 134 13 147,.
i o
2449 3,*4 74 33 2.241 572 2.920 1.401 210 1,6111 190 12w 4%8 50 548w 834 83 917
.1 1.316 197 1.5141
.200 275 1100 121 00190 3710 21os 673 3I~'~50 3WO 57 437 4.30 645 4945 10.338 2`151 18.789 28,94 4.341 33.2113 74 '32.241 55,474 9.618 72.135 407
.290 3.755 18.950 41.216 56.100 37.156 194,786 66ý 37 955 730 6
17 214 154 135 773 2-33 44 3(2 894 705 3147 2-.0r 10 9
20 29 4 228 9710 5
11 014 °'
- 1 9
1<
tO 156 106 1
SI 26 2
1o 159 1605 593
- 30-2.16 3
13 182 30 9 1 31 24 104 1,573 581 3591 1 9
8 37 561 148 983(
3 6
45 61
<1 236 i 11 U) 309** :
3 11 I 8 3w 69 412 16 54 725 223 U32 2O3>4A 10 26 106 402 330 1474 1
1 1 2
32 24 16t 100<
4 17 250 8 2 51 24 165 2
is7
-1 18 471
.2 7
163-w 41 2511 84 3
115 M15 "3
73 21 1.116 615 108 4.560 4.124 1.165 23.454 106 106 295 295 2
14 211 2
4 9
64
/
.1 S
3 35 3
45 74 413 6.288 21 111 1.6M3 3
23 342 w
1 4
63 223 1.215 18.417 72 19 1t1 I5 27 12.848 5.157 27.219 34.034 1.572 144 63 944 144 63 2.529 40 123 619 40 123 619 94 1.886 3.401 76 4.619 1.160 25,150 11 297 537 633 t89 243 124 357 377 4
S 17 31 7 742 200 2.056 216 1.309 229 79 25 269 151 673 238 269 19 25 164 161 15 98 I
88 1.348 5,3.7
- 20.222 M77 345 624 735 220 282 415 5
368 236 92 2,39 1,521 260 S
20 313 175 782 277 313 22 29 1 91 187 17 22 114 I
86 13.118 7
3w 12 12 20 3
28 3
1 9 22 S1 47 1.TT7 47 1.T7 5.301 27.219 3M.0115 67 M8 109 6
1 420 6"
22 se 2M 14 55 5
20 2
7 39 151 24 92 40 100 2,763 10.658 50 3,279 167 643 3
146 5.584 S3t10 1.519 5.859 711 36.621 142.410 550 2.122 16 447 1.725 16 998 3.849 13007 1.182
- 163 398 410 t.581 31 119 1.106 387 1,493 156 54 210 660 2546 1.218 4.699 668 2.578 1.628 070 2.198 221 221 579 203 781 06 13 1.308 1.529 535 2.004 221 77 290 442 155 596 4.996 1.74 6.745 8.983 6,644 25.627 3.628 11.775 45.397 4.455 25,137 06.007 5.183 63.465 244.795 258 994 269 1.03 '
909 3.505 275 1.002 so 195 o5o 1.930 31 121 2
6 215 026 30 116 1
3 836 3.225 196 755 1 305 5.341 397 1.531 76 293 10 39 010 423 151 583 736 284 398 1.536 29 113 M256 793 S 6 24 17 67 96 370 0
2 24 307 63 43`4 13 42 62 942 14 228 19 261 149 2.258 7
65 16 212 78 1 N41 29 152 1
3 24 360 1
25 10 14'8 65 7M2 219 25 50 25 185 V4
NOTE: Totals my rW sur due to ro1nd0 Ena.otr 3 POE Letter
_OLCLO-TABLE C-2 TABLE C-2 DIABO CANYON POWER PLANT UNIT 2 DLABLO CANYON POWER PLANT UNIT 2 DECON DECOMMISSIONING COST ESTIMATE DECON DECOMUOSSION]ENG COST ESTIMATE MT.oussod. of 2004 Dolt.1 )
(Thou.ods of 12009 DO1l1.)
.1D r-e LLW Buriotllt Off-Site LLEW Ntie Avitv De-itiot Dea-Re-o.-
Pockagig T r
P ssing Distpeal 0th-Cotigeooy T-1 A CP BCP C"IP GTCC*
t De-.
Retti Trst
.Poa PTting Disipo.l Other Cotingency
" Tot-l 25.11.3 48aeal"""u ReatorCoolan t4 78 2
3 22 56 45 221 123~
18 91 2
4 32 45 6
250 2b.1.1.31 Nudlee Stea SuoolySamotia 12 1
12 12 14 1
210
-0 2b.1.1.32 Nualer SteaboDDool5amotinottonulatedl 5
1 m
3 t4 11
-1j S
1 4
-4 1
21,.1>33 Retaddutl attoottmo 221 183 22 43 228 1.46
'148 2.218!>
2193W 257 213 28 62 327 87
-1 87 2.381 2b.1.1.34 Stetloeone
-nzo 76 3
5 57 55 422 238 120 88 3
7 82 44
-79 304 2b.1.1.35 Safev lniation (lns atedl 3
3 2
I1 3
2 3
12 21.1.1.36 SafetvjIniecon(RCAttulatedl I.3 1
2 17 30 1S 89 63 27 1
3 24 25 28 108 2b1,1..37 Safetlniection(RCA 194 10 17 152 2S-142 785 505 225 12 24 2t8 223 246 948 2M.1.1.38 ServiceCootinaWater 90 13 103 i 105 37 141 2b.1.1,3 SermoeCooairWeter(RCA) 22 2
26 10 MO 26 3
37 23 89 2b1,1.1.0 Sewer SW-e E--nso 31 5
- 31L, 732
- ,oi
'o,"144 10536 69 6,22838,413 3
,3749 2b.1.1 Totals 1217 9,258 195 466 5.595 3.607 4,397 24.733 1 732 1.1 8.34 32.37 2M.1.2 Salffl800onsooo4oldenort.
oreatotdons 4.436 2m 10 138 43 148 5.792' 96 5.154 23 14 200 34 1.899 7.324 20,1.3 1 Reactor 1.182 1.313 2*1 304 319 8.742 3.M221 15%312 18464 1.72S 268 436 458 3843 14.822 21,.1.3,2 Auotiar BUS 44 59 48 174 2.161 1.t24 4931 4832 1
574 64 123 250 1,7M9 1,289 4,973 20.1.32 CeodJAddA oa 85-2002 264 140 13 18 22 470 282 t,168 i 1049 307 116 is 25 32 371 Ml03 1170 201,.3 Coarrannt Penetraon Area 284 145 15 24 90 537 291 1,341 1.204 237 1
17 34 129 422 353 1.362 2M.1.3.2 RedwesteStoaoe 5
45 6
9 6
235 75 381 524
-,6 52,7 13 8
186 S8 201,3 Totals 2 481 2.098 324 440 610 12.152 44.83 M2"I8 27403 -28
- 2.
378 82 878 847 884 22=95 21b.1 Subtotal Period21Actity Colst 3.698 15t.79.
539 818 6,344 15.802 10,634 53.6241 385.128',
4.297 18.348 628 1.315 9.107 12.524 16.176 62,395 Petod 20 Colateral Costs 2b.41 Process liuddwaste 68 169 220 1.63X 491 2.579 1895' 79 196 316 2.34-1,026 3.957 M04.2 Smafoo toolaalnoo 313 47 3598 364 l
17 491 21,43 Spent FuelCapitalond T-1rte 50(M) 75D 5 7W8
-5
.810 2.032 7.843 2044 Radotote Proceossm EacUhmentoSernoas 394 59 453
'15B ISO 6
2534018 204 Subtotal Period 2a Coltatel Coate 8
313 169 220 1.630 5.308 1.347 8,142 1,85 79 364 184 316 2.W 6,267 3.347 12.909 Pedod 2b Period-De88 rde4 Costs al,8.
21b4 I s
De SUoo es 408 2.038 1.894
-663 2.557 2b642 insurance-5.738 573 6.M831 -
6--
.6"58 2.330 89588 26423 Prooertv ta-e
-N 80 8 8 5
935 327 1.263 20.44 114810 ohoics soolien DB 4NI
.0 5.100 4.741 1.659 6.40 284.5 Heaw edsument rental 4,345 652 4.996 5,048 1.767 60815 20 48 0isosalttof4DWoenerated 111 49 3.365 860 438t4
-8.3.9 128 70
-2.427
-8835455 2b.47 Planteobtbuet 2269 340 26101 i
2.636 823 3008 2048 N8CISFSIF-1.143 1-1328
,1328 2b 49 68CFe 2.347 236 2582 2727 954 3681 22410 Emoarolt-oPtljo8F-2.8973 297 32703454 1.209 4.6&3 26411 SpendFuelTransfer-lSFStoaDOE 61.82D 243
- 1.
14882 659 28541 2b.412 Seret FuelPool O&M 7.m23 1.148 98112
-892M6 322 12428 28.4.13 Sponl Fueo Stobe*eeC/mtoal Eui-onlent 43.631 6.545 508175 6
50695 17.743 68.438 20.414 JEFSl Oeorao 1,143 172 1,315 1.328 46 1783 2b4.15 ISFSI Foed Costs 2.287 343 263,0 r
2,67 86 2b.0416 SecurkvStaffCost 13.625 2044 15E6O9
-"15,831 5.541 21.372 2M.4,17 DOC Staff Cost 22.649 3,37 26.046 -
268316 9.211 3.5526 2b0418 UOtNta8Cost 75,49 1124 8384 87,258 2358540 117,748 284 Subtotal Period 2M PerOedod-DerDenrt Costs 1.630 8.425 111 49 3360 183245 2.61 226448 8348 1.894 9.789 129 70 2427 212912 798527 348749 2b.0 TOTAL PERIOD 21COSTS 5,396 24.529 819 1.186 6.3W4 28.786 188,3 41.453 28S92521 42.597 1,895 270 28.50(
952 1.703 9.107 17.530 219.18(
99.134 382376 Period 2c -Deneoraaooalbo Fottoodosa Wet Fuel Stolors Period20 Direct OeaoroioroniActMtss A
25.1.1 R-e soent fuel rak 365 37 7
28 1.048 46 2834 2
2 424 43o
- 4) 800 1.929 Disoasat of Peaal Systems 1
2c.1.2.1 Eleal (Cltaomonated)-FFHB 66 1
2 34 6
m2 1
3 2 12 T7 1
3
'19 4
47 182 2.1.2.2 Elactnait (Doeontaminated)
-FHB 403 5
21 325 153 98 7
468 487 w
1.31 2c.1.2.3 FireProtecton(RCA) 157 3
11' 166 66 4031 a
182 3
16 238 E4 154 594 25.1.24 HVAC (Contaminatedl
-FHB 158 3
11 158 31 71 4251 64, 174 3
16 228 26 157 6N5 2.1.2c 5 S entFueoOPOColin-56 13 17 89 38 131 703 834 r
65 15 24 128 338 187 758 2.1.2.6 Sont FuelPaCooina-F11HB 76 14 18 96 427 m144 778 88"
-88 16 26 138 -
354 218 840 2e.1.2.7 Totals 908 38 80 869 862 O58 3,34u6 14867 1.055 44 115 1.248 715 1.112 4=288 Deaontamniotion oa Ste Buildonas 2c.1.3.1 Fuel Handino 20.1.3 Totals 2,.1.4 0afloldin8 in sUoDOd of deomissionins 2e.1 Subtotal Penod 2c A otv Costs Period 2c Colateral Costs 20.3.1 Proaesa Idoud roso.
20232 Srnl tool aoooetl 2c03.3 ODeaomsiorts o Eouioroeot DOsoosoJn 25.24 3
oRadaste P
e Eouiomeot/Seaoaes 2c03 Subtotal Period 2a Colateral Costs Period 2c Pedod-Deoendeto Costs 2c.4.1 Deoon suooies 62 520 21 w
154 47 52 525 21 33 16 487 487 4
2 28 9
481 2.357 142 144 1,021 2.615
-5 2"55,-
1.58-
-1 811 810 598 2
.55 4
1.547
-4 611 610 228 1.158
'18 1.031 1,882 9,082 0.723 1.035 2738 82
- 485, 269.
38 8
60 6-166 25 190 165 2486
~
1 Sil 289' a
38 46 229.-..
r 214 24 47 221 547 721 2.783 24 47 221 547 721 2,783 5
3
- 4) 7 380 1,466 165 207 1.5(X 2.098 2,713 10,486 19 59 334 158 B88
-21 82 8O6.,;"
66 736 126 355 1.370 3
48 260 145 125 736 461 193 601 2.320 33 33 52 16 74 N0 41 m3 46 513 158 87 513 3m2 184 75 289
NOTE: Totals may not satu due to rondNVg Enclosure I
PI&E Letter DC L9-*
TABLE C-2 TABLE C-2 DIABLO CANYON POWER PLANT UNIT 2 DIABLO CANYON POWER PLANT UNIT 2 DECON DECOMMISSIONING COST ESTIMATE DECON DECOMMISSIONING COST ESTIMATE (Thu
..ose.
of 2004 Dollat) lThoaneeds of 209 Dollt,.)
lEere~let a* tor tree troo fl0atd 43ts for LILtW Iroe 2O4: R~e++d Eoootromrl%: Re+ree SCeasA Btmral Na. to S*atd Off-S t.
LlwOff-Sites Notritt AoDesetitoo Deon Raroves PsAlnog.
'T-esport Praoe..to Disosal Othte Coetiogeocy Total I
A CF RB CI C CP OTCC'I Daes Ratooe Packceito Traosport Preasine Otetrcot lth.r Conitinefly Total 2.4.2 Insrra-ce 261 26 288
.o
.1 303 106 409 2c 4.4 Proealthae
-h
-Ilea 40 4
45, 4616.-
2 c.4.5 H a.e.
..icha en tnre ntal 912 137--
.068 371 5.436 2c4.6 DsaosalofDAWaencerted 26 203 1 0371 Mý 769
,L 30 17 631 237 916 2c4.7 Pl anrnerbinaoet-179 Z7
66
-66 2c 4.1 NREFe1-e s--
151 15 1 66
+
\\
15 t237
-C 10
-h
-'C
-"i' 1-9 i
6173 61 234 2..4.11 soentFuelTranele-tSFSltt0OE s
30 19 149 45
-5
-6 3
2o.4.12 lSFSl Ooero~atost C
-Is-57 9
66 6
38 2o.413 ISFSI "o"aCoss 1
15 17 1 32 134 47 180 2c.4.14 SeauntoEtallCost 043 156 1210 1
-1212 424 1636 2c.4.15 DOC Staffre C-m 3235 485'Ce 3720 4--.35 1316 57 2C.4.16 UItii Stall Coat 6174 T26 7 t06 I 7.174 2.511 9.684 2,.4 SubtotaltPeriod2c Peiod-eDoortoCosts 14 1.254 26 12 m
796 11.593 2.172 16.036 1710 314 1.457 m6 17
-3 13.470 5.W3 21.
200 TOTAL PERIOD 2c0COSTS 1.107 3.664 258 243 1.564 3.83 11.758 4,300 266 745 1286 4,257 310 349 2.245 3.190 t2662 8.851 3.4 PERIOD 2e- *Uc-Terdbodion
- +*",*
Period 2e Direct Decnourmsrreace Actiodies 2e 1 A 06152 confrloutattsrc 119 36 1631 t
31 48 187 2e.1.2 Termiteoto
-e 2cr Sulbtutal Period 2aActm Coats, 119 36 110--
138 48 187 Period 2e Addlitoel Coete 1 -
2e.2.1 Uenoso Termraito* Sulvo.
9,770 2,931 12.701 1 -
11.352 36973 15.325 2e.2 Subtotal 2e Add ional Coats 9.770 2,931 12,701
-o-
-11.352 3.973 15.325 Period2c Colaft ree
-n-1.031 153
< :X:
1.106 415 1.C02 2e 1 DOT Staff roalootbr, I=64
-5 1.1744-
.18 4
602 2e.3 Subtotal 2e Callatral Coats Period 2e Period-Deonadeot Coats 2e.4,1 lrnsuroane 2e,42 Prfoarlytaces 2e.43 Hcalth ohvsim Suoalie 2e,44 Disol-of DAW oenerated 2e.45 Plat enerr budaet 2e.456 NRC ISFSI Fees 2e.47 NRC Fees Dn.A4 Emnemenr Plannca Fees 2e.4.9 Soern Foal Trensfer - ISFSI to DOE 2e4l0 ISFSI ODetnot Costs 2e.4.11 ISF51 FIred Costs 2e.4.12 Security Staff Cost 2e.4.13 DOC StaffCoat 2eA14 Uh Stafl Coat 2e.4 Subtotal Period 2e Pearod-Deoledent Corte 2e,0 TOTAL PERIOD 2e COST PERIOD 2 TOTAL PERIOD 3b ReStoration Perod 35 Direct Deoanumlasionino Activities Semollion of Remainirt Sote Buildinoa 3b111 Reactor 3b,1.l,2 Adiflrltration 3b1.1.3 AoailaryI 3b11.4 Cait al Additionas 85-2104 3bl.1.5 ChemIcal Stmoae 3b1.1.6 Chlornaloan.
3b.1.1.7 Circula"r Waer Tunealt 3b11.,8 Cold Machlne Shoo 3b.1.1.9 Comtrunioatioa 3b1,1.1,10 Condensate PdoahinofTeohnicka Suvooret 35,1.1.11 Containment Peretect ion Area 3b.11.12 DOehaMr SssCturc 3b.1.1.13 Fabrtcaton Shoo 3b.1.1.14 Fire Put Hroue 35.1.1.15 Haalardos Wase Stotre Faity 3b,.1116 Atake SIStI""rte 35.1.1.17 Maintenanc5, Soo 3b1.118 Misaelaeoos Strutres 35,1.1,19 NPO Perharrrat Wrnarelhosee 3511.20 Poads 3b.1.1.21 Pale Finre Pumo & Fuel Cat 35.11.2 Pretrerrl 3b.1.1.23 Radoaste Stbr-e 36.11,24 Roadwase Storaso Facfltv (Additional) 3.1.1.25 RoorWareoseso 3b,1.1.20 SreuiNb 1,021 153 1.7 321 32 3534.
4 66 7
72 215 541 268
-15 4
2123
-1 31 32 273 145 22 1674' 245 25 270,M IL 243 24 2 7 <
137 26 2151 6
14 1071 167 26 2151 m
L40 1.70~
3.916 587 4.504 7O6-5716 057 6.5 215 4
2 123 1 2.14 1.849 143361 273 3215 4
2 123 23.054 4,99 28.366 273 7.663 53,557 12.372 5SAM 26167 65.938 279.551 676967 39.100r 11 744 996 574 7678 26.07 1
863
+;' ::++:+
6,0922 9 14
.7006 9-'
o 7
773 116 803 52498 825 6.323
° 3A499
-5 25 4.024 I28
-43 331 1
-3 4
0 605 91 696 489 73 463 6it 13 7621 1
4,,,--*
13
- 1. 78D 267 2.N71 3.810-S-563 4.471 266 Q
4 1iS 47 7
978 147
- 1.
5 t.2611-190 14581 557 as 6
0 761 240
-w 3
2761.
25S 250 250 8.904 62.228 5
3 698 5
3 98 5
3 S0i 14.375 7.444 38.570 W1.666 1.186 373 77 168 118 2S5 282 217 106 217 1,051 4.55()
6.641 14.110 26.786 324.810 415 1.602 131 5)4 27 104 87 337 37 142 59 227 108 100 36 99 381 76 2m3 38 146 76 m9 378 1.459 1.553 6.143 2.324 8.69 5.063 19.526 9.499 3W.641 180,949 M07.948 7.078 898 l.388 4.0653 81 3
703 568 790 to5 2.068 4.517 309 55 1.136 1
1.473 38 682 279 2A47 9.556 314 1.213 2.236 8,624 1.423 5.488 3
11 312 1.203 117 452 1
5 244 094 199 767 S 273 1.067 35 135 2
6 724 2.792 1.581 6.099 108 417 19 74 3988 1.534 0
2 0
2 3
11 516 1.986 13 52 m
923 21 98 376 10
4,4"?
NOTE: Totals my not sI du to roonding Enslosure 3 PG&E Letter DCL-*9-SS TABLE C-2 DIABLO CANYON POWER PLANT UNIT 2 DECON DBCOMRiSSiONING COST ESTIMATE (Thosond. of 2004 Dotl1s)
I ubr c
h De iption 3b.1.1.27 Seouut 8uldLktais lAddional) 3b1.120 Simnutator 3b.1.1.29 Steam Generator Stame Fesrltv 3b1.1.30 Teltehoee Termina 3b.1.1.31 Turbne 3b1.1.32 Turbine Pedestal Vetisle Maint enace 3Ml.1.33 Vehaot Mainteoatce 3hA1,1.34 Waste Water Holra & Treatment Facty 3M.1.135 Fuel Handlrm 3b.1 Totals Site Ciooout AscMtes 3b.1.2 Removo Rubbie 3b.t.3 Grode S landscae site 3b.1.4 Final reportto NRC 3b.t1 Dubtotal Period 30 Ativat Costs Period 3b Addittooal Cost 3,2.1 Concrete a
sohino 3W..22 Brelawoter Demolition and Removal 3b.2 Subtotal Period 3b AddflJonad Co*ts Period 3b Codateral Costs 31.3.1 Smolt tot aootri a 30.3 Su I 3b Costoeral Costs Perod 3b Pedod-Eeeendetd Costs 3,4.1 1 -surdosa 3b.4.2 Prooeýtttaoes 3.4.3 Heoatn eaurtens rental 31.4.4 Plant
-e udoelt 30.45 NBC ISFSI Fees 31.40 Emeroenso Planiaro Fees 3M.4.7 Spent Futl Transfer -ISFSI to DOE 304.0 ISF51 Oeretaso Costs 3b.4.9 ISFSI Flood Costs 31,4.10 Securit Staff Cost 31,4.11 DOEC Staf Cost 30 4.12 UtIV Statt Cost 3b.4 Subtotal Period 30 Perrod-Desendent Costs 3b.D TOTAL PERIOD 3b COST PERIOD 3c -Foal Stonage Oenratione/Slhiooioan Period 3, Direct Desommslosilno Costs Period 3c Period-Dependent Costs 3s.4A I--sranue 3s.4.2 Pto erto Ones 3c.4.3 Plant enesry buhoet 3s.4.4 NRC ISFSI Fees 3W.45 Emem t Plsmonac Fees 3c.4.6 Soet Fut Transfe -ISFSI to DOE 3W.47 ISFSI Coeroain Costs 3c.4.8 ISFS Fxood Costs 30.49 Seuttv StafD Cost 3C.4.t1 U" Stats Coa0O 3c4 SuDoRal Period 3c Petid-Eeoeoodent Costs 3c,0 TOTAL PERIOD 30 COST PERIOD 3 - GTCC SbitDna Period 3d Direct Decommassiornlrr Astlea Nusloar Steam DSuopl Sotem Revl 3d.1.1.t Vessel & Internoas GTCC Dtoosal 3d.t.1 Totals 34.1 Subtotal Pertod 3d Aotiltn Costs Period 3M Pedod-Deoendenl Costs 34.4.1 Insuteanc 3d.4.2 Poennt taxes 3d 4.3 Plant enemy budoat 3X4.4 NRC ISFDI Fees 3M4.5 Emeraeooo Planino Feea.
3 7.4.0 1SFS Oterotina Costs 3A4,S7 SF5i Food Costs 3M4.4 Soeutiv StaDf Cost 3dA.9 Utility Staff Cold 34.4 Dubtotes Period 3d Period-Deeesdent Costs 3d.0 TOTAL PERIOD 3M COST PERIOD 3 -ISFS0 Daontarrlsasiolr Off-Site LLRW DRoo Remone Pnckagit g Traneoort Pro*o ste Dispos Other Co-tr 65.3 2
4.384 24 1 6 1.347 M.6 8vl 21,295 1.812 58.72M 6.535 33.3209 39.864 6S3 5.531 5.5311 104.604
' 66 5755 181 257 257 513 2.555 26.643 1,44 14*
175 120 338 1.238 1.238 8.447 0.447 9 447
,3 TABLE C-S DLSBLO CAN0YON POWER PLA.NT UNIT 2 DECON DECOMUOSSIONING COST ESTVI[ATE (Thoeund. of 0O9 Datil-)
nd L
-1 BooleteAitent at t Off-Site LLRW tgenno Tetet ACF BCP -CC?
GTCC BeIenn Remoe Pt enPnPe o
Dospo eat Cohen Coatingeeny Tote1 5
t4 42 15 50 45 341'
-2 4
1t 166 04 751li
-~-
750 1 M 24 t54 22 t.54 2
-!!1 3
65043 5.04241 4-5 1.783 6.877 145 113 125 394 t.51 4
- 24.
20 10 30 2
19It
- 7.
19 73 2
982 175 40,19, t-4
-759-548 2413 5.33 4041441.00 3
-,B25 14.485 55.009 3.1094 448 24 744
- 28.
w4)3 277 20863 2.5 21 273 1732.0142 10 58023M 23.041 92.114 961 7525 7.50 9
2-0 1
10.263 8,332 410641 r,-*
,.725 1 7 13.554 52,279 0.314 49156 46.318
-9..*
1 5
16.215 63.54
.75 3
I 704L 7
27 1
S 0731 103 78r 7
794 270 5'
632
-51 23 9D2 it t1991 9
210 74 030
- 5..4'0 2.240 t.67R 6301 22-o*
MI 8---311 312 9
257 "
350 27-297 67 1.73 T`-:-
775 271 1.0.4 75 574 5
0 Mo 203 703 39 2051 M
0 105 403 77 596 209 0D0 303 200 2,969 1t039 4.004 1702 13 736 13.079 4.650l 1t.737 I.Mo 10,2591 10.365 30328 135093 4.705 30005 6.420 6
30.871 1 30I54 50,35t 22940 154.3871 121.772.
30,957 53,455 206.103 14 1551 167 59 226 4
49 51 18
-04 10 lor 101 07 257 20 6
2013 71 274 9
n 73 20 99 10 1451
,--140 51 15 103867 o'
11 M
137 527 150 l
2 07 i
1.438 503 1.942 144 11.0481 4331 1.4 3 4 0 4 0 44 3 3,1 1.434 1 1 5o48*i.>
o:*
° 433r 167 167 167 104 194 19't 13,562 13,562 13,562 4.115 18.571 4,815 18.571 4,115 18.571 12 V 5
5*.+
1 1
14 10 1
11 i M6 4
29*
01 10 9
9.447 81 1.444 11139 433 13 4
17 3
1 5
6 6
14 5
19 6
2 0
12 4
18 12 4
10 30 11 41 w4 33 127 13562 4
4.848 18.698 167 194 11
NOTE: Totals may not sum due to ronding Encloure 3 PG&E Letter ECL-OS9-s TABLE C-2 DIABLO CANYON POWER PLANT UNIT 2 DECON DECOMMISSIONING COST ESTIMATE (Tohooud of 2004 D.ollac-TABLE C-2 DIABLO CANYON POWER PLANT UNIT 2 DECON DECOMMISSIONING COST ESTIMATE
.ffThosnde ea2009 Dol1ers)
Off-Sloe LLRW irri{OO4:i ev ff-S ont LLWR Nuober Acotivity Doesipton Does RB..oan Peckaieo Tranapost P roceise Ditpecet Other Centiee cy Toe I
A P
iB IP uC C
TCC De-Re....
Psckaegig r
e Pceise O
a 0c-Co
- e.
o C CTs
-AJt it GT-rnpr r~sn isoa te otnec o
Period 3e Dikedt Dcmmissioning Aotstias Period 3e Addlionel Costs 3e.2.1 ISFSI Licens Te*iinion 3e.2 Subtotal Period 3e Additioral Costs Penod 3S Collateral Costs 3e.3.1 Smali tol alioaance 3e.3 Subtotal 3e Collateral Costs Period 3e Period-Seendent Costs 3e. 4.1 Isrance" 3e4.2 Proeruta 1e 3e.4.3 Heaw eouiement renail 31a44 Pant eners budset 3e.4.5 NRC ISFSI Fees 3S46 Secunv Staff Cost So.4.7 U0iit Stet Cost 21.4 Subtotal Penod 3e Period-Debondemt Costs oe S TOTAL PERIOD 3e COST PERIOD 3f - ISFSI See Restoration Penod 3f Diredt Decommissiono Activities Penrod 3f Addional Costs 3St2 A SFSI Demoltion and SOe Retmaetion 3f.2 Subtotal Period 3f AddMlonl Coets Period 3S Collateral Costs 3t.3, S-inat-l a1IO-ance 3f.3 Subtotal St Collateral Costs Period 3f Penod-Secendem Costs 3f.4 A i.ua 3U42 Praeerv taoo 3f.43 Hear ecuiement rantal 3f144 A
Pnt enery budoet 3f.45 NRC ISFSI Fees 3fAN6 Secutv Staff Cost 3f.47 UtOirtS Staff Coatl 3f.4 Subtotal Period 3f Period-Decendent Costs 3f.0 TOTAL PERIOD 3f COST PERIOD 3 TOTALs TOTAL COSTh TO DECOMeMISSION
, - mndicatm that this a*
oemmomed!
1w debommissionina stuff 651 6
70 851 3
70 0
132 792 8
70 2.17 7M 837 4518 4.$j 2197 758 837 4.518 488V N
S 321 16l 2
tea 756 7
155 756 7
1w0 1,742 801 1.220 4707 1742 N81 1.220 4,707 99 3
13 3
13 153 41
- 41.
>1r~
ti 7
3 12 OS 95~r4r 368 67 087 153 S
2.197 1.126 SOS SOS.1095 35
~
o 7
too S 34 12 45 54 207 19 7
25
% o 34 130 230 81 311 428 203 784 1742 1308 1.427 5.505 M
23 34w
.335 831 20 211
.082 966 M6 2
2 3
2 2
1 3
15 1
1
'17 8
24 4
-7
-0 St 1
18 ON
-8 1
3 13 218 21 24
-24 42 16 4
45 17 ON
-~~8 O
13 102 03 So 1,10 4
174 M5 24 51 t
202 ON 342
-1 o
1.311 1,019 M27 436 1.62 i06,47a 172 70 116 29.M 25.688 173.32 r 123.710 200 100 153N4 34023 600668 234.005 11.14" 162.418 13.113 6864 26.867 82.38 372221 125.961 800.529.1-22. 8 i
i 4
12.91 186713 16,236 8a418 38.570 83.498 422AM 272.964 1.052.824 12