-pacific electric gas company' and

-Pacific Gas andElectric Company' John Conway 77 Beale Street, B32Senior Vice President San Francisco, CA 94105Energy Supply andChief Nuclear Officer 415.973.3336

Fax: 415.973.2313Internet: [email protected]

March 21, 2012

PG&E Letter HBL-12-006 10 CFR 50.75 (f)

U.S. Nuclear Regulatory CommissionATTN: Document Control DeskWashington, DC 20555-0001

Docket No. 50-133, OP-DPR-7Humboldt Bay Power Plant Unit 3Decommissioning Funding Report for Humboldt Bay Power Plant Unit 3

Dear Commissioners and Staff:

PG&E is submitting the decommissioning funding report for Humboldt Bay Power Plant (HBPP) Unit3, pursuant to the requirements of 10 CFR 50.75(f).

Humboldt Bay Unit 3

At the end of calendar year 2011, the market value of the HBPP Unit 3 (220 MWt) decommissioningtrust funds was $301.8 million. PG&E estimates an additional $69.15 million (future nominal dollars)will need to be collected over three years beginning in 2010 based on a site-specific decommissioningcost estimate prepared by TLG Services, Inc. and approved by the California Public UtilitiesCommission (CPUC) per Decision D.10-07-047. The CPUC Application is based on an IndependentSpent Fuel Storage Installation (ISFSI) that would be in operation until 2020 when all fuel would beremoved from HBPP by the Department of Energy (DOE).

The market value of the HBPP trust is lower than the minimum amount of the NRC decommissioningestimate of $645.4 million (2012 dollars) that was calculated pursuant to the requirements specified in10 CFR 50.75(c), which is based on a minimum 1200 MWt plant. This is due to $188.3 million havingbeen spent on decommissioning activities through December 2011 and an estimate to complete of$256.5 million for the NRC radiological scope.

PG&E is confident the HBPP trust, with the noted additional contributions, will be sufficient to ensuresuccessful decommissioning and maintaining the spent fuel in an ISFSI at HBPP until 2020, based ona March 2009 site-specific decommissioning cost estimate prepared by TLG Services, Inc. andapproved by the CPUC Decision D.10-07-047.

Supporting Cost Estimates

Based on a March 2009 site-specific cost estimate prepared by TLG Services, Inc. PG&E hasestimated that the decommissioning costs are approximately $562.4 million (including $188.3 milliondisbursed from the Trust(s) through December 2011 and $256.5 million future radiological removalcosts) for HBPP Unit 3 in 2012 dollars. These costs do not include site restoration of the facilities($2.8 million), nor spent fuel management until 2020 ($114.8 million).

! Document Control Desk PG&E Letter HBL-12-006March 21, 2012

To assure that sufficient funds will be available for decommissioning, PG&E has established external

sinking trust fund accounts for HBPP Unit 3.

Supportingq Enclosures

Supporting documentation for this report is included as Enclosures 1 through 4.

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

Enclosure 2 provides information on the escalation of the required decommissioning funding amountsto 2011 dollars. As required by 10 CFR 50.75(c)(2), and using NUREG-1577, "Standard Review Planon Power Reactor Licensee Financial Qualifications and Decommissioning Funding Assurance,"Revision 1 and NUREG-1307, "Report on Waste Burial Charges," Revision 14, the informationincludes escalation factors for energy, labor, and waste burial costs.

Enclosure 3 is Appendix D from the TLG Services, Inc. decommissioning cost estimate reportprepared in March 2009 for PG&E for HBPP Unit 3. The TLG Services, Inc. cost estimate has thenbeen adjusted to reflect the costs in 2012 dollars per the CPUC Decision D. 10-07-047. The reportprovides cost estimates for decommissioning of NRC scope (radiological), non-NRC scope (non-radiological), and spent fuel management, including operation of the ISFSI.

Enclosure 4 is a cash flow of the total decommissioning of HBPP that identifies the monies for NRCscope (removal of radiological contamination), site restoration (including the non-radiological work)and the spent fuel management.

There are no regulatory commitments in this letter.

Should you have any questions in regard to this document please feel free to call Bob Kapus at(707) 444-0810.

Sincerely,

waySenior Vice Presiden - gy Supply & CNO

Enclosurescc/enc: Elmo E. Collins, Jr.

John B. HickmanINPOHBPP Humboldt Distribution

Enclosure 1PG&E Letter HBL-12-006

NRC Decommissioning Funding Status Report

Humboldt Bay Power Plant - Unit 3 (220 MWt)

(2 pages)


NRC Decommissioning Funding Status ReportHumboldt Bay Power Plant - Unit 3 (220 MWt)

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

$ in Millions1. The minimum decommissioning fund estimate,

pursuant to 10 CFR 50.75 (b) and (c).1

January 2012 dollars $ 645.4

(HBPP is a shutdown unit with a Site Specific Cost Study;therefore, the minimum decommissioning fund estimate is basedon the Site Specific Cost Study shown in item 8 of this enclosure.)

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

Market Value (December 2011 dollars) $ 301.8

3. A schedule of the annual amounts remaining to be collected;.for items in 10 CFR 50.75 (b) and (c). (Alternatively, the annualamounts remaining to be collected can include items beyond thoserequired in 10 CFR 50.75 (b) and (c) if the cover lettertransmitting the report provides a total cost estimate andindicates what portion of that estimate is for items that are notincluded in 10 CFR 50.75 (b) and (c). All values below are from 2009 NDCTP filing,Final Decision D.10-07-047.

Amount remaining $69.15Number of years to collect beginning in 2010 3 yearsAnnual amount to be collected $ 23.05

1 The NRC formulas in section 10CFR50.75(c) include only those decommissioning costsincurred by licensees to remove a facility or site safely from service and reduce residualradioactivity to levels that permit: (1) release of the property for unrestricted use andtermination of the license; or (2) release of the property under restricted conditions andtermination of the license. The cost of dismantling or demolishing non-radiological systemsand structures is not included in the NRC decommissioning cost estimates. The costs ofmanaging and storing spent fuel on site until transfers to DOE are not included in the costformulas.

1


4. The assumptions used regarding escalation in decommissioningcost, rates of earnings on decommissioning funds (assumes trustwill be gradually converted to a more conservative, all fixed incomeportfolio after 2010), and rates of other factors used in fundingprojections (all values below are from the 2009 NDCTP filing).

Escalation in decommissioning costsRate of Return on Qualified Trust 2012Rate of Return on Qualified Trust 2013Rate of Return on Qualified Trust (2014-2020)

Rate of Return on Non-Qualified Trust 2012Rate of Return on Non-Qualified Trust 2013Rate of Return on Non-Qualified Trust (2014-2020)

5. Any contracts upon which the licensee is relying pursuant to10 CFR 50.75(e)(1)(v);

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

7. Any material changes to trust agreements.

3.34 percent2.95 percent2.95 percent

2.95 percent2.95 percent2.95 percent

None

None

None

8. CPUC Submittal in 2012 Dollars in Millions:

Total Project (Decommission 2012)Scope Excluded from NRC calculationsScope of ISFSI from Licensing to Decommissioning in 2020Scope Decommissioned and disbursed from Trust(s)

Total NRC Decommissioning Remaining Scope

$ 562.4$ 2.8$ 114.8$ 188.3$ 256.5

2


* 2012 Decommissioning Estimate(1 page)

* Composite Escalation(1 page)

* Development of E Component(3 pages)

* Development of L Component(2 pages)

" Development of B Component(1 page)

2012 Decommisioning Estimate Enclosure 2PG&E Letter HBL-12-006

Nuclear Regulatory CommissionEstimate of Decommission Costs for Boiling Water Reactor (BWR)In 2012

HBPPBWR

($ in millions)$114.80Jan 1986 Estimate

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

Escalated to 2010

Escalated to 2011

Escalated to 2012

(Table 2.1 in NUREG 1307 Rev 14128.9 has no value for 1999 Burial)

400.2 ($360.9 in 2000 Submittal)

354.1 ($425.3 in 2001 Submittal)

357.4 ($445.6 in 2002 Submittal)

373.8 ($430.1 in 2003 Submittal)

388.0 ($439.6 in 2004 Submittal)

416.8 ($453.2 in 2005 Submittal)

519.2 ($494.3 in 2006 Submittal)

550.3 ($548.6 in 2007 Submittal)

564.4 ($590.9 in 2008 Submittal)

574.2 ($573.8 in 2009 Submittal)

594.5 ($596.6 in 2010 Submittal)

618.9 ($619.0 in 2011 Submittal)

645.4

Jan 1986 based on 10 CFR 50.75 (c) Table of minimum amountsBWR based on minimum 1200 MWt = ($104 + (.009xMWt)) million per unitwhere BWR less than 1200 MWt use P=1200 MWt, HBPP 220 MWt

Page 1

Composite Escalation Enclosure 2PG&E Letter HBL-12-006

Calculating Overall Escalation Rate

BWR Dec-05 Dec-06 Dec-07 Dec-08 Dec-09 Dec-10 Dec-11 Weight (1)

L (Labor)E (Energy)B (Burial)

2.0600 2.1218 2.1939 2.2536 2.2784 2.3175 2.37111.9106 1.9808 2.4513 1.8323 2.0402 2.3945 2.7733

13.3331 14.3491 14.4164 14.9931 15.6028 16.2425 16.9085

0.650.130.22

(1) from NUREG 1307 Revision 14, Report on Waste Burial Charges, Section 2 Summary, Page 3 ... where A, B, and C are the fractions of the total 1986dollar costs that are attributable to labor (0.65), energy (0.13), and burial (0.22), respectively, and sum to 1.0.

BWRCombined Escalation Rate for:

Dec-07 Dec-08 Dec-09 Jan-10 Jan-11 Jan-12

4.7935 4.9163 5.0015 5.1788 5.3910 5.6ý216

Page 2

Development of E Component Enclosure 2 Enclosure 2PG&E Letter HBL-12-006

Calculation of Energy Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.2Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 02/23/12) and WPU0543 Industrial Electric Power (as of 02/23/12)

REBASED TO 1986 = 100PPI for Fuels & PPI for Light PPI for Fuels & PPI for LightRelated Products Fuel Oils Related Products Fuel Oils(2000 = 100) (2000=100) (2000 = 100) (2000=100)(P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils

BWR wt = 0.54 BWR wt = 0.46

Energy EscalationFactor (E)

for BWR(Humboldt)

Dec-99Jan-00Feb-00Mar-00Apr-00

May-00Jun-00Jul-00

Aug-00Sep-00Oct-00Nov-00Dec-00Jan-01Feb-01Mar-01Apr-01

May-01Jun-01Jul-01


May-02Jun-02Jul-02


May-03Jun-03Jul-03

Aug-03Sep-03Oct-03

Nov-03Dec-03

126.5126.8126.7126.7126.8128.6133.6136.2137.4137.8134.1130.9132.7136.4136.4136.5135.1136.2148.4149.5148.9148.2143.8137.3136.9136.3135.4135.7135.4137.9143.6144.9145.0145.8140.0139.5139.6140.3140.6143.3144.3145.1148.3151.6151.3152.0147.4142.7142.9

72.975.387.989.783.182.986.288.791.6

110.1108.6108.4100.696.191.683.186.294.290.281.383.2

9376.870.556.658.359.669.176.4

7571.475.577.989.595.182.884.695.7

120.4128.998.385.587.290.194.188.297.8

-93.095.8

1.00001.00241.00161.00161.00241.01661.05611.07671.08621.08931.06011.03481.04901.07831.07831.07911.06801.07671.17311.18181.17711.17151.13681.08541.08221.07751.07041.07271.07041.09011.13521.14551.14621.15261.10671.10281.10361.10911.11151.13281.14071.14701.17231.19841,19601.20161.16521.12811.1296

1.00001.03291.20581.23051.13991.13721.18241.21671.25651.51031.48971.48701.38001.31821.25651.13991.18241.29221.23731.11521.14131.27571.05350.96710.77640.79970.81760.94791.04801.02880.97941.03571.06861.22771.30451.13581.16051.31281.65161.76821.34841.17281.19621.23591.29081.20991.34161.27571.3141

1.00001.01641.09551.10691.06561.07211.11421.14111.16451.28301.25771.24281.20131.18871.16031.10701.12061.17581.20261.15121.16061.21951.09851.03100.94150.94970.95411.01531.06011.06191.06351.09501.11051.18711.19771.11801.12971.20281.35991.42511.23631.15891.18331.21571.23961.20541.24631.19601.2145

Page 3


Calculation of Energy Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.2Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 02/23/12) and WPU0543 Industrial Electric Power (as of 02/23/12)

REBASED TO 1986= 100PPI for Fuels & PPI for Light PPI for Fuels & PPI for LightRelated Products Fuel Oils Related Products Fuel Oils(2000 = 100) (2000=100) (2000 = 100) (2000=100)(P) -industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils

BWR wt = 0.54 BWR wt = 0.46Jan-04 143.1 106.8 1.1312 1.4650Feb-04 143.1 100.8 1.1312 1.3827Mar-04 143.1 107.8 1.1312 1.4787Apr-04 143.1 115.2 1.1312 1.5802

May-04 144.2 116 1.1399 1.5912Jun-04 152.4 111.5 1.2047 1.5295Jul-04 152.2 119.3 1.2032 1.6365

Aug-04 154.0 131.1 1.2174 1.7984Sep-04 154.0 136.8 1.2174 1.8765Oct-04 145.8 161.7 1.1526 2.2181Nov-04 144.9 153.6 1.1455 2.1070Dec-04 146.2 133.8 1.1557 1.8354Jan-05 148.9 138.5 1.1771 1.8999Feb-05 148.0 146 1.1700 2.0027Mar-05 148.1 169.4 1.1708 2.3237Apr-05 148.7 170.9 1.1755 2.3443

May-05 151.1 165.3 1.1945 2.2675Jun-05 159.7 180.6 1.2625 2.4774Jul-05 162.1 186.2 1.2814 2.5542

Aug-05 162.5 194.5 1.2846 2.6680Sep-05 162.8 209.9 1.2870 2.8793Oct-05 159.5 252.0 1.2609 3.4568Nov-05 161.1 199.1 1.2735 2.7311Dec-05 161.4 193.6 1.2759 2.6557Jan-06 167.0 191.8 1.3202 2.6310Feb-06 168.6 190.0 1.3328 2.6063Mar-06 167.4 199.2 1.3233 2.7325Apr-06 169.6 221.9 1.3407 3.0439

May-06 170.8 231.4 1.3502 3.1742Jun-06 181.2 238.1 1.4324 3.2661Jul-06 181.9 231.6 1.4379 3.1770


May-07 179.2 225.3 1.4166 3.0905Jun-07 186.7 222.4 1.4759 3.0508Jul-07 187.0 237.8 1.4783 3.2620

Aug-07 187.6 225.5 1.4830 3.0933Sep-07 188.4 238.9 1.4893 3.2771Oct-07 182.7 243.3 1.4443 3.3374Nov-07 180.3 288.2 1.4253 3.9534Dec-07 180.0 266.7 1.4229 3.6584Jan-08 181.9 273.8 1.4379 3.7558Feb-08 180.0 280.2 1.4229 3.8436


for BWR(Humboldt)

1.28481.24691.29111.33781.34751.35411.40251.48461.52061.64271.58781.46841.50961.55301.70111.71311.68811.82131.86691.92102.01942.27101.94401.91061.92311.91861.97152.12422.18922.27592.23792.29252.05421.98081.96441.98081.86961.95842.09192.20162.18662.20032.29882.22372.31172.31512.58822.45132.50422.5364

Page 4


Calculation of Energy Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.2Using Regional Indices SERIES ID: WPU0573 Light Fuel Oils (as of 02/23/12) and WPU0543 Industrial Electric Power (as of 02123/12)

REBASED TO 1986 = 100PPI for Fuels & PPI for Light PPI for Fuels & PPI for LightRelated Products Fuel Oils Related Products Fuel Oils(2000 = 100) (2000=100) (2000 = 100) (2000=100)(P) =Industrial Energy Power (F) = Light Fuel Oils (P) =Industrial Energy Power (F) = Light Fuel Oils

BWR wt = 0.54 BWR wt = 0.46Mar-08 183.1 339.6 1.4474 4.6584Apr-08 185.2 352.5 1.4640 4.8354

May-08 189.5 384.9 1.4980 5.2798Jun-08 191.9 410.5 1.5170 5.6310Jul-08 196.1 423.8 1.5502 5.8134

Aug-08 197.1 343.9 1.5581 4.7174Sep-08 195.9 335.1 1.5486 4.5967Oct-08 193.0 279.0 1.5257 3.8272

Nov-08 187.7 218.2 1.4838 2.9931Dec-08 188.3 163.0 1.4885 2.2359Jan-09 190.3 159.8 1.5043 2.1920Feb-09 190.3 145.6 1.5043 1.9973Mar-09 187.6 136.8 1.4830 1.8765Apr-09 186.9 159.9 1.4775 2.1934

May-09 190.5 158.6 1.5059 2.1756Jun-09 193.3 183.7 1.5281 2.5199Jul-09 196.2 165.2 1.5510 2.2661


May-10 192.0 226.0 1.5178 3.1001Jun-10 197.8 212.4 1.5636 2.9136Jul-10 199.8 209.3 1.5794 2.8711


May-11 196.9 315.1 1.5565 4.3224Jun-11 205.7 316.9 1.6261 4.3471Jul-11 215.3 311.5 1.7020 4.2730

Aug-11 216.6 296.9 1.7123 4.0727Sep-11 215.8 306.5 1.7059 4.2044Oct-11 205.3 299.4 1.6229 4.1070Nov-11 205.1 323.7 1.6213 4.4403Dec-11 204.0 301.5 1.6126 4.1358


for BWR(Humboldt)

2.92453.01493.23773.40943.51133.01142.95072.58442.17811.83231.82071.73111.66401.80681.81401.98431.87992.06852.00942.03042.10522.04022.18792.05772.17612.26672.24572.18462.17362.25422.24202.31862.36282.39452.46742.58912.77272.88002.82882.87772.88462.79812.85522.76562.91812.7733

Oct 11 through Dec 11 are Preliminary Values from PPI Indices

Page 5

Development of L Component Enclosure 2PG&E Letter HBL-12-006

Calculation of Labor Escalation Factor - Reference NUREG-1 307, Revision 14, Section 3.1Using Regional Indices SERIES ID: CIU20100000002401 (as of 02/23/12)Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.

Employment Cost IndustWest Region LaborPrivate Industry Escalation(2005=100) Factor

Dec-05 100 2.06000Jan-06Feb-06Mar-06 100.6 2.07236Apr-06May-06Jun-06 101.8 2.09708Jul-06

Aug-06Sep-06 102.5 2.11150Oct-06Nov-06Dec-06 103 2.12180Jan-07Feb-07Mar-07 104.2 2.14652Apr-07

May-07Jun-07 104.9 2.16094Jul-07

Aug-07Sep-07 105.7 2.17742Oct-07Nov-07Dec-07 106.5 2.19390Jan-08Feb-08Mar-08 107.8 2.22068Apr-08May-08Jun-08 108.4 2.23304Jul-08

Aug-08Sep-08 109.3 2.25158Oct-08Nov-08Dec-08 109.4 2.25364Jan-09Feb-09Mar-09 109.9 2.26394Apr-09

May-09Jun-09 110 2.26600Jul-09

Aug-09Sep-09 110.3 2.27218Oct-09Nov-09

Page 6

Development of L Component Enclosure 2PG&E Letter HBL-12-006

Calculation of Labor Escalation Factor - Reference NUREG-1307, Revision 14, Section 3.1Using Regional Indices SERIES ID: CIU20100000002401 (as of 02/23/12)Note 1: The Base Labor factor was re-indexed in December 2005, at which time the index was reset to 100.

Employment Cost IndustWest Region LaborPrivate Industry Escalation(2005=100) Factor

Dec-05 100 2.06000Dec-09 110.6 2.27836Jan-10Feb-10Mar-10 111.3 2.29278Apr-1 0

May-10Jun-10 111.7 2.30102Jul-10

Aug-10Sep-10 112.3 2.31338Oct-10Nov-1 0Dec-10 112.5 2.31750Jan-11Feb-11Mar-11 113.5 2.33810Apr-11May-11Jun-11 114.3 2.35458Jul-1i

Aug-11Sep-11 114.6 2.36076Oct-11Nov-11Dec-11 115.1 2.37106

Page 7

Development of B Component Enclosure 2 Enclosure 2PG&E Letter HBL-12-006

Development of Burial EscalationDeveloped from NUREG-1 307 Revision 14Table 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 are assumed to be thje same as that provided for the Atlantic Compact,for lack of a better alternative at this time

BWR BWRBurial Costs Restated to(South Carolina) 1986 = 100

198619871988198919901991199219931994199519961997199819992000200120022003200420052006200720082009201020112012

1.561

1.831

2.361

9.4349.79410.42

10.37913.83713.948

16.24416.47416.70517.32617.97019.33920.81322.39922.50423.40424.35625.35526.394

1.0000

1.1730

1.5125

6.04366.27426.67526.64898.86428.93530.0000

10.406110.553510.701511.099311.511912.388913.333114.349114.416414.993115.602816.242516.9085

Table 2.1 Note ('c) From 7/1/95 through 6/30/2000 access was allowed for all states except North Carolina. Effective7/11/2000 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 calculatedby applying the average % change between 2000 and 2002 and adding to the 2000 base


2005 has no information in NUREG-1307 Rev 12. 2005 is an estimate that is calculatedby applying the average % change between 2004 and 2006 and adding to the 2004 base.





2011 has no information in NUREG-1 307 Rev 14. 2011 is an estimate that is calculated byapplying the average % change between 2008 and 2010 and adding to the 2010 base

2012 has no information in NUREG-1307 Rev 14. 2012 is an estimate that is calculated byapplying the average % change between 2008 and 2010 and adding to the 2011 estimate

Page 8


Humboldt Bay Power Plant Unit 3Decommissioning Cost Study

Area-By-Area Estimate(7 pages)

Humboldt Bay Po-er Plant Unit 3 Ebn-e 3

DecomLioning Cost Study PG&E Letter HBL-12-006TLG Services Io, Appendix D

Humboldt Bay Power Plant, Unit 3

AREA-BY-AREA ESTIMATE

I

Humbokdt Bay Poer Pta,, UM 3 Encl-e 3Deconrrftonhn Cos Study PG&E Lefer HBL-I2-006TLG S1e- oft, Appeod' 0



4Z.4.1

Humboldt Bay P0owr Plant Unit 3Demoiolnasoing Cogt Study"TLG C•t •n Ino. Appendix D

Activity

Index Actiity Do,

40,12.1 R82-74b.t.2.2 R82-84b,1.2.3 R82-94b,1.2.4 RWt-14b.1 2.5 RW1-20b .21.6 RW1-34b.1.2.7 RW1-44b.1.2.8 RWt.5

4b,1.2.9 RWI-640.1.2.10 RWl-745.1.2_11 RWI-84b.1.2.12 RWl-941..2.13 RWP4b.1.2 Tota]s

40.1.3 Smeffoldion in soe of deon

4b.1 Suotal 1Perod 41 Aii Co

Perod 4b Additional Coots

t41,2,2 AsbetosRemv0 .2.3 Exan Ellt !nk~ol La,

Endlosuee 3PG&E Letter HBL-12-006

14.1

HumbOddl Bay Po Plant Unit 3 End e 3Deorrlttnisslonwng COwt Study PG&E Letter HBL-124)D

TLG Seroe Ito. Apperfd- D

Ilumboldt Bay Power Plant, Unit 3


H-wbm ld Oey Mwee PO d VI3Oo-Z[vO Coml Study

TLG Sews-. le. Appendec D

E-1lo-uee 3PG&E Letter HBL-12-006


Hunbeldt Day Po-~e Plant Uni 3 Enlosts,, 3Deommssoning Cost Study PG&E Lete HBL-12-006TLG Scrcs Inc. AyppndN D

Humboldt Bay Power Plant. Unit 31

Humboldt Bay Power Pant Unit 3 Encloure 3D -onniseonrng Cost Study PG&E Letter HBL-12-•OTLG Serices Inc. Appendix D




Humboldt Bay Power Plant Unit 3Decommissioning Cash Flow

(Estimated in 2012 Dollars)(1 page)

Humboldt Bay Power Plant Unit 3Decommissioning Cash Flow (Note 1)

(Estimated in 2012 Dollars)


Non-NRCNRC Scope Scope (Non-

(Radiological) Radiological)Year

1996199719981999200020012002200320042005200620072008200920102011201220132014201520162017201820192020

$1,678,452$8,663,216$5,573,757

$723,490$85,241$89,543

$994,127$494,838$491,070$161,506

$1,073,612$4,474,247

$12,590,383$32,901,391$56,957,494$60,585,531$76,442,100$81,341,000$47,849,900$42,355,200

$5,770,152$0$0$0

$3,436,072

ISFSIEngr/LicenseConstruction

Operation(Note 1)

$344,408$2,281,454$2,736,091

$398,012$113,704

$2,539,476$1,444,628$1,671,769$3,546,617$9,240,172

$28,485,988$3,179,956$5,734,776$5,495,157$5,354,800$5,354,800$5,354,800$5,354,800$5,354,800$5,354,800$5,354,800$5,354,800$4,752,385

$114,802,991

Total

$1,678,452$8,663,216$5,918,165$3,004,944$2,821,331

$487,555$1,107,831$3,034,313$1,935,698$1,833,274$4,620,229

$13,714,418$41,076,371$36,081,347$62,692,270$66,080,688$81,796,900$86,695,800$54,528,400$49,033,700$11,321,900$5,354,800$5,354,800$5,354,800$8,188,457

$562,379,660

CummulativeDecommission

Estimate

$1,678,452$10,341,669$16,259,834$19,264,778$22,086,109$22,573,664$23,681,495$26,715,809$28,651,506$30,484,781$35,105,009$48,819,428$89,895,799

$125,977,145$188,669,415$254,750,103$336,547,003$423,242,803$477,771,203$526,804,903$538,126,803$543,481,603$548,836,403$554,191,203$562,379,660

Trust AccountFunding(Note 2)

$254,750,103

$556,511,426$566,044,490

$1,323,700$1,323,700

$196,948

TOTAL $444,732,321 $2,844,348

Notes:1) Cash Flow is based on construction of ISFSI and Fuel removed from HBPP in 2020 (Assumes

DOE Used Fuel Repository opens 2020 allowing HBPP Fuel to be shipped during 2020)2) Trust Account Value of $311.3 million is Expense Equivalent Liquidation Value (Includes Tax Break)

Market Value of Trust as of 12/11 was $301.8 million, actual expended as of 12/11 was $254.8 million

1

-pacific electric gas company' and

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