Text

Submittal of the Decommissioning Funding Status Reports for Beaver Valley, Units 1 and 2, Davis-Besse and Perry, Unit 1
	ML15090A447
Person / Time
Site:	Beaver Valley, Davis Besse, Perry
Issue date:	03/31/2015
From:	Boles B; FirstEnergy Nuclear Operating Co
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	L-15-101
	Download: ML15090A447 (305)
	v • d • e

{{#Wiki_filter:FENOC Fnn Enw liucia I @abnaOonpanF 341 tlVhitePondDr. Akron, Ohio44320 March31,2015 L-15-101 10 cFR 50.75 ATTN:DocUment ControlDesk U.S.NuclearRegulatory Commission Washington, DC 20555-0001

SUBJECT:

BeaverValleyPowerStation,UnitNos.1 and2 DocketNo.50-334,LicenseNo. DPR-66 DocketNo.50-412,LicenseNo. NPF-73 Davis-Besse NuclearPowerStation DocketNo.50-346,LicenseNo.NPF-3 PerryNuclearPowerPlant DocketNo.50-440,LicenseNo.NPF-58 Submittalof the Decommissionino FundinqStatusReportsfor BeaverValleyPower Etation.UnitNos. 1 and 2, Davis-Besse NuclearPowerSt?tion.and PerryNuclear PowerPlant In accordance with 10CFR50.75,"Reporting and recordkeeping for decommissioning planning," paragraph (0(1),FirstEnergyNuclearOperating Company(FENOC)is submitting the decommissioning fundingstatusreportsfor BeaverValleyPowerStation; UnitNos.1 and 2; Davis-Besse NuclearPowerStation;and PerryNuclearPowerPlant. The reportsare containedin Attachments1 through4, respectively. In accordance with 10 CFR50.75(b)and 10 CFR50.75(e), the estimatedcostof decommissioning can be basedon eitherthe NuclearRegulatory Commission (NRC) formulacostamountcalculated in accordance with 10 CFR50.75(c)or a site-specific decommissioning costestimate.lf usedin this report,the site-specific costestimates-- are basedon a periodof safestoragethat is describein the estimate.Site-specific cashflowsbasedon the site-specific decommissioning costestimates,are included,as applicable. FENOChas not madea finaldetermination on the decommissioning approachfor any of the listednuclearunits. FENOCuseseitherthe NRCformulacostamountor the site-specific decommissioning costestimatesto demonstrate adequacyof fundingto meetNRCrequirements. FENOCmayselecta differentdecommissioning optionin the futurefor any of the listednuclearunits,recognizing thatthe chosenoptionmustmeet NRCrequirements for decommissioning funding.

BeaverValleyPowerStation,UnitNos.1 and2 Davis-Besse NuclearPowerStation PerryNuclearPowerPlant L-15-101 Page2 As describedin a letterdatedJuly2, 2014(Accession NumberML141838295), FirstEnergy SolutionsCorp.,on behalfof FirstEnergy Nuclear Generation, LLC, established a parentcompanyguarantee to provideadditionaldecommissioning funding assurance for BeaverValley Power Station,UnitNo. 1, and Perry Nuclear Power Plant. As a resultof the performance decommissioning of a site-specific costestimate each for facility,togetherwith an analysisof the currentfund balancestakingintoaccount earningsduringa periodof safestorage,thisparentcompanyguaranteeis no longer needed.Noticeis herebygiventhatthisparentcompanyguarantee willbe terminated 120daysafterthe electronicsubmittalof this letterin accordancewith Section14 of the parentcompanyguarantee. Thereare no regulatorycommitments containedin this letter. lf thereare any questions,or if additionalinformationis required,pleasecontactMr. ThomasA. Lentz, Manager - FleetLicensing,at (330)315-6810. Sincerely, &->/g* BrianD. Boles Vice President, NuclearSupport Attachments:

1. Decommissioning FundingStatusReport- BeaverValleyPowerStation,UnitNo. 1

2. Decommissioning FundingStatusReport- BeaverValleyPowerStation,UnitNo.2

3. Decommissioning FundingStatusReport- Davis-Besse NuclearPowerStation

4. Decommissioning FundingStatusReport- PerryNuclearPowerPlant

Enclosures:

A. DecommissioningCost Analysisfor the BeaverValleyPower Station, December2AM B. DecommissioningCost Analysisforthe Perry NuclearPowerPlant, February2015

BeaverValleyPowerStation,UnitNos.1 and2 Davis-Besse NuclearPowerStation PerryNuclearPowerPlant L-15-101 Page3 cc: NRCRegionlAdministrator NRCRegionlll Administrator NRCResidentInspector (BeaverValley) NRC Resident (Davis-Besse) Inspector NRC ResidentInspector(Perry) NRCProjectManager(BeaverValley) NRC ProjectManager(Davis-Besse) NRCProjectManager(Perry) DirectorBRP/DEP Site BRP/DEPRepresentative SafetyBoard UtilityRadiological

Attachment1 L-15-101 Decommissioning FundingStatusReport- BeaverValleyPowerStation,UnitNo. 1 Page1 of6 This reportreflectsFirstEnergyCorp.'sconsolidated shareof ownershipinterestin Beaver ValleyPower Station,UnitNo. 1, as of December 31,2014.

1. The minimumdecommissioning fundestimate,pursuantto 10 CFR50.75(c)(see Schedule 1):

FirstEnergy NuclearGeneration, LLC $510,038,480

2. The amountaccumulated in externaltrustfundsas of December31,2014:

After Tax FirstEnergy NuclearGeneration,LLL $270,773,373 3 . Thereare no longerany fundsto be collectedfromthe ratepayers. 4 . The assumptionsusedregardingratesof escalationin decommissioning costs,rates of earningson decommisiioning funds,and ratesof otherfactorsusedin funding projections: Consolidated Ownership Interestin Unit 1A0o/o "Real"Rateof ReturnthroughDismantlement 2.00o/o Yearof LicenseTermination 2036 5 . Thereare no contractsuponwhichthe owners/licensees are relyingpursuantto 10 cFR 50.75(e)(1)(v).

6. Therehasbeenno modification to the currentmethodof providing decommissioning fundingassurance sincethe lastsubmitted report.

7 . Therehavebeenno materialchangesto the applicable trustagreement(s) sincethe lastsubmittedreport. 8 . Mathematical roundingwas performed duringthe development of the supporting calculations. L-15-101 Page2 of 6

9. Site-Specific CostAnalysis 10 CFR50.75(e)(1)(i), states,in part,that:

A licenseethat has prepaidfundsbasedon a site-specific estimateunder S 50.75(b)(1)of thissectionmaytake creditfor projectedearnings on the prepaiddecommissioning trustfunds,usingup to a 2 percentannualreal rateof returnfromthe time of futurefunds'collectionthroughthe projected decommissioning period,providedthatthe site-specific estimateis based on a period of safe storage that is described specifically in the estimate. fn accordance with Regulatory Guide1.159,Revision2, alacilityspecificanalysis maybe usedto demonstrate the adequacyof decommissioning funds,providedthat: NRC-required costestimatefor decommissioning costs,as definedin 10 CFR50.2,is equalto or greaterthanthe amountstatedin the formulas in 10 CFR50.75(c)(1) and(2). Schedule2 providesa FENOCanalysisthatprovidescashflowsbasedon the site-specificdecommissioning costestimatethat includesthe use of a safestorageperiod. The analysisis associated withthe costsfor the radiological decommissioning of the facility.The cashflow analysisassumesthe yearlyexpensesare incurred at the beginningof year. A two percentyearlyrateof returnwas assumed' As a resultof this analysis,FENOChas determinedthat thereis reasonable assurance thatadequatedecommissioning fundswillbe available for the decommissioning processin compliance withNRCdecommissioning funding assuranceregulitions.Therefore, the parent company guarantee that is currentlyin place,whichprovidesadditional decommissioning fundingassurance for the Beaver ValleyPowerStation,UnitNo. 1, is no longerneeded.Thisparentcompany guaranteewill be terminatedin accordancewith the requirements of the parent companyguarantee. 10.

References:

A. Decommissioning CostAnatysisfor the BeaverValleyPowerStation, December2014. Referto Enclosure A. L-15-101 Page3 of 6 Schedule1 FIRSTENERGY CORP. Calculation of MinimumFinancial Assurance Amount December 31,2014 BEAVERVALLEYPOWERSTATION,UNITNO.1 PgnnsvlvaniaReqions Labor(L) = Northeast Energy(E) = National WasteBurial(B) = Generic For PWRUnit Adjustment Escalation Factor Ratio Factorl l-= 2.661 0.65 1.73 f= 2.222 0.13 0.289

                       $=          13.885            0.22            3.055 PWR EscalationFactor =                                              5.074 BaseAmountfor PWRbetween12OO        MWtand 3400MWt = ($75m+ 0.0088P)

(P = powerlevelin megawattsthermal= 2900) ($7S+ 0.0088(2900))million= $100,520,000 EscalatedAmountfor unitl = 100,520,000 x 5.074 $510,038,480 Owner/Licensee Ownershio FirstEnergyNuclear Generation, LLC 100.00% $510,038,480 roundingwas performed Note1: Mathematical duringthe development calculations of the supporting L-15-101 Page4 of 6 Schedule2 Calculationof a Site-specificCashFlowAnalysis December 31,2014 BeaverValleyPowerStation,UnitNo. 1 The site-specificcostestimatefor the radiologicaldecommissioning of the BeaverValley PowerStation,UnitNo. 1 is $673,694,000. The minimum decommissioning fundestimate, pursuantto 10 CFR50.75(c)is $510,038,480. SinceRG 1.159statesthatthe site-specific costshouldbe equalto or greater thanthe cost by 10 CFR50.75(c),the RG is calculated satisfied. A two percentrateof returnwas usedin the analysis.The analysisalsoassumesa period of safestorage.Theseinputsto the analysisare consistent with 10 CFR50.75(e)(1). The analysisis basedon 2014dollars. The analysiscontainsexpensesbasedon the site-specific decommissioning cost estimate.The analysisconservatively assumesthat expensesduringa yearare incurredat the beginning of year. Mathematical roundingwas performed duringthe development of the supportingcalculations. Beginning Ending Year Balance Deposits Earninqs Withdrawal Balance 2015 270.773.373 5.415,467 276.188.840 2016 276.188.840 5.523.777 281,712,617 2017 281.712.6',17 5.634,252 287,346,870 2018 287,346,870 5.746.937 293,093,807 2019 293,093,807 5,861,876 298.955,683 2020 298,955,683 5.979.114 304,934,797 2021 304,934,797 6,098,696 311.033,493 2022 311.033.493 6.220.670 317,254,163 2023 317,254,163 6,345,083 323,599,246 2024 323,599,246 6,471,985 330,071,231 2025 330,071,231 6,601,425 336,672,655 2026 336,672,655 6,733,453 343,406,108 2027 343,406,108 6,868,122 350,274,231 2028 350,274,231 7,005,485 357,279,715 2029 357,279,715 7,145,594 364,425,310 L-15-101 Page5 of 6 Beginning Ending Year Balance Deposits Earninqs Withdrawal Balance 2030 364.425.310 7.288.506 371.713.816 2031 371.713.816 7,434,276 379.148.092 2032 379.148.092 7.s82.962 386.731,054 2033 386.731.054 7.734.62'l 394.465,675 2034 394.465.675 7,889,314 402.354,989 2035 402.354,989 8.047.100 410.402,088 2036 410.402.088 7.212.002 (49,802,000) 367.812,090 2037 367.812,090 6.333.382 ( 5 1 , 1 4 3 , 0 0 0 ) 323.002,472 2038 323.O02,472 6.386.529 (3,676,000) 325,713,001 2039 325.713.001 6.440.740 (3,676,000) 328,477,741 2040 328.477,741 6.495.835 (3.686.000) 331,287,576 2041 331.287,576 6.552.232 (3.676.000) 334.163.808 2042 334,163,808 6.609,756 (3.676.000) 337.097,564 2043 337,097,564 6.674,371 (3.379.000) 340.392,935 2044 340,392,935 6.740,599 (3.363.000) 343.770.534 2045 343,770,534 6.808,331 (3,354,000) 347.224,864 2046 347,224,864 6.877,417 (3,354,000) 350.748,282 2047 350.748.282 6,947,886 (3.354.000) 354.342.167 2048 354,342,167 7,019,583 (3.363,000) 357.998,751 2049 3s7.998.751 7,092,895 (3.354,000) 361,737,646 2050 361.737.646 7.167.673 (3,354,000) 3 6 5 , 5 5 1 , 3 1 9 2051 365.551.319 7.243.946 (3,354,000) 369,441,265 2052 369.441.265 7.321.565 (3,363,000) 373,399,830 2053 373.399.830 7.400.917 (3,354,000) 377,446,747 2054 377.446.747 7.481,855 (3,354,000) 381,574,602 2055 381.574,602 7.564.412 (3.354.000) 385.785,014 2056 385,785,014 7,648.440 (3,363,000) 390.070,454 2057 390.070.454 7.734.329 (3,354,000) 394.450.783 2058 394,450.783 7,821.936 (3.354.000) 3 9 8 , 9 1 8 , 7 1 9 2059 398,918.719 7.911.294 (3.354,000) 403.476.013 2060 403.476.013 8.002,260 (3.363,000) 408.115.274 2061 408.115,274 8.095.225 (3.354.000) 412,856,499 2062 412.856.499 8,190,050 (3,354,000) 417,692,549 2063 417.692,549 8.286.771 (3.354,000) 422,625,320 2064 422.625.320 8,385,246 (3,363,000) 427.647,566 2065 427.647.566 8.485.871 (3.354.000) 432.779.438 L-15-101 Page6 of 6 Beginning Ending Year Balance Deposits Earnings Withdrawal Balance 2066 432.779,438 8.588.509 (3,354,000) 438.013.947 2067 438,013,947 8.693.199 (3,354,000) 443.353,145 2068 443,353,'145 8.799.803 (3,363,000) 448.789.948 2069 448,789,948 8.908,719 (3,354,000) 454,344.667 2070 454.344.667 9.019.813 (3,354,000) 460,010,481 2071 460,010,481 9.133,130 (3.354.000) 465,789,610 2072 465,789,610 9.248.532 (3,363,000) 471,675,142 2073 471.675j42 9,366,423 (3.354.000) 477,687,565 2074 477.687.s65 9,486,671 (3.354.000) 483,820,237 2075 483.820.237 9,609,325 (3.354,000) 490.075.561 2076 490.075.561 9,731,751 (3,488,000) 496.319.313 2077 496.319,313 9,856,826 (3.478,000) 502.698.139 2078 502,698.139 9,984,403 (3,478,000) 509.204.542 2079 509.204.542 10.114.531 (3.478,000) 515.841.072 2080 515.841,072 10.247.061 (3.488.000) 522.600.134 2081 522,600j34 10.382.443 (3.478.000) s29.504,577 2082 529,504.577 10.520.532 {3.478.000) 536.547.108 2083 536.547.108 10.661.382 (3.478.000) 543,730,490 2084 543,730,490 10.804,850 (3,488,000) 551,047,340 2085 551,047,340 10.951.387 (3.478.000) 558,520,727 2086 558,520,727 11,100,855 (3.478.000) 566.143.581 2087 566,143,581 11.253.312 (3.478.000) 573.918,893 2088 573,918,893 11,332,858 0.276.000) 577.975.751 2089 577,975,751 10,664,615 A4.745.0041 543.895.366 2090 543.895.366 8.755.647 ( 1 0 6 . 1 1 3 , 0 0 0446.538.013

2091 446.538.013 6,742,500 (109.413,000)343.867.514 2092 343.867,514 5,649,590 (61,388,000) 288j29,104 2093 288j29.'t04 4.847.042 A5.777.000\ 247,199,146 2094 247,199,146 4.881.823 (3.108.000) 248,972,969 2095 248.972.969 4.542.159 (21.865.000) 231,650,'128 2096 231.650,128 4.592.783 ( 2 . 0 1 1 . 0 0 0 ) 234,231,911 2497 234.231.911 4.682.298 (117.000) 238.797.209 Total (673,693,000)

Attachment2 L-15-101 Decommissioning FundingStatusReport- BeaverValleyPowerStation,UnitNo.2 Page1 ot? This reportreflectsFirstEnergyCorp.'sconsolidated shareof ownershipinterestin BeaverValleyPowerStation,UnitNo.2, as of December31,2014.

1. The minimumdecommissioning fundestimate,pursuantto 10 CFR50.75(c)(see Schedule 1):

OhioEdisonGompany $110,474,335 The ToledoEdisonCompany 93,133,026 FirstEnergy NuclearGeneration, LLC 306.431,119 FirstEnergy Consolidated $gloJ3tuao

2. The amountaccumulated in externaltrustfundsas of December31,2014:

After-Tax OhioEdisonCompany $ 83,455,605 The ToledoEdisonCompany 93,550,819 FirstEnergy NuclearGeneration, LLC 170.242.573 FirstEnergy Consolidated sw2&-99[ 3 . Thereare no longerany fundsto be collectedfromthe ratepayers. 4 . The assumptions usedregardingratesof escalation in decommissioning costs,rates of earningson decommissioning funds,and ratesof otherfactorsused funding in projections: Consolidated Ownership Interestin Unit 100o/o "Real"Rateof ReturnthroughDismantlement 2.00o/o Yearof LicenseTermination 2047 5 . Thereare no contractsuponwhichthe owners/licensees are relyingpursuantto 10 CFR50.75(eX1Xv). 6 . Therehas beenno modification to the currentmethodof providingdecommissioning fundingassurancesincethe lastsubmittedreport. 7 . Therehavebeenno materialchangesto the applicable trustagreement(s) sincethe lastsubmittedreport.

8. Mathematical roundingwas performed duringthe development of the supporting calculations.

Attachment2 L-15-101 Page2 of 2 Schedule1 FIRSTENERGY CORP. Calculation of MinimumFinancial Assurance Amount December 31,2014 BEAVERVALLEYPOWERSTATION,UNITNo. 2 PennsvlvaniaReqions Labor(L) = Northeast EnergY(E) = National WasteBurial(B) = Generic For PWRUnit Adjustment Escalation Factor Ratio Factorl l_= 2.661 0.65 1.73 f= 2.222 0.13 0.289

                      $=           13.885            0.22            3.055 PWR EscalationFactor =                                                5.074 BaseAmountfor pwR between1200MWtand 3400MWt= ($75m+ 0.0088P)

(P = powerlevelin megawattsthermal= 2900) ($ZS+ 0.0088(2900)) million= $100,520,000 Escalated Amountfor unitl= 100,520,000 x 5.074 : $510,038,480 Owner/Licensee Ownership OhioEdisonCompanyl 21.660/o $110,474,335 The ToledoEdisonCompanyl 18.260/o $93,133,026 FirstEnergyNuclearGeneration, LLCl 60.08% $306,431,119 TotalFirstEnergyConsolidatedl $510,038,480 roundingwas performed Note1: Mathematical duringthe development calculations. of the supporting

Attachment3 L-15-101 Decommissioning FundingStatusReport- Davis-Besse NuclearPowerStation Page 1 of2 This reportreflectsFirstEnergyCorp.'sconsolidated shareof ownershipinterestin Davis-Besse NuclearPowerStationas of December31,2014.

1. The minimumdecommissioning fundestimate,pursuantto 10 CFR50.75(c)(see Schedule 1):

FirstEnergy NuclearGeneration, LLC $495,954,312

2. The amountaccumulated in externaltrustfundsas of December31,2014:

After-Tax FirstEnergy NuclearGeneration, LLC $513,842,141 3 . Thereare no longeranyfundsto be collectedfromthe ratepayers.

4. The assumptionsusedregardingratesof escalationin decommissioning costs,rates of earningson decommissioning funds,and ratesof otherfactorsusedin funding projections:

Consolidated Ownership Interestin Unit 100o/o "Real"Rateof ReturnthroughDismantlement 2.00o/o Yearof LicenseTermination 2017 Thereare no contractsuponwhichthe owners/licensees are relyingpursuantto 10 CFR50.75(eX1Xv). 6 . Therehasbeenno modification to the currentmethodof providing decommissioning fundingassurance sincethe lastsubmittedreport. 7 . Therehavebeenno materialchangesto the applicable trustagreement(s) sincethe lastsubmittedreport. 8 . Mathematical roundingwas performedduringthe development of the supporting calculations. L-15-101 Page2 of 2 Schedule1 FIRSTENERGY CORP. Calculation of MinimumFinancial Assurance Amount December 31,2014 DAVIS-BESSE NUCLEARPOWERSTATION Ohio Reqions Labor(L) = Midwest Energy(E)= National WasteBurial(B) = Generic For PWRUnit Adjustment Escalation Factor Ratio Factorl l= 2.502 0.65 1.626 f= 2.222 0.13 0.289

                       $=           13.885           0.22            3.055 PWR EscalationFactor =                                              4.970 BaseAmountfor PWRbetween1200MWtand 3400MWt= ($75m+ 0.0088P)

(P = powerlevelin megawattsthermal=2817) ($7S+ 0.0088(2817))million= $ 99,789,600 Escalated Amountfor unitl= 99,789,600 x 4.970 _$1e5,991tr_ Owner/Licensee Ownership FirstEnergyNuclear Generation,LLC 100.00% : $495,954,312 roundingwas performed Note1: Mathematical duringthe development calculations. of the supporting

Attachment4 L-15-101 Decommissioning FundingStatusReport- PerryNuclearPowerPlant Page1 of6 This reportreflectsFirstEnergyCorp.'sconsolidated shareof ownershipinterestin PerryNuclearPowerPlantas of December31,2014.

1. The minimumdecommissioning fundestimate,pursuantto 10 CFR50.75(c)(see Schedule 1):

OhioEdisonCompany $ 85,492,422 FirstEnergy NuclearGeneration, LLC 594,097.578 FirstEnergy Consolidated $0ru*5s*000

2. The amountaccumulated in externaltrustfundsas of December31,2014:

After-Tax OhioEdisonCompany $ 70,808,063 FirstEnergy NuclearGeneration, LLC 415.555.294 FirstEnergy Consolidated $486-3ffi352 3 . Thereare no longerany fundsto be collectedfromthe ratepayers. 4 . The assumptionsusedregardingratesof escalationin decommissioning costs,rates of earningson decommissioning funds,and ratesof otherfactorsusedin funding projections: Consolidated Ownership Interestin Unit 100o/o "Real"Rateof ReturnthroughDismantlement 2.00o/o Yearof LicenseTermination 2026 5 . Thereare no contractsuponwhichthe owners/licensees are relyingpursuantto 10 cFR 50.75(e)(1)(v). 6 . Therehasbeenno modification to the currentmethodof providing decommissioning fundingassurancesincethe lastsubmittedreport. 7 . Therehavebeenno materialchangesto the applicable trustagreement(s) sincethe lastsubmittedreport. 8 . Mathematical roundingwas performed duringthe development of the supporting calculations. L-15-101 Page2 of 6

9. Site-specificCostAnalysis 10 CFR50.75(e)(1)(i), states,in part,that:

A licenseethat has prepaidfundsbasedon a site-specific estimateunder S 50.75(b)(1)of thissectionmaytakecredit for projectedearnings on the prepaiddecommissioning trustfunds,usingup to a 2 percentannualreal rateof returnfromthe time of futurefunds'collectionthroughthe projected decommissioning period,providedthatthe site-specific estimateis based on a period of safestorage that is described specifically in the estimate. In accordance with Regulatory Guide1.159,Revision2, a facilityspecificanalysis maybe usedto demonstrate the adequacyof decommissioning funds,providedthat: NRC-required costestimatefor decommissioning costs,as definedin 10 CFR 50.2,is equalto or greaterthanthe amountstatedin the formulas in 10 CFR50.75(c)(1) and (2). Schedule2 providesa FENOCanalysisthat providescashflowsbasedon the site-specificdecommissioning costestimatethat includesthe use of a safestorage period. The analysisis associatedwiththe costsfor the radiological decommissioning of the facility.The cashflowanalysisassumesthe yearly expensesare incurredat the beginningof year. A two percentyearlyrateof return was assumed. As a resultof thisanalysis,FENOChasdetermined thatthereis reasonable assurance thatadequatedecommissioning fundswillbe available for the decommissioning processin compliance withNRCdecommissioning funding assuranceregulitions. Therefore,the parentcompanyguaranteethat is currentlyin place,whichprovidesadditional decommissioning fundingassurance for Perry NuclearPowerPlant,is no longerneeded.Thisparentcompanyguarantee will be terminatedin accordance withthe requirements of the parent company guarantee. 10.

References:

A. Decommissioning Cost Analysisfor the PerryNuclearPowerPlant, February2015. Referto Enclosure B.

Attachment4 L-15-101 Page3 of 6 Schedule1 FIRSTENERGY CORP. Calculation of MinimumFinancial Assurance Amount December 31,2014 PERRYNUCLEARPOWERPLANT Ohio Reqions Labor(L) = Midwest EnergY(E) = National WasteBurial(B) = Generic For BWR Unit Adjustment Escalation Factor Ratio Factorl l_= 2.502 0.65 1.626 f= 2.255 0.13 0.293 S= 14.160 0.22 3.115 BWR EscalationFactor= 5.034 BaseAmountfor BWRgreaterthan3400M\M = $135,000,000 EscalatedAmountfor unitl = 135,000,000 x 5.034 $679,590,000 Owner/Licensee Ownership OhioEdisonCompany 12.58o/o $ 85,492,422 FirstEnergyNuclear Generation,LLC 87.42o/o $594,097,578 TotalFirstEnergyConsolidated roundingwas performed Note1: Mathematical duringthedevelopment calculations. of the supporting L-15-101 Page4 of 6 Schedule2 Calculation of a Site-SpecificCashFlowAnalysis December31,2014 PerryNuclearPowerPlant The site-specificcostestimatefor the radiological decommissioning of the PerryNuclear PowerPlantis $1,054,131,000. The minimumdecommissioning estimate,pursuant fund to 10 CFR50.75(c)is $679,590,000. SinceRG 1.159statesthatthe site-specific cost shouldbe equalto or greater thanthe costcalculated by 10 CFR 50.75(c), the RG is satisfied. A two percentrateof returnwas usedin the analysis.The analysisassumesa periodof safestorage.Theseinputsto the analysisare consistent with 10 CFR50.75(eX1).The analysisis basedon2014dollars. The analysiscontainsexpensesbasedon the site-specific decommissioning cost estimate.The analysisconservatively assumesthat expensesduringa yearare incurredat the beginning of year. Mathematical roundingwas performed duringthe development of the supporting calculations. Beginning Ending Year Balance Deposits Earnings Withdrawal Balance 2015 486,363,357 9.727.267 496.090.624 2016 496,090,624 9.921,812 506.012.437 2017 506,012.437 10.120.249 516,132,685 2018 516,132,685 10.322.654 526.455.339 20'19 s26,455,339 10.529,107 536.984.446 2020 536,984,446 10,739,689 547.724.135 2021 547,724,135 10,954,483 558.678,617 2022 558,678,617 11.'173,572 569,852,190 2023 569.852.190 l't.397.044 581,249.234 2024 581.249.234 11.624.985 592,874,218 2025 592.874.218 11.857.484 604,731,703 2026 604.731.703 10.943,834 (57.540.000) 558.135.537 2027 558.135,537 9.629.011 (76.685.000) 491.079.547 2028 49't,079.547 9.671,051 ft.527.0001 493.223.598 2029 493,223,598 9.714.352 (7.506,000) 495,431,950 L-15-101 Page5 of 6 Beginning Ending Year Balance Deposits Earnings Withdrawal Balance 2030 495.431.950 9.758.519 (7,506,000) 497.684.469 2031 497.684.469 9,803,569 r.506,000) 499.982.039 2032 499.982.039 9.849.101 0.527.0001 502.304.140 2033 502.304.140 9,937,183 (5,445,000) 506.796.322 2034 506.796.322 10.037.686 (4,912,000) 511.922,009 2035 511.922,009 10.140.200 (4,912,000) 517.150,209 2036 517,150,209 10.244.504 (4.925.000) 522,469,713 2037 522,469.713 10.351,154 (4.912.000) 527,908,867 2038 527,908,867 10.459,937 (4.912.000) 533,456,805 2039 533,456,805 10.570,896 (4.912.000) 539,115,701 2040 539,115,701 10,683,814 (4.925,000) 544.874.515 2041 544,874,515 10.799,250 (4.9'12.000) 550.761.765 2042 550,761,765 10.916,995 (4.912,000) 556.766.760 2043 556,766,760 11,037,095 (4,912,000) 562.891,856 2044 562.891.856 11 , 1 5 9 , 3 3 7 (4.925,000) 569.126,193 2045 569.126.'t93 11,284,284 (4,912,000) 575.498,477 2046 575.498.477 11,411,730 (4,912,000) 581,998,206 2047 581,998,206 11,541,724 (4.912,000) 588.627,930 2048 588.627.930 11.674.059 (4,925,000) 595.376,989 2049 595.376.989 11.809.300 (4,912,000) 602.274,289 2050 602.274,289 11.947.246 (4,912,000) 609,309,534 2051 609.309.534 12.087.951 (4,912,000) 616.485.485 2052 616.485,485 12,231.210 (4.925.000) 623.791.695 2053 623.791,695 12.377.594 (4.912.000) 631.257.289 2054 631,257,289 12.526,906 (4.912.000) 638.872.194 2055 638.872,194 12.679.204 (4.912.000) 646.639.398 2056 646,639,398 12,834,288 (4.925.000) 654.548.686 2057 654,548,686 12.992.734 (4.912.000) 662.629.420 2058 662,629,420 13.154,348 A.912,000\ 670.871.768 2059 670,871,768 13,319,195 (4.912,000) 679.278.964 2060 679.278,964 13.487.079 (4.925.000) 687.841.043 2061 687,841,043 13,658,581 (4,912,000) 696.587.624 2062 696,587,624 13,833,512 (4,912,000) 705.509.136 2063 705.509.136 14.011.943 (4,912,000) 714,609,079 2064 714.609.079 14.193,682 (4.925,000) 723.877.761 2065 723.877.761 14,331,075 ft.324,0001 730.884,836 L-15-101 Page6 of 6 Beginning Ending Year Balance Deposits Earnings Withdrawal Balance 2066 730.884.836 14.471.217 (7.324.000\ 738.032,053 2067 738,032,053 14.614.161 r.324.000) 745.322.214 2068 745.322.214 14.759,544 (7.345.000) 752.736.758 2069 752.736.758 14.908,255 0.324.0001 760,321,013 2070 760,321,013 15.059.940 (7.324.000\ 768.056.953 2071 768.056,953 15.214.659 0.324.0001 775,947,612 2072 775,947.612 15.372.052 (7.345.000) 783.974.665 2073 783,974,665 15.533,013 (7.324,000) 792.183.678 2074 792,183,678 15.697,194 (7.324.000) 800.556.872 2075 800,556,872 15.864,657 r.324.000) 809.097,529 2076 809,097,529 16,035,051 r.345,000) 817.787.580 2077 817,787,580 16.209.272 r.324.000) 826.672.851 2078 826.672.851 16,386,977 r.324,000) 835.735,828 2079 835.735.828 16.568.237 ff,324,000\ 844,980,065 2080 844.980,065 16.224.881 (33,736,000) 827,468,946 2081 827.468.946 14.984.759 (78,231,000) 764,222,705 2082 764.222.705 11.731.314 (177.657.000) 598,297,019 2083 598.297.019 9.480.420 (24.276.0401 483.501.439 2084 483.501.439 7.367.629 ( 11 5 . 1 2 0 , 0 0 0 ) 375,749,068 2085 375,749,068 5.991,321 f6.183.000) 305,557,390 2086 305.557.390 5.926.048 (9,255,000) 3A2,228,437 2087 302.228,437 6.042.649 (e6,o0o) 308.175,086 2088 308,175,086 6j62,802 (35.000) 314,302,888 Total (1.054,130,000)

Enclosure A L-15-101 CostAnalysisfor the BeaverValleyPowerStation, Decommissioning December2014 (157pagesfollow)

Document F07-1696-001.Reu. 0 DECOMMISSIONINGCOSTANALYSIS for the BEAVER VALLEY POWER STATION prepared for FirstEnergy Corp. prepared by TLG Services, Inc. Bridgewater, Connecticut December 2014

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissio n in g Cost An aly si s Page ii of xx APPROVALS Frnj*** }ifslx sr eaf,#d fr{** f t Prsj**f Exgill*er ,4$fl*

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?*sh*ie*I Sfienager rffillism A Cloutier, Jr. I}s** TLG Seruices.Inc.

Beauer VaIIey Power Station Document F07-1696-001,Reu. 0 D ecomm ission ing Cost An aly si s Page iii of xx TABLE OF CONTENTS SECTION PAGE EXECUTIVE

SUMMARY

........... .....vii-xx

1. I N T R OD U C T ION ............ ....1- 1 1.1 Objectivesof Study .....1-1 L.2 SiteDescription....... .....1-z 1.3 RegulatoryGuidance ...1-3 1.3.1 High LevelWaste ..............1-5 I.3.2 Low-LevelRadioactive Waste ............1-8 1.3.3 RadiologicalCriteria for LicenseTermination.......... .........1-9 DECOMMISSIONINGALTERNATIVES ...........2-1 2 . r D E C ON ... .....2- 2 2.L.I Period1- Preparations .....2-2 2.I.2 Period2 - Decommissioning Operations............. ................2-4 2.I.3 Period3 SiteRestoration.............. ...2-8 2.1.4 ISFSI Operationsand Decommissioning ..........2-9 2.2 SAFSTOR ..2-10 2.2.1 Period 1- Preparations ...2-t0 2 .2 .2 P e ri o d2 - D o rma ncy........... ..............2- 11 2.2.3 Periods3 and 4 - DelayedDecommissioning.. .2-12 2.2.4 Period5 - Site Restoration.............. .z-tg

3. cosT ESTIMATES............ ...................

3-1 3.1 Basisof Estimates........... .............3-1 3.2 Me th o d o l o g y............ ..... 3- 1 3.3 Impact of DecommissioningMultiple ReactorUnits ...3-3 3.4 FinancialComponents of the CostModel............... ......3-4 3 .4 .1 C o n ti n g e n cy

                                    .............                                    ........ ..3- 4 3.4.2 FinancialRisk.........                                              ...........3-6 3.5 Site-Specific     Considerations...                                             ......3-7 3.5.1 SpentFuel Management..                                        ..................3-7 3 .5 .2 R e a cto rV e sse l andInter nalCom ponents......... ............. ..3- 10 3 .5 .3 P ri ma ryS yste mC om ponents.............                  ............ ..3- 11 3.5.4 Main Turbine and Condenser.........                                        .3-L2 3 .5 .5 R e ti re dC o mp o n ents..............                        .......... .3- I2 3.5.6 TransportationMethods                                                      .3-L2 TLG Seruices. Inc.

Beauer Valley Power Station Document F07- I 696-001, Reu. 0 D ecommi ssioning Cost An aly sis Page iu of xx TABLE OF CONTENTS (continued) SECTION PAGE 3.5.7 Low-LevelRadioactiveWasteDisposal ...........3-14 3.5.8 Site ConditionsFollowing Decommissioning ..3-15 3 . 6 A ssu mp ti o n s........... i3_15 3.6.1 EstimatingBasis .............3-16 3.6.2 LaborCosts .....3'16 3 .6 .3 D e si g nC o n d i ti o ns............... ..............3- 17 3 .6 .4 Ge n e ra l ............3- 18 3.7 CostEstimateSummarv .......... .3-21

4. SCHEDULEESTIMATE.......... ..........4-1 4.I Schedule Estimate Assumptions........... .......4-l 4.2 ProjectSchedule.. .........4-2

5. RADIOACTIVEWASTES ...5-1

6. RESULTS ...........6-1

7. REFERENCES ......... ............7-r TABLES IntegratedDECON Decommissioning CostElements......... .............xix SAFSTORDecommissioning CostElements......... .............xx 3.1 Integrated DECON Alternative, Total Annual Expenditures,Unit L ...........3-22 3.2 Integrated DECON Alternative, Total Annual Expenditures,Unit 2 ...........3-24 3.3 SAFSTORAlternative,Total Annual Expenditures,Unit 1 ..........................3-25 3.4 SAFSTORAlternative,Total Annual Expenditures,Unit 2 ..........................3-28 5.1 IntegratedDECON AlternativeWasteSummary ............5-5 5.2 SAFSTORAlternativeWasteSummary ...........5-6 6.1 IntegratedDECON Decommissioning CostElements......... .............6-4 6.2 SAFSTORAlternativeDecommissioning CostElements......... ........6-5 TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1690-001,Reu. 0 D ecommissioning Cost Analysis Page u of xx TABLE OF CONTENTS (continued) SECTION PAGE FIGURES 1.1 BeaverValley PowerStationGeneralP1an......... ............1-11 I.2 BeaverValley PowerStationReactorBuilding Section .................1-12 3.1 ManpowerLevels- IntegratedDECONAlternative.............. ..........3-30 3.2 ManpowerLevels- SAFSTORAlternative......... .............3-31 4.1 Activity Schedule - IntegratedDECON .............4-3 4.2 Decommissioning Timeline,IntegratedDECON ..............4-6 4.3 Decommissioning Timeline,SAFSTOR ............4-7 5.1 R a d i oa cti ve Wa steD i sp o si ti on.............. ............5- 3 5.2 DecommissioningWasteDestinations,Radiological ........5-4 APPENDICES A. Unit CostFactorDevelopment........... A-l B. Unit CostFactorListing.... B-f C. DetailedCostAnalysis,IntegratedDECON........... C-l D. DetailedCostAnalysis,SAFSTOR........... D-1 E. DetailedCostAnalysis,ISFSI E-1 TLG Seruices, Inc.

Beauer VaIIey Power Station Document F07-1696-001,Reu. 0 D ecommi ssioning Cost An aly sis Page ui of xx REVISION LOG No. Date Item Revised Reason for Revision 0 r217512014 Original Issue TLG Seruices, Inc.

Beaver VaIIey Power Station Document F07-1696-001,Reu. 0 D eco rnrnission ing Cost An aly si s Page uii of xx EXECUTIVE

SUMMARY

This report presents estimates of the cost to decommissionthe Beaver Valley Power Station (Beaver Valley) for the selected decommissioningscenariosfollowing the scheduled cessation of plant operations. The analysis relies upon site-specific, technical information from an evaluation prepared in 2009,t11updated to reflect current assumptionspertaining to the disposition of the nuclear units and relevant industry experience in undertaking such projects. The current estimates are designedto provide the FirstEnergy Corporation with the information to assessits current decommissioningliability, as it relates to Beaver Valley. The costs are based on several key assumptionsin areas of regulation, component characterization, high-level radioactive waste management, low-Ievel radioactive waste disposal, performance uncertainties (contingency' and site restoration requirements. The analysis is not a detailed engineering evaluation, but an estimate prepared in advanceof the detailed engineering required to carry out the decommissioningof the nuclear unit. It may also not reflect the actual plan to decommissionBeaver Valley; the plan may differ from the assumptions made in this analysis based on facts that exist at the time of decommissioning. The primary goal of decommissioningis the removal and disposalof the contaminated systemsand structures so that the operating licensescan be terminated. This analysis recognizesthat spent fuel will be stored at the site in the wet storagepools and/or in an independent spent fuel storage installation (ISFSI) until such time that it can be transferred to an appropriate disposal facility. Consequently, the estimates include those costsnecessaryto manage and subsequentlydecommissionthese interim storage facilities. The coststo decommissionBeaver Valley for the scenariosevaluated are tabulated at the end of this section. Costs are reported in 2014 dollars and include monies anticipated to be spent for radiological remediation and operating licensetermination, spent fuel management,and site restoration activities. A discussionof 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 timeline for each scenario. 1 "DecommissioningCost Analysis for the BeaverValley Power Station," DocumentF07-1619-002, Rev. 0, TLG Services,Inc., November 2009 TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecomrnission in g Cost An aly sis Page uiii of xx Detailed cost reports used to generate the summary tables contained within this documentare providedin AppendicesC, D and E. The cost estimates assumethat the shutdown dates of the nuclear units are scheduled and pre-planned(i.e.,there is no delay in transitioning the plant and workforce from operationsor in obtaining regulatory relief from operating requirements, etc.). The estimates include the continued operation of the spent fuel buildings as interim wet fuel storagefacilities for approximately seven years after each unit ceasesoperations. During this time period, it is assumedthat the spent fuel residing in the poolswill be transferred to an independent spent fuel storage installation (ISFSI) located on the site. The ISFSI wiII remain operational until the spent fuel is transferred to an appropriate disposalfacility. tzl The cost elements in the estimates for the decommissioning alternatives are assignedto one of three subcategories:U.S. Nuclear Regulatory Commission(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 550.75).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 FueI Management" subcategory contains costs associated with the containerization and transfer of spent fuel from the wet storage pools to an appropriate transport cask or to the ISFSI for interim storage, as well as the transfer of the spent fuel in storage at the ISFSI to a disposal facility. Costs are included for the operation of the storage pools and the management of the ISFSI until such time that the transfer is complete (spent fuel pools will operate until sevenyears afber shutdown of each unit, and the ISFSI until all fuel is transferred to a disposal facility in 2075). It does not include any spent fuel management expensesincurred prior to the cessationof plant operations,nor doesit include any costsrelated to the final disposalof the spent fuel. "Site Restoration" is used to capture costs associatedwith the dismantling and demolition of buildings and facilities demonstrated to be free from contamination. This includes structures never exposedto radioactive materials, as well as those 2 Projected expenditures for spent fuel management identified in the cost analyses do not consider credit for DOE's payment of damages to FirstEnergy for DOE's failure to perform under the terms of the disposalcontract betweenDOE and FirstEnergy. Collectionof spent fuel damages from the DOE is expected to provide the majority of funds neededfor spent fuel management following shutdown. TLG Services, Inc.

Beauer Valley PouserStation Document F07-1696-001,Reu. 0 D ecommissio ning Cost An aly si s Page ix of xx facilities that have been decontaminated to appropriate levels. Structures are removedto a depth of three feet and backfilled to conformto local grade. It should be noted that the costs assigned to these subcategoriesare allocations. Delegationof cost elementsis for the purpose of comparison(i.e.,with NRC fi.nancial guidelines)or to permit specificfinancial 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 decideto removenon-contaminated structures early in the project to improve accessto highly contaminated facilities or plant components.In these instances, the non-contaminatedremoval 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 expectedto be incurred for the specifi.csubcomponentsof the total estimatedprogram cost,if executedas described. Alternatives and Regulations The Nuclear Regulatory Commission (I.IRC) provided general decommissioning requirements in a rule adopted on June 27, 1988. tsl 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 decommissioningalternatives as being acceptableto 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 decontaminatedto a level that permits the property to be released for unrestricted use shortly after cessation of oPerationg."[41 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 qss.rtl5l Decommissioningis required to be completedwithin 60 years, although U.S. Codeof Federal Regulations,Title 10,Parts 30, 40, 50, 51, 70 and 72 "General Requirementsfor DecommissioningNuclear Facilities," U.S. Nuclear Regulatory Commission,Federal Register Volume 53, Number 123 (p 24018et seq.),June 27, 1988 4 Ibid. Page FR24022, Coiumn 3 5 Ibid. TLG Services, Inc.

Beauer VaIIey Pouter Station Document F07-1696-001,Reu. 0 D ecommissio n ing Cost An aly sis Page x of xx longer time periodswill be consideredwhen necessaryto protect public health and safety. ENTOMB is defined as "the alternative in which radioactive contaminants are encasedin a structurally long-lived material, such as concrete; the entombed structure is appropriately maintained and continued surveillance is carried out until the radioactive material decaysto a level permitting unrestricted releaseof the property."t6lAs with the SAFSTORalternative, decommissioningis currently required to be completed within 60 years, although longer time periods will also be consideredwhen necessaryto protect public health and safety. The 60-year restriction has limited the practicality for the ENTOMB alternative at commercial reactors that generate signifi.cant amounts of long-livedradioactivematerial. In 1997,the Commissiondirectedits staff to re-evaluate this alternative and identifr 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 completionof additional researchstudies (e.g.,on engineeredbarriers). In 1996,the NRC published revisions to its general requirements for decommissioning nuclear power plants to clarifr ambiguities and codifr proceduresand terminology as a means of enhancing efficiency and uniformity in the decommissioningprocess.tflThe amendments allow for greater public participation and better defi.nethe transition process from operations to decommissioning. Regulatory Guide 1.184, issued in October 2OI3, further describedthe methods and proceduresthat are acceptableto the NRC staff for implementing the requirements of the 1996 revised rule that relate to the initial activities and the major phasesof the decommissioningprocess. The costs and schedulespresented in this analysis follow the general guidance and sequencein the amended regulations. The format and content of the estimates is also consistent with the recommendations of Regulatory Guide I.202, issued February 2005.t8l b Ibid. Page FR24023, Column 2 7 U.S. Codeof Federal Regulations,Title 10,Parts 2, 50, and 51, "Decommissioningof Nuclear Power Reactors,"Nuclear Regulatory Commission,Federal RegisterVolume 61, (p 39278et seq.),July 29, 1996 "Standard Format and Content of DecommissioningCost Estimates for Nuclear Power Reactors," Regulatory Guide 1.202,Nuclear Regulatory Commission, February 2005 TLG Seruices, Inc.

Beauer Valley Power Station Docurnent F07-1696-001,Reu. 0 D ecommissioning Cost Analysis Page xi of xx Decommissioning Scenarios Tlwo decommissioning scenarios were evaluated for the Beaver Valley nuclear units. The scenarios selected are representative of alternatives available to the owner and are defined as follows:

1. The first scenario(DECON alternative) assumesthat the decommissioning of the Beaver Valley site will be a coordinatedeffort between both units. Unit 1 will be decommissionedupon the final shutdown of Unit 2, thereby avoiding performing decommissioningoperations adjacent to an operational unit. This combinedeffort for the site will be referred to as IntegratedDECON.

2. In the secondscenario (SAFSTOR alternative), the nuclear units are placed into safe-storageat the end of their current operating Licenses.Decommissioningis deferuedto the maximum extent (approximately 50 years for Unit 1) such that the licensesfor both units are terminated within the required 60-yearperiod.

Spent fuel storage operations continue at the site until the transfer of the fuel to an appropriate disposalfacility is complete,assumedto be in the yeat 2075. Methodolos.v The methodology used to develop the estimates follows the basic approach originally presented in the cost estimating guidelines tsl developed by the Atomic Industrial Forum (now Nuclear Energ5rInstitute). This reference describes a unit cost factor method for estimating decommissioningactivity costs. The unit cost factors used in this analysis incorporate site-specificcosts 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 ensuresa high degreeof confidencein the reliability of the resulting costs. Contingencv Consistent with cost estimating practice, contingencies are applied to the decontamination and dismantling costs developed as "specific provision for unforeseeableelementsof cost within the definedproject scope,particularly important where previous experience relating estimates and actual costs has shown that e T.S. LaGuardia et al,, "Guidelinesfor Producing CommercialNuclear Power Plant Decommissioning CostEstimates,"AIFAtrESP-036, May 1986 TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 Decomtnissioning Cost Analysis Page xii of xx unforeseeable events which will increase costs are likely f,6 egs111."[10] The cost elements in the estimates are based on ideal conditions; therefore, the t5,pesof unforeseeableevents that are almost certain to occur in decommissioning,based on industry experience,are addressedthrough a percentagecontingencyapplied on a line-item basis.This contingencyfactor is a nearly universal elementin all large-scale constructionand demolition projects.It should be noted that contingency,as used in this analysis, does not account for price escalation and inflation in the cost of decommissioningover the remaining operating life of the station. Contingencyfunds are expectedto be fully expendedthroughout the program. As such, inclusion of contingency is necessaryto provide assurancethat sufficient funding will be available to accomplishthe intended tasks. Low-LevelRadioactiveWaste 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 passageof the "Low-Level Radioactive Waste Disposal Acf in 1980 and its Amendments of 1985, ttil the states becameultimately responsiblefor the disposition of low-level radioactive waste generated within their own borders. It was expected that groups of states would combine together to jointly deal with their radioactive wastes;theseorganizationsare referredto as waste disposalcompacts. Few approved facilities for the disposal of LLW are currently available. Construction of the newest facility, in Texas, is now complete and the facility was declared operational by the operator, Waste Control Specialists (WCS), in November 2011. The facility will be able to accept limited quantities of non-Compactwaste; however, at this time the cost for non-Compactgeneratorsis being negotiatedon an individual basis. All options and services currently available to FirstEnergy for disposition of the various waste streams produced by the decommissioningprocesswere considered. The majority of the low-level radioactive waste designatedfor direct disposal (Class A t121) can be sent to EnergySolutions'facility in Clive, Iltah. Therefore, disposal costsfor Class A waste were based upon FirstEnergy's Life of Plant Agreemenlwith Project and Cost Engineers' Handbook, SecondEdition, American Associationof Cost Engineers, Marcel Dekker, Inc., New York, New York, p. 239. It "Low-Level RadioactiveWaste Policy AmendmentsAct of 1985,"Public Law 99-240,January 15, 1986 t2 Waste is classifiedin accordancewith U.S. Codeof Federal Regulations,Title 10, Part 61.55 TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001, Rev. 0 D ecom.missioning Cost Analysis Page xiii of xx EnergySolutions.This facility is not licensed to receive the higher activity portion (ClassesB and C) of the decommissioning waste stream. The Texas facility is licensed to receivethe higher activity waste forms (ClassesB and C). As such, for this analysis, disposal costs for the Class B and C waste were based upon the preliminary and indicative information on the cost for such from WCS. The dismantling of the componentsresiding closest to the reactor core generates radioactivewaste that may be consideredunsuitable for shallow-land disposal (i.e., low-level radioactive waste with concentrations of radionuclides that exceed the Iimits establishedby the NRC for Class C radioactive waste, or greater than Class C (GTCC)). The Low-Level Radioactive Waste Policy Amendments Act of 1985 assignedthe 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 reasonablecosts of disposing of such waste. However, to date, the federal government has not identified a cost for disposingof GTCC or a schedulefor acceptance. For purposes of this analysis, the GTCC radioactive waste is assumed to be packaged and disposed of in a similar manner as high-Ievel waste and at a cost equivalent to that envisionedfor the spent fuel. The GTCC is packagedin the same canisters used for spent fuel and either stored on site or shipped directly to a disposal facility as it is generated (depending upon the timing of the decommissioningand whether the spent fuel has been removed from the site prior to the start of decommissioning). A significant portion of the waste material generated during decommissioningmay only be potentially contaminated by radioactive materials. This waste can be analyzed on site or shipped off site to licensed facilities for further analysis, processing and/or conditioning/recovery. Reduction in the volume of low-level radioactive waste requiring disposal in a licensed low-level radioactive waste disposal facility can be accomplished through a variety of methods, including analysesand surveys or decontaminationto eliminate the portion of waste that does not require disposal as radioactive waste, compaction,incineration or metal melt. The estimates reflect the savings from waste recovery/volumereduction. Material removed during decommissioningthat is less than the site release criteria will be designatedfor conventionaldisposalor reuse / recovery. TLG Seruices. Inc.

Beauer Valley Pouter Station Docurnent F07-1696-001,Reu. 0 D ecom.missioning Cost Analy sis Page xiu of xx Hish-LevelRadioactiveWasteManasement Congresspassed the "Nuclear Waste Policy Act"t13l(NWPA) in 1982, assigning the federal government'slong-standingresponsibility for disposalof the spent nuclear fuel createdby 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 servicesfor that material. NWPA, along with the individual contracts with the utilities, specifi.edthat 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 acceptany spent fuel or high level waste, as required by the NWPA and utility contracts. Delays continue and, as a result, generators have initiated legal action against the DOE in an attempt to obtain compensationfor DOE's partial breach of contract. To date no spent fuel has been acceptedfrom commercialgeneratingsites for disposal. The NRC's review of DOE's license application to construct a geologicrepository at Yucca Mountain was suspended in 2011 when the Administration slashed the budget for completing that work. However, the US Court of Appeals for the District of Columbia Circuit recently issued a writ of mandamus (in August 2013) t141 ordering NRC to comply with federal law and restart its review of DOE's Yucca Mountain repository license application to the extent of previously appropriated funding for the review. That review is now underway. The current schedulecalls for completion and publication of the safety evaluation report by January 2015. The adjudicatory hearing, which must be completed before a licensing decision can be made,remains suspended In 2010 the administration appointed a Blue Ribbon Commission on America's Nuclear Future (Blue Ribbon Commission) to make recommendations for a new plan for nuclear waste disposal. The Blue Ribbon Commission'scharter includes a 13 "Nuclear Waste Policy Act of 1982and Amendments,"DOE's Office of Civilian Radioactive Management,I9B2 T4 United States Court of Appeals for the District Of Columbia Circuit, In Re: Aiken County, et al, August 2013 http://www.cadc.uscourts.gov/internet/opinions.nsflBAE0CF34F762EBD985257BC6004DEB l8l$file/11-1271-1451347.pdf TLG Seruices. Inc.

Beauer Valley Pouter Statian Document F07-1696-001,Reu. 0 D ecomrnissio n ing Cost An aly sis Page xu of xx requirement that it consider "[o]ptions for safe storage of used nuclear fuel while final dispositionpathwaysare selectedand deployed."tlsl On January 26, 2012, the Blue Ribbon Commission issued its "Report to the Secretary of Energy" containing a number of recommendationson nuclear waste disposal.Two of the recommendationsthat may impact decommissioningplanning are'.

       "[T]he United States [should] establish a program that leads to the timely developmentof one or more consolidatedstoragefacilities"llGl
       "[T]he United States should undertake an integrated nuclear waste managementprogram that leads to the timely developmentof one or more permanent deep geologicalfacilities for the safe disposal of spent fuel and high-level nuclear rervzsf,s." [171 In January 2013, the DOE issued the "Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste," in response to the recommendationsmade by the Blue Ribbon Commission and as "a framework for moving toward a sustainable program to deploy an integrated system capable of transporting, storing, and disposingof used nuclear              "[i8] This document states:

"With the appropriate authorizations from Congress,the Administration currently plans to implement a program over the next 10 years that: o Sites, designs and licenses, constructs and begins operations of a pilot interim storage facility by 2021 with an initial focus on accepting used nuclear fuel from shut-down reactor sites: o Advances toward the siting and licensing of a larger interim storage facility to be available by 2025 that will have sufficient capacity to provide flexibility in the waste management system and allows for acceptanceof enough used nuclear fuel to reduce expectedgovernmentliabilities; and to Ibid. t6 "Blue Ribbon Commission on America's Nuclear Future, Report to the Secretary of Energy," http://www.brc.govl,p. 32,January 2012 Ibid., p.27 t8 "Strategy for the Managementand Disposal of Used Nuclear Fuel and High-Level Radioactive Waste,"U.S. DOE. Januarv 11.2013 TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommi ssioning Cost An aly si s Page xui of xx

     . Makes demonstrable progress on the siting and characterization of repository sites to facilitate the availability of a geologic repository by 204g."trel FirstEnerg;r'scurrent spent fuel managementplan for the Beaver Valley spent fuel is based in general upon:

1) Fuel transferred from the pool to the ISFSI within 7 years of each unit's final shutdown;

2) Fuel will be shipped in the Transnuclear dry shielded storagecanisters (DSCs),and

3) Availability of a DOE storage repository by 2025. First shipment of fuel from the Beaver Valley site occurs four years after DOE initial availability.

Completion of the Beaver Valley decommissioningprocess is dependent upon the DOE's ability to remove spent fuel from the site in a timely manner. DOE's repository program assumesthat spent fuel allocationswill be acceptedfor disposal from the nation's commercial nuclear plants, with limited exceptions,in the order (the "queue") in which it was dischargedfrom the reactor.t20lFirstEnergy's current spent fuel managementplan for Beaver Valley spent fuel assumedin this estimate is based in general upon: I) a 2025 start date for DOE initiating transfer of commercial spent fuel to a federal facility (not necessarilya final repository),and 2) expectationsfor spent fuel receipt by the DOE for the Beaver Valley fuel. The DOE's generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. Assuming a maximum rate of transfer of 3,000 metric tons of uranium (MTu)/year,[21J 11t"removal of spent fuel from the site is completedin 2075. Different DOE acceptanceschedulesresult in different completion dates. l9 Ibid., p.2 20 In 2008, the DOE issued a report to Congressin which it concludedthat it did not have authority, under present law, to acceptspent nuclear fuel for interim storagefrom decommissionedcommercial nuclear power reactor sites. However, the BIue Ribbon Commission, in its final report, noted that:

   "[A]ccepting spent fuel according to the OFF [Oldest FueI First] priority ranking instead of giving priority to shutdown reactor sites could greatly reduce the cost savings that could be achieved through consolidated storage ifpriority could be given to accepting spent fuel from shutdown reactor sites before acceptingfuel from still-operating plants. .... The magnitude of the cost savings that could be achieved by giving priority to shutdown sites appears to be large enough (i.e., in the billions of dollars) to warrant DOE exercising its right under the Standard Contract to move this fuel first."

27 'Acceptance Priority Ranking & Annual Capacity Report," DOE/RW-0567,July 2004 TLG Seruices, Inc.

Beauer Valley Power Station Docurnent F07-1696-001,Reu. 0 D ecommissioning Cost Analy sis Page xvii of xx The NRC requires that licenseesestablish a program to manage and provide funding for the caretaking 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).t221 This requirement is prepared for through inclusion of certain cost elements in the decommissioningestimates,for example,associatedwith the isolation and continued operationof the spent fuel pool and the ISFSL The spent fuel pools are expectedto contain freshly discharged assemblies(from the most recent refueling cycles) as well as the final reactor core at shutdown. Over the following sevenyears,the assembliesare packagedinto DSCs for transfer to the ISFSI for interim storage. It is assumed that this period provides the necessarycooling for the final core to meet the storage requirements for decayheat. An ISFSI, operated under a Part 50 General License (in accordancewith 10 CFR 72, Subpall (tz3l), has been constructedto support continued plant operations.The facility is assumed to be expanded to support decommissioning. This will allow decommissioningactivities to proceedwithin the fuel buildings. FirstEnerry's position is that the DOE has a contractual obligation to accept Beaver Valley's fuel earlier than the projections set out above consistent with its contract commitments. No assumption made in this study should be interpreted to be inconsistent with this claim. However, including the cost of storing spent fuel in this study is appropriate to ensure the availability of sufficient decommissioningfunds at the end of the station's life if the DOE has not met its obligation. 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 unreasonableto 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 processis deferred. This estimate assumes that some site features will remain following the decommissioningproject. These include the existing electrical switchyard, which is U.S. Codeof Federal Regr.rlations,Title 10,Part 50, "DomesticLicensing of Productionand Utilization Facilities," Subpart 54 Ob), "Conditions of Licenses" U.S. Codeof Federal Regulations,Title 10, Part 72, Subpart K, "General Licensefor Storageof Spent Fuel at Power ReactorSites." TLG Seruices, Inc,

Beaver Valley Power Station Document F07-1696-001,Reu. 0 D ecom,missioning Cost Analy sis Page xuiii of xx assumed to remain functional in support of the regional electrical distribution system.The existing shoreline,canals and ponds will also be left intact. Consequently,this study assumesthat non-essential site structures addressedby this analysis are removed to a nominal depth of three feet below the local grade level wherever possible.The site is then graded and stabilized. Summarv The estimates to decommission Beaver Valley assume the removal of all contaminated and activated plant componentsand 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 commercialprocessorfor treatment/conditioning or to a controlled disposal facility. Decommissioningis accomplishedwithin 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 an appropriate disposal facility is complete. Once emptied, the storage facility can also be decommissioned. The alternatives evaluated in this analysis are described in Section 2. The assumptions are presented in Section 3, along with schedulesof annual expenditures. The major cost contributors are identified in Section 6, with detailed activity costs, waste volumes,and associatedmanpowerrequirementsdelineatedin AppendicesC, D and E. The major cost componentsare also identified in the cost summary provided at the end of this section. As noted within this document, the estimates were developedand costs are presented in 2014 dollars. As such, the estimates do not reflect the escalation of costs (due to inflationary and market forces)over the remaining operating Lifeof the plant or during the decommissioningperiod. TLG Services, Inc.

Beauer VaIIey Power Station Document F07- 1696-001, Reu. 0 D ecommissio n ing Cost An aly si s Page xix of xx INTEGRATED DECONDECOMMISSIONINGCOSTELEMENTS (thousands of $2014) CostElement Il+lt?---",r Total 72,184 :*-*-aeJa-q lgoi91--___?I&1ll 21.531 44,18r tron 19.070 15,239 34,309 Waste 67,686 56.731 L24,4L7 Off-site Waste 31,430 30,703 62,1 33 m Manasemsnf ltl 245,543 256,542 502,084 53.428 86.564 139.991 ipent _FuelPool Isolation t2.434 8.290 20.724 ipent Fuel Manasement [2] 103.831 61.643 765.474 I4sq{4pce^and Regulatory Fees 34.381 19.937 54,318 v 18,380 15,091 33.47A Characterization and Lice 20.2r4 19 138 39,352 rertv Taxes T4 16.585 39,399 Miscellaneous 9,688 7.274 16,962 Corp-grateA&G 34,466 19.672 54.r37 Total Isl 828,288 783.916 t.6L2.204 CostElement LicenseTermination 558,713 582.292 1.141. 005 SpeALIqelManagement 2l2,gl3 L27.832 340.745 Site Restoration 56.661 73.792 130,453 Total t3l 828.288 783.916 I.6L2.204 t1l Includes engineeringcosts

12) Excludesprogram managementcosts(staffrng)but includescostsfor spent fuel loading/transfer/spentfuel pool O&M and EP fees t3l Columns or rows may not add due to rounfing TLG Seruices. Inc.

Beauer VaIIey Power Station Document F07-1696-001,Rev. 0 D ecommissio ning Cost An aly sis Page xx of xx SAFSTORDECOMMISSIONINGCOSTELEMENTS (thousands of $2014) QgetElssle4t--.---." - I u,u!J-* Un*-?- Total Decontamination i 13.864 L4.476 340 Besqy-a-l- *1*1"Q,qgg -r7,917_" ?5-_4,Ql"q Packasin 17.57I 14.724 32,295 IrrusperlaLlss !.7,!?9 ia94q gQ,ry.q Wept"_Djqpgsel_* 57,967 47,7rr r05,677 Off-siteWaste Processing 33.2r4 31,879 65.093 lp"gr^am*M4n4gemenf ttl 270.636 329,273 599,909 Site Securi 107,196 L14,r87 221,383 nt FueI Pool Isolation 12,434 8,290 20,724 Spent Fuel Management [21 102,r24 59,494 161.618 Insurance and &egulatory Eeeg_ 48,228 L08,220 tv 25,889 24.2L2 50.1 01 Characterization and Licensing Surveys r9.727 19.917 39.644 Property-Taxes 34.801 28.573 63.375 Miscellaneous 18.999 18.864 37.863 Qorpgrat_e, A&G 33.929 30.084 64.013 Total tsl 941.543 940.903 1.882.446 CostElement LicenseTermination 673.694 688.602 r,362,296 Spent Fuel Manageme-U! 209.207 t78.692 387,899 Site Restoration 58,641 73.609 132.250 Total tsl 94r.543 940.903 1.882,446 tll Includes engineeringcosts I2l Excludes program management costs (staffrng) but includes costs for spent fuel loading/transfer/spentfuel pool O&M and EP fees t3l Columns or rows may not add due to rounding TLG Seruices,Inc.

Beauer Valley Power Station Document F07-1696-001, Rev. 0 D ecornmi ssion in g Cost Analy sis Section 1, Page 1 of 12

1. INTRODUCTION This report presentsestimatesof the cost to decommissionthe Beaver Valley Power Station (Beaver Valley) for the selected decommissioning scenarios following the scheduledcessationof plant operations.The analysisrelies upon site-specffic, technical information from an evaluation prepared in 2009, tll. updated to reflect current assumptions pertaining to the disposition of the nuclear units and relevant industry experience in undertaking such projects. The current estimates are designed to provide the FirstEnerg5' Corporation with the information to assess its current decommissioningliability, as it relates to BeaverValley.

The analysis relies upon site-specifi.c,technical information compiled by TLG from information provided by FirstEnergSz.The analysis reflects current assumptions pertaining to the disposition of nuclear power plants and relevant industry experience in undertaking such projects. The costs are basedon several key assumptionsin areas of regulation, componentcharacterization, high-level radioactive waste management, low-level radioactive waste disposal, performanceuncertainties (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 decommissioningof the nuclear units. It may also not reflect the actual plan to decommissionBeaver Valley; 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 decommissionBeaver Valley, to provide a sequenceor schedulefor the associated activities, and to develop waste stream projections from the decontaminationand dismantling activities. The original operating license for Unit 1 was issued on January 29,1976. The application for license renewal was approved by the NRC 5 November 2009, with a new licenseexpiration date of January 29,2036. The original operating license for Unit 2 was issued on May 27, L987. The application for license renewal was approved by the NRC on November 5, 2009, with a new license expiration date of May 27, 2047. For purposes of this analysis, the units are assumedto operatethe full sixty years. References provided in Section 7 of the document TLG Seruices.Inc.

Beaver Valley Power Station Document F07-1696-001,Reu. 0 D ecomrnissioning Cost Analy si s Section 1, Page 2 of 12 I.2 SITE DESCRIPTION Beaver Valley is located on the south bend of the Ohio River in Beaver County, 25 miles northwest of Pittsburgh, Pennsylvania. The station is comprised of two essentially identical pressurizedwater reactors with supporting facilities. The Nuclear Steam Supply System (NSSS) for each consists of a pressurized water reactor system designed by Westinghouse Electric Corporation. The reactor coolant system is comprisedof the reactor vessel and three heat transfer loops, each containing a vertical shell and U-tube steam generator, and a vertical centrifugal reactor coolant pump. In addition, the system includes an electrically heated pressurizer, a pressurizer relief tank, and interconnectingpiping and valves. The licensedreactor core power is 2,900 megawatts-thermal (MWt) for each unit, which correspondsto a net maximum dependablecapacity of 892 megawatts electric (MWe) for Unit 1 and 905 MWe for Unit 2. The NSSS is housedwithin the Reactor Building, which is a heavily reinforced concrete, steel-Iined vessel with a flat base mat, cvlindrical walls, and a hemisphericaldome. Heat producedin the reactor is convertedto electrical energy by the Steam and Power Conversion System. A turbine-generator system converts the thermal energy of steam produced in the steam generatorsinto mechanicalshaft power and then into electrical energy. The turbine consistsof a high-pressuredouble flow turbine element, four moisture separator/reheater assemblies,and two double-flow low-pressure turbine elements, all aligned in tandem. The generator is a hydrogen-cooled,rotor-arch-stator unit, driven at 1,800rpm and rated as 1,026 MVA. The turbines are operated in a closed feedwater cycle which condensesthe steam: the heated feedwater is returned to the steam generators.Heat rejected in the main condensersis removedby the circulating water system. The circulating water system provides the cooling water for the main condenserof the turbine generator unit. It is a closed-Ioopsystem consisting of cooling tower pumps, a pump house, circulating water and blowdown piping, main condenser vacuum priming system, mechanical tube cleaning system, and a natural draft cooling tower. Makeup water is supplied to the closedloop circulating waste system by dischargrng the plant service water into the circulating water condenserdischargelines. Figure 1.1 is an excerpt from the Beaver Valley Updated Final Safety Analysis Report (UFSAR), showing the general plant and surrounding environs. Figure 1.2 is also an excerpt from the UFSAR, showing a Reactor Building section view. TLG Services, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommi ssioning Cost An aly sis Section 1, Page 3 of 12 1.3 REGULATORY GUIDANCE The Nuclear Regulatory Commission (NRC or Commission) provided initial decommissioning requirements in its rule "General Requirements for DecommissioningNuclear Facilities," issued in June 1988.t21This rule set forth financial criteria for decommissioninglicensed 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 decommissioningwould be accomplishedin a safe and timely manner and that adequate funds would be available for this purpose. Subsequentto the rule, the NRC issued Regulatory Guide 1.159,"Assuring the Availability of Funds for Decommissioning Nuclear Reactors,"[3] 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 assurancemechanismsindicated in the rule. The rule defined three decommissioningalternatives as being acceptableto 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 decontaminatedto levels that permit the site to be releasedfor unrestricted use shortly after the cessationofplant 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 necessaryto 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 licensetermination. The ENTOMB alternative has not been viewed as a viable option for power reactors due to the significant time required to isolate the long-Iived radionuclides for decay to permissible levels. However, with rulemaking permitting the controlled release of a site,t+l the NRC did re-evaluate the 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 neededbefore this option could be treated as a generic alternative. TLG Seruices, Inc,

Beauer VaIIey Pouser Station Docurnent F07- 1696-001, Reu. 0 D ecomrnissionin g Cost Analy si s Section 7, Page 4 of 12 The NRC had consideredrulemaking to alter the 60-year time for completing decommissioning and to clarify the use of engineered barriers for reactor entombmsnfs.[5J However,the NRC's staff has subsequentlyrecommendedthat rulemaking be deferred, based upon several factors (e.g., no licensee has committed to pursuing the entombment option, the unresolved issues associatedwith the disposition of greater-than-ClassC 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 plants.l0l When the decommissioning regulations were adopted in 1988, it was assumed that the majority of licenseeswould decommissionat the end of the facility's operating licensedlife. Since that time, several licenseeshad permanently and prematurely ceased operations. Exemptions from certain operating requirements were required once the reactor was defueledto facilitate the decommissioning.Each casewas handled individually, without clearly defined generic requirements. The NRC amended the decommissioningregulations in 1996 to clarifu ambiguities and codifit procedures and terminology as a means of enhancing efficiency and uniformity in the decommissioningprocess.The amendments allow for greater public participation and better define the transition processfrom operationsto decommissioning. Under the revised regulations, licenseeswill submit written certification to the NRC within 30 days after the decision to ceaseoperations. Certification will also be required once the fuel is permanently removed from the reactor vessel. Submittal of these notices entitle the licenseeto a fee reduction and eliminate the obligation to follow certain requirements neededonly during operation of the reactor. Within two years of submitting notice of permanent cessationof operations, the licensee is required to submit a Post-Shutdown Decommissioning Activities Report (PSDAR) to the NRC. The PSDAR describesthe planned decommissioningactivities, the associatedsequenceand schedule, and an estimate of expected costs. Prior to completing decommissioning,the licenseeis required to submit an application to the NRC to terminate the license,which includes a licensetermination plan (LTP). In 2011, the NRC published amended regulations to improve decommissioning planning and thereby reduce the likelihood that any current operating facility will become a legacy sifs.tzl The amended regulations require licensees to conduct their operations to minimize the introduction of residual radioactivity into the site, which includes the site's subsurface soil and groundwater. Licenseesalso may be required to perform site surveys to determine whether residual radioactivity is present in subsurface areas and to keep records of TLG Seruices. Inc.

Beauer Valley Pouter Station Docum.ent F07-1696-001,Reu. 0 D ecomrnissio nin g Cost An aly sis Section 1, Page 5 of 12 these surveys with records important for decommissioning. The amended regulations require licensees to report additional details in their decommissioning cost estimate as well as requiring additional financial reporting and assurances. These additional details, including the ISFSI decommissioningestimate, are included in this analysis. 1.3.1 Hieh Level Waste Congress passed the "Nuclear Waste Policy Asf,'t8l (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 NVIPA provided that DOE would enter into contracts with utilities in which DOE would promise to take the utilities' spent fuel and high-level radioactivewaste and utilities would pay the cost of the disposition servicesfor that material. NWPA, along with the individual contracts with the utilities, specifiedthat the DOE was to begin acceptingspentfuel by January 31, 1998. Since the original legislation, the DOE has announcedseveral delaysin 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. Delays continue and, as a result, generators have initiated legal action against the DOE in an attempt to obtain compensationfor DOE's partial breach of contract. To date no spent fuel has been acceptedfrom commercial generating sites for disposal. The NRC's review of DOE's license application to construct a geologic repository at Yucca Mountain was suspended in 20IL when the Administration slashed the budget for completing that work. However,the US Court of Appeals for the District of Columbia Circuit recently issued a writ of mandamus (in August 2013) tel ordering NRC to comply with federal law and restart its review of DOE's Yucca Mountain repository license application to the extent of previously appropriated funding for the review. That review is now underway. The current schedule calls for completion and publication of the safety evaluation report by January 2015. The adjudicatory hearing, which must be completed before a licensingdecisioncan be made,remains suspended In 2010 the administration appointed a Blue Ribbon Commission on America's Nuclear Future @lue Ribbon Commission) to make recommendationsfor a new plan for nuclear waste disposal. The Blue Ribbon Commission'scharter includes a requirement that it consider

            "[o]ptions for safe storage of used nuclear fuel while final disposition pathways are selectedand deployed."tlo1 TLG Seruices.Inc.

Beauer VaIIey Power Station Document F07-1696-001,Reu. 0 D ecornmissio n ing Cost An aly sis Section 1, Page 6 of 12 On January 26, 2012, the Blue Ribbon Commissionissued its "Report to the Secretary of Enerry" containing a number of recommendationson nuclear waste disposal. TWo of the recommendationsthat may impact decommissioning planning are:

                      "[T]he United States [should]establisha program that leadsto the timely developmentof one or more consolidatedstoragefacilities"
                      "[T]he United States should undertake an integrated nuclear waste managementprogram that leads to the timely development of one or more permanent deep geological facilities for the safe disposalof spent fuel and high-levelnuclear $r2sf,s."[111 In January 2013,the DOE issuedthe "Strategy for the Managementand Disposal of Used Nuclear Fuel and High-Level Radioactive Waste," in responseto the recommendationsmade by the Blue Ribbon Commission and as "a framework for moving toward a sustainable program to deploy an integrated system capable of transporting, storing, and disposing of usednuclear fuel..."[tz]This documentstates:
            "With the appropriate authorizations from Congress,the Administration currently plans to implement a program over the next 10 years that:

Sites, designs and licenses,constructs and begins operations of a pilot interim storage facility by 202I with an initial focus on acceptingused nuclear fuel from shut-down reactor sites; Advances toward the siting and licensing of a larger interim storage facility to be available hy 2025 that will have suffi.cient capacity to provide flexibility in the waste management system and allows for acceptanceof enough used nuclear fuel to reduce expectedgovernment liabilities; and

                 . Makes demonstrableprogresson the siting and characterization of repository sites to facilitate the availability of a geologicrepository by 2048;'

FirstEnerry's current spent fuel management plan for the Beaver Valley spent fuel is basedin generalupon:

1) Fuel transferred from the pool to the ISFSI within 7 years of each Unit's final shutdown;

2) Fuel will be shipped in the Transnuclear dry shielded storage canisters(DSCs),and TLG Seruices, Inc.

Beaver VaIIey Power Station Document F07-1696-001,Reu. 0 D ecorntnissioning Cost An aly si s Section 1, Page 7 of 12

3) Availability of a DOE storage repository by 2025. First shipment of fuel from the Beaver Valley site occurs four years after DOE initial availability.

Completionof the Beaver Valley decommissioningprocessis dependent upon the DOE's ability to remove spent fuel from the site in a timely manner. DOE's repository program assumesthat spent fuel allocations will be acceptedfor disposalfrom the nation's commercialnuclear plants, with limited exceptions, in the order (the "queue") in which it was dischargedfrom the reactor. FirstEnergy's current spent fuel management plan for Beaver Valley spent fuel assumed in this estimate is based in general upon: 1) a 2025 start date for DOE initiating transfer of commercial spent fuel to a federal facility (not necessarily a frnal repository), and 2) expectationsfor spent fuel receipt by the DOE for the Beaver Valley fuel. The DOE's generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. Assuming a maximum rate of transfer of 3,000 metric tons of uranium MTtDiyear,ttsl the removal of spent fuel from the site is completedin 2075.Different DOE acceptanceschedulesresult in different completion dates. The NRC requires that licensees establish a program to manage and provide funding for the caretaking of all irradiated fuel at the reactor site until title of the fuel is transferred to the Secretary of Energ;r,pursuant to 10 CFR Part 50.54(bb).tt+1 This requirement is prepared for through inclusion of certain cost elements in the decommissioningestimates, for example,associatedwith the isolation and continued operation of the spent fuel pool and the ISFSI. The spent fuel pools are expectedto contain freshly dischargedassemblies (from the most recent refueling cycles)as well as the final reactor cores at shutdown. Over the following seven years, the assembliesare packaged into dry shielded storage canisters for transfer to the ISFSI for interim storage.It is assumedthat this period provides the necessarycooling for the final coresto meet the storagerequirements for decayheat. An ISFSI, operated under a Part 50 General License (in accordancewith 10 CFR 72, Subpart Kt151), has beenconstructedto supportcontinuedplant operations. The facility is assumed to be expanded to support decommissioning. This will allow decommissioning activities to proceed within the fuel buildings. FirstEnergy's position is that the DOE has a contractual obligation to accept Beaver Valley's fuel earlier than the projections set out above consistent with its contract commitments. No assumption made in this TLG Seruices,Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecornmission in g Cost An aly sis Section 7, Page 8 of 12 study should be interpreted to be inconsistentwith this claim. However, including the cost of storing spent fuel in this study is appropriate to ensure the availability of sufficient decommissioningfunds at the end of the station'slife if the DOE has not met its obligation. I.3.2 Low-LevelRadioactiveWaste 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 passageof the "Low-Level Radioactive Waste Policy Act" in 1980,t161and its Amendments of 1985,t171 the states became ultimately responsible for the disposition of low-level radioactive waste generatedwithin their own borders. It was expectedthat groups of states would combinetogether to jointly deal with their radioactive wastes; these organizations are referred to as waste disposalcompacts. Few approved facilities for the disposal of LLW are currently available. Construction of the newest facility, in Texas, is now complete and the facility was declared operational by the operator, Waste Control Specialists (WCS), in November 2011. The facility will be able to accept limited quantities of non-Compactwaste; however, at this time the cost for non-Compactgeneratorsis being negotiatedon an individual basis. All options and services currently available to FirstEnerry for disposition of the various waste streams produced by the decommissioningprocesswere considered.The majority of the low-level radioactive waste designatedfor direct disposal (ClassA t18l)can be sent to EnergSrSolutions'facility in Clive, Utah. FirstEnergy provided the disposal rates for Class A waste disposal at EnergySolutions. This facility is not licensed to receive the higher activity portion (ClassesB and C) of the waste stream. The Texas facility is licensed to receive the higher activity waste forms (ClassesB and C). As such, for this analysis, disposalcostsfor the Class B and C waste were based upon the preliminary and indicative information on the cost for such from WCS. The dismantling of the componentsresiding closest to the reactor core generates radioactive waste that may be considered unsuitable for shallow-land disposal (i.e., low-level radioactive waste with concentrationsof radionuclides that exceedthe limits establishedby the NRC for Class C radioactive waste, or greater than Class C (GTCC)). TLG Seruices, Inc.

Beauer Valley Power Station Docutnent F07-1696-001,Rev. 0 D ecomm.ission ing Cost An aly sis Section 1, Page 9 of 12 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 beneficiariesof the activities resulting in the generationof such radioactive waste bear all reasonable costs of disposing of such waste. However, to date, the federal government has not identified a cost for disposingof GTCC or a schedule for acceptance. For purposesof this analysis, the GTCC radioactive waste is assumedto be packagedand disposedof in a similar manner as high-level waste and at a cost equivalent to that envisioned for the spent fuel. The GTCC is packagedin the same canisters used for spent fuel and either stored on site or shipped directly to a disposal facility as it is generated (depending upon the timing of the decommissioningand whether the spent fuel has been removed from the site prior to the start of decommissioning). A significant portion of the waste material generated during decommissioningmay only be potentially contaminated by radioactive materials. This waste can be analyzed on site or shipped off site to licensed facilities for further analysis, processing and/or conditioning/recovery.Reduction in the volume of low-Ievel radioactive waste requiring disposal in a licensed low-level radioactive waste disposal facility can be accomplished through a variety of methods, including analyses and surveys or decontamination to eliminate the portion of waste that does not require disposal as radioactive waste, compaction, incineration or metal melt. The estimates reflect the savings from waste recovery/volumereduction. 1.3.3 RadiologicalCriteria for License Termination In 1997, the NRC published Subpart E, "Radiological Criteria for License Termination,"[1e]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 releasedfor unrestricted use if radioactivity levels are such that the averagemember of a critical group would not receive a Total Effective Dose Equivalent (TEDE) in excessof 25 millirem per year, and provided that residual radioactivity has been reduced to levels that are As Low As ReasonablyAchievable (ALARA). The decommissioningestimates assume that the Beaver Valley site will be remediated to a residual level consistent with the NRC-prescribed level. TLG Seruices. Inc,

Beauer Valley Power Station Document F07-1696-001,Rev. 0 D ecornmissio n i ng Cost An aly sis Section 7, Page 10 of 12 It should be noted that the NRC and the Environmental Protection Agency (EPA) differ on the amount of residual radioactivity considered acceptablein 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).tzol An additional and separate limit of 4 millirem per year, as defined in 40 CFR S141.16,is appliedto drinkiniwater.[2l] On October 9,2002,the NRC signedan agxeementwith the EPA on the radiological decommissioning and decontamination of NRC-licensed sites. The Memorandum of Understanding (MOU)tzztprovides that EPA will defer exercise of authority under CERCIA for the majority of facilities decommissionedunder NRC authority. The MOU also includes provisions for NRC and EPA consultation for certain sites when, at the time of license termination, (1) gtoundwater 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 doesnot impose any new requirements on NRC licenseesand should reduce the involvement of the EPA with NRC licenseeswho are decommissioning.Most sites are expectedto meet the NRC criteria for unrestricted use, and the NRC believes that only a few sites will have groundwater or soil contamination in excessof the levels specifiedin 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 Iicensees. The present study does not include any costs for this occurrence. TLG Seruices, Inc.

Beauer VaIIey Power Station Document F07- I 696-001, Reu. 0 D ecommissioning Cost An aly sis Section 1, Page 11 of 12 FIGURE 1.1 BEAVER VALLEY POWER STATION GENERAL PLAN itHIu RI1lE{:t -' i l f f i E* . t t il ri TLG Seruices, Inc.

Beauer VaIIey Power Station Document F07-1696-001, Reu. 0 D ecommissioning Cost Analy sis Section 1, Page 12 of 12 FIGURE 1.2 BEAVER VALLEY POWER STATION REACTORBUILDING SECTION

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                                                            +r tai"Iln TLG Seruices, Inc.

Beauer VaIIey Power Station Document F07-1696-001, Reu. 0 D ecommissioning Cost An aly sis Section 2, Page I of 13

2. DECOMMISSIONING ALTERNATIVES Detailed cost estimateswere developedto decommissionBeaverValley basedupon the approved decommissioningalternatives: DECON and SAFSTOR.Although the alternatives differ with respect to technique,process,cost, and schedule,they attain the sameresult: the ultimate releaseof the site for unrestricted use.

Two decommissioningscenarioswere evaluated for the Beaver Valley nuclear units. The scenariosselectedare representativeof alternatives available to the owner and are defined as follows:

1. The first scenario (DECON alternative) assumesthat the decommissioningof the Beaver Valley site will be a coordinated effort between both units. Unit 1 will be decommissionedupon the final shutdown of Unit 2, thereby avoiding performing decommissioningoperations adjacent to an operational unit. This combinedeffort for the site will be referred to as Integrated DECON.

2. In the second scenario (SAFSTOR alternative), the nuclear units are placed into safe-storage at the end of their current operating licenses.

Decommissioningis deferred to the maximum extent (approximately 50 years for Unit 1) such that the licenses for both units are terminated within the required 60-year period. Spent fuel storageoperations continue at the site until the transfer of the fuel to an appropriate disposalfacility is complete,assumedto be in the year 2075. The following sectionsdescribethe basic activities associatedwith each alternative. Although detailed procedures for each activity identified are not provided, and the actual sequenceof work may vary, the activity descriptionsprovide a basis not only for estimating but also for the expectedscopeof work, i.e., engineering and planning at the time of decommissioning. The conceptual approach that the NRC has described in its regulations divides decommissioninginto three phases. The initial phase commenceswith the effective date of permanent cessationof operations and involves the transition of both plant and licenseefrom reactor operations (i.e., power production) to facility de-activation and closure. During the first phase, notification is to be provided to the NRC certi$zing the permanent cessationof operations and the removal of fuel from the reactor vessel. The licenseeis then prohibited from reactor operation. The secondphase encompassesactivities during the storageperiod or during major decommissioningactivities, or a combination of the two. The third phase pertains TLG Seruices, Inc.

Beauer VaIIey Power Station Document F07-169&001, Reu. 0 D ecommissio ning Cost An aly si s Section 2, Page 2 of 13 to the activities involved in license termination. The decommissioningestimates developed for Beaver Valley are also divided into phases or periods; however, demarcation of the phases is based upon major milestones within the project or significant changesin the projected expenditures. 2 . I D E C ON The DECON alternative, as defined by the NRC, is "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 releasedfor unrestricted use shortly after cessation ofoperations." This study doesnot addressthe costto disposeofthe spentfuel 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 to an off-site disposal facility. The DECON scenariofor the Beaver Valley site includes an abbreviatedperiod of safe storagefor Unit 1 prior to the start of decommissioning.This allows the integration of Unit 1 decommissioningactivities with Unit 2; this combination of the units will be referred to as Integrated DECON. The Unit 1 safe storage processis describedin Section2.2. 2.I.I 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 staffi.ng transition plan, the organization required to manage the intended decommissioningactivities is assembledfrom available plant staff and outside resources. Preparations include the planning for permanent defueling of the reactor, revision of technical specifi.cations applicable to the operating conditions and requirements, a characterization of the facility and major components, and the developmentof the PSDAR. Engineering and Planning The PSDAR, required prior to or within two years of permanent cessationof operations, provides a description of the licensee'splanned decommissioning activities, a timetable, and the associated financial requirements of the intended decommissioningprogram. Upon receipt of the PSDAR, the NRC will make the document available to the public for TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001, Reu. 0 D ecomrn i ssion ing Cost An aly sis Section 2, Page 3 of 13 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 licenseemay begin to perform major decommissioningactivities under a modified 10 CFR 550.59 procedure (10 CFR 550.59 establishesthe conditions under which licenseesmay make changes to the facility or procedures and conduct test or experiments without prior 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) containingGTCC, as definedby 10 CFR 561. Major componentsare further defined as comprising the reactor vessel and internals, Iarge bore reactor coolant system piping, and other large components that are radioactive. The NRC includes the following additional criteria for use of the modified S50.59 process in decommissioning.The proposedactivity must not:

                . foreclosereleaseofthe site for possibleunrestricted use, o   significantlyincreasedecommissioningcosts, o   causeany significant environmental impact, or o   violate the terms of the licensee'sexisting license Existing operational technical specificationsare reviewed and modified to reflect plant conditions and the safety concerns associated with permanent cessationof operations.The environmental impact associated with the planned decommissioning activities is also considered.

Typically, a licenseewill not be allowed to proceedif the consequences of a particular decommissioningactivity are greater than that bounded by previously evaluated environmental assessmentsor impact statements. In this instance, the licenseewould have to submit a licenseamendment for the specificactivity and update the environmental report. The decommissioningprogram outlined in the PSDAR will be designed to accomplish the required tasks within the ALARA guidelines (as defined in 10 CFR S20) 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 procedureswould be assembledto support the proposed decontaminationand dismantline activities. TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecomrnissioning Cost Analysis Section 2, Page 4 of 13 Site Preparations Following final plant shutdown, and in preparation for actual decommissioningactivities, 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 decommissioningoperations can commence on the balance of the plant. The pools will remain operational for approximately seven years following the cessation of each unit's operationsbefore the inventory resident at shutdown can be transferredto the ISFSI. Specification of transport and disposal requirements for activated materials and/or hazardous materials, including shielding and waste stabilization. Development of procedures for occupational exposure control, control and releaseof liquid and gaseouseffluent, processingof radwaste (including dry-active waste, resins, filter media, metallic and non-metallic components generated in decommissioning),site security and emergencyprograms, and industrial safety. Perform chemical decontamination of the Unit 2 NSSS to reduce radiation levels in support of removal operations.Unit 1 dose rate reduction will be accomplishedvia radioactive decay rather than chemical decontamination 2.I.2 Period 2 - DecommissioningOperations This period includes the physical decommissioningactivities associated with the removal and disposal of contaminated and activated componentsand structures, including the successfulrelease of the site from the 10 CFR S50 operating license, exclusive of the ISFSI. Significant decommissioningactivities 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 TLG Seruices, Inc.

Beauer Valley Power Station Docurnent F07-1696-001,Reu. 0 D ecomm.ission in g Cost An aly sis Section 2, Page 5 of 13 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 accessof large/heavy equipment. Modifications will also be required to the refueling area of the reactor building to support the segmentation of the reactor vesselinternals and componentextraction. Transfer of the spent fuel from the storage pools 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. Procurement (lease or purchase) of shipping canisters, cask liners, and industrial packages for the transportation and disposal of low-level radioactive wastes generated during decommissioning. Decontamination of componentsand piping systemsas required to control (minimize) worker exposure. Removal of piping and components no longer essential to support decommissioningoperations. Removal of control rod drive housings and the head service structure from reactor vessel head. Segmentationof the vessel closure head. 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.Somematerial is expectedto exceedClass C disposal requirements. As such, the segments will be packaged in modified fuel storagecanisters for geologicdisposal. Segmentation of the reactor vessel. A shielded platform is installed for segmentation as cutting operations are performed TLG Seruices, Inc.

Beauer Valley Power Station Docannent F07-1696-001,Reu. 0 Decommissioning Cost Analysis Section 2, Page 6 of 13 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. Segmentation of the neutron shield tank and reactor vessel support structure. Removal of the activated portions of the concrete biological shield and accessible contaminated concrete surfaces surrounding the reactor vessel and neutron shield tank. If dictated by the steam generator and pressurizer removal scenarios, those portions of the associatedcubicles necessary for accessand componentextraction are removed. Removal of the steam generators and pressurizer for material recovery and controlled disposal. The generatorswill be moved to an on-site processingcenter, the steam domes removed and the internal components segregated for recycling. The lower shell and tube bundle will be packaged for direct disposal. These components can serve as their own burial containers provided all penetrations are properly sealed. Steel shielding will be added, as necessary, to those external areas of the packageto meet transportation limits and regulations. At least two years prior to the anticipated date of licensetermination, an LTP is required. Submitted as a supplement to the UFSAR 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 completethe decommissioning,and any associatedenvironmental concerns.The NRC will notice the receipt of the plan, make the plan available for public comment, and schedulea local hearing. LTP approval will be subject to any conditions and limitations as deemedappropriate by the Commission.The licenseemay then commencewith the final remediation of site facilities and services, including: Removal of remaining plant systems and associated components as they become nonessential to the decommissioningprogram or worker health and safety (e.g., waste collection and treatment systems, electrical power and ventilation systems). TLG Seruices, Inc.

Beauer Valley Power Station Doeument F0 7-1696-001, Reu. 0 D ecomm issionin g Cost An aly sis Section 2, Page 7 of 13 Removal of the steel liners from refueling canal, disposing of the activated and contaminated sections as radioactive waste. Removalof any activated/ contaminatedconcrete. Surveys of the decontaminated areas of the containment structure. Remediation and removal of the contaminated equipment and material from the auxiliary and fuel buildings 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 componentsftoth clean and contaminated)located within these buildings. This activity facilitates surface decontamination and subsequent verification surveys required prior to obtaining releasefor demolition. Routing of material removed during decontamination and dismantling to a central processingarea. Material certified to be free of contamination is releasedfor unrestricted disposition, as scrap, recycle, or for general disposal. Contaminated material is characterized and segregatedfor additional off-site processing (disassembly,chemical cleaning, volume reduction, and waste treatment), and/or packagedfor controlled disposal at a low-level radioactive waste disposal Incorporated into the LTP is the Final Survey Plan. This plan identifies the radiological surveys to be performed once the decontamination activities are completedand is developedusing the guidanceprovided in the "Multi-Agency Radiation Survey and Site Investigation Manual (MARSSIM)."Iz31 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 confidencethat applicable NRC criteria are satisfied. Once the survey is complete, the results are provided to the NRC in a format that can be 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 Iicenses (that would release the property, exclusive of the ISFSI, for unrestricteduse). TLG Seruices, Inc.

Beauer VaIIey Power Station Doeument F07-1696-001,Rev. 0 D ecomtn issioning Cost An aly sis Section 2, Page 8 of 13 The NRC will amend the operating licenses if it determines that site remediation has been performed in accordancewith 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 Period3 - Site Restoration Following completion of decommissioningoperations, site restoration activities can begin. Efficient removal of the contaminated materials and verification that residual radionuclide concentrationsare below the NRC limits may result in substantial damage to many of the structures. Although performed in a controlled, safe manner, blasting, coring, drilling, scarification (surfaceremoval), and the other decontamination activities will substantially degrade power block structures including the reactor and auxiliary buildings. Under certain circumstances, verif ing 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 necessaryfor those facilities and plant areas where historical records, when available, 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 processand 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 processis deferred. This cost study presumesthat non-essentialstructures 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 establishedfor erosion control. Site areas affected by the dismantling activities are restored and the plant area graded as required to prevent ponding and inhibit the refloating of subsurfacematerials. Non-contaminated concrete rubble produced by demolition activities is processedto remove reinforcing steel and miscellaneousembedments. The processedmaterial is then used on site to backfill foundation voids. TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Rev. 0 D ecommissioning Cost Analysis Section 2, Page I of 13 Excess non-contaminatedmaterials are trucked to an off-site area for disposal as constructiondebris. 2.I.4 ISFSI Operationsand Decommissionine For purposes only of this estimate, transfer of spent fuel to a repository or interim facility is assumedto be exclusively from the ISFSI once the fuel pools has been emptied and the fuel buildings have been released for decommissioning.The ISFSI will continue to operate under a general license (10 CFR Part 50) following the amendment of the operating licenseto releasethe adjacent (power block) property. Completion of the decommissioningprocess is dependent upon the ability to remove spent fuel from the site in a timely manner. This analysis assumesthat the last of the spent fuel will be removed from the site within approximately forty years of the shutdown of Unit 1. This assumption assumes that spent fuel is off site prior to commencing decommissioning operations in the SAFSTOR alternative. Spent fuel transfer operations from the ISFSI to the DOE are assumed to be completedby 2075. At the conclusion of the spent fuel transfer process,the ISFSI will be decommissioned.The Commissionwill terminate the Part 50license if it determines that the remediation of the ISFSI has been performed in accordancewith 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 licensefor the ISFSI. The design of the ISFSI is based upon the use of a DSC and a horizontal storage module (HSM) for pad storage.It is assumedthat once the inner canisters containing the spent fuel assemblieshave been removed, any required decontamination is performed on the HSMs (some minor neutron activation is assumed), and the license for the facility terminated, the modules can be dismantled using conventional techniques for the demolition of reinforced concrete. The concrete storagepad is then removed and the area regraded. TLG Seruices, fnc.

Beaver Valley Power Station Document F07-1696-001,Reu. 0 D ecommissioning Cost Analy sis Section 2, Page 10 of 13 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 subsequentlydecontaminated(deferred decontamination)to levels that permit release for unrestricted use.'t The facility is left intact (during the dormancy period), with structures maintained in a sound condition. 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 fi.xation and sealing of remaining contamination are performed. Access to contaminated areas is securedto provide controlled accessfor inspection and maintenance. The engineering and planning requirements are similar to those for the DECON alternative, although a shorter time period is expected for these activities due to the more limited work scope. Site preparations are also similar to those for the DECON alternative. However, with the exceptionof the required radiation surveys and site characterizations, the mobilization and preparation of site facilities is less extensive. 2.2.I Period 1 - Preparations Preparations for long-term storage include the planning for permanent defueling of the reactor, revision of technical specificationsappropriate to the operating conditions and requirements, a characterization of the facility and major components,and the developmentof the PSDAR. The process of placing the plant in safe-storageincludes, but is not limited to, the following activities: Isolation of the spent fuel storage services and fuel handling systems so that safe-storageoperations may commenceon 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 systemsto the greatest extent possible. Transferring the spent fuel from the storagepools to the ISFSI for interim storage, following the minimum required cooling period in the spent fuel pools. Draining and de-energizing of the non-contaminated systems not required to support continued site operations or maintenance. TLG Seruices. Inc.

Beauer VaIIey Power Station Document F07- I 696-001, Reu. 0 D ecomrnissioning Cost An aly sis Section 2, Page 11 of 13 Disposing of contaminated filter elements and resin beds not required for processingwastes from layup activities for future operations. Draining of the reactor vessel, with the internals left in place and the vesselhead secured. Draining and de-energizing non-essential systems, decontaminating them 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 systemswhose continued use is not required. r Cleaning of the loose surface contamination from building accesspathways.

             . Performing an interim radiation survey of plant, posting warning signs where appropriate.

o Erecting physical barriers and/or securing all access to radioactive or contaminated areas. except as required for inspection and maintenance. o Installing security and surveillance monitoring equipment and relocating security fence around secured structures, &s required. 2.2.2 Period 2 - Dormanc]' The second phase identified by the NRC in its rule addresseslicensed activities during a storage period and is applicable to the dormancy period 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 TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecomnrissioning Cost An aly sis Section 2, Page 12 of 13 emergency procedures are established and initiated for potential releases that exceedprescribed limits. The environmental surveillance program constitutes an abbreviated version of the program in effect during normal plant operations. Security during the dormancy period is conductedprimarily to prevent unauthorized entry and to protect the public from the consequencesof its own actions. The security fence, sensors, alarms, and other surveillance equipment are maintained throughout the dormancy period. Fire and radiation alarms are also functional. Consistent with the DECON scenario, the spent fuel storage pools are emptied within seven years of the cessationof operations, with the fuel transferred to the ISFSI. Spent fuel transfer from the ISFSI to an appropriate disposal facility is assumed to be complete by 2075. Once emptied, the ISFSI is secured for storage and decommissionedalong with the power block structures in Period 4. After a period of storage (such that license termination is accomplished within 60 years of final shutdown), it is required that the licensee submit an application to terminate the license, along with a LTP (describedin Section2.L.2),thereby initiating the third phase. 2.2.3 Periods3 and 4 - DelayedDecommissionine Corresponding to the DECON Periods 1 and 2, Delayed Decommissioningfollowing a SAFSTOR dormancy period is similar to the DECON counterparts, with the following considerations. Prior to the commencementof decommissioningoperations,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 and the assembly of activity specifications and detailed work 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 associatedwith this phase and the follow-on decontamination and dismantling processesare detailed in Sections2.1.1 and 2.I.2. The primary difference between the sequencesanticipated for the DECON and this deferred scenariois the absence,in the latter, of any constraint TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissio ning Cost An aly si s Section 2, Page 13 of 13 on the dismantling processdue to the operation of the spent fuel pools in the DECON option. Variations in the length of the dormancy period are expected to have some effect upon the quantities of radioactive wastes generated from system and structure removal operations. Given the levels of radioactivity and spectrum of radionuclides expectedfrom sixty years of plant operation, ro plant process system identified as being contaminated upon final shutdown are assumed to become releasable due to the decay period alone. However, due to the lower activity levels, a greater percentage of the waste volume can be designatedfor off-site processingand recovery. The delay in decommissioningalso yields lower working area radiation levels. As such, the estimate for this delayed scenario incorporates reduced ALARA controls for the SAFSTOR's lower occupational exposurepotential. Although the initial radiation levels due to 60Cowill substantially decreaseduring 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 presenceof long-lived radionuclides such as e4Nb,seNi, and asNi. Therefore, the dismantling proceduresdescribedfor the DECON alternative would still be employed during this scenario. Portions of the biological shield will still be radioactive due to the presenceof activated trace elements with long half-lives (1528uand 154Eu).Decontamination will require controlled removal and disposal. It is assumedthat 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 componentswill be surveyed as they are removed and disposed of in accordancewith 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 processis a cost-effectiveoption, as describedin Section2.I.3. The basis for the dismantling cost is consistent with that des*ibed 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 Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. A D ecommissio n ing Cost An aly sis Section 3, Page 1 of 31

3. COST ESTIMATES The cost estimates prepared for decommissioningBeaver Valley considerthe 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 describedin this section.

3.1 BASIS OF ESTIMATES The analysis relies upon site-specific,technical information from an earlier evaluation prepared in 2009, updated to reflect current assumptionspertaining to the disposition of nuclear power plants and relevant industry experiencein undertaking such projects. This information was reviewed for the current analysis and updated as deemed appropriate. The site-specificconsiderations and assumptions used in the previous evaluations were also revisited. Modifications were incorporated where new information was available or experience from ongoing decommissioning programs provided viable alternatives or improved processes. 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 Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates,"[2aJ and the DOE "Decommissioning Handbook.t'[25] These documents present a unit factor method for estimating decommissioning activity costs, which simplifies the estimating calculations. Unit factors for concreteremoval ($/cubicyard), steel removal ($/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 costsfor the conventional disposition of components and structures rely upon information available in the industry publication, "Building Construction Cost Data," publishedby R.S.V[sang.[26J The unit factor method provides a demonstrablebasis for establishing reliable cost estimates. The detail provided in the unit factors, including activity duration, labor costs (by craft), and equipment and consumablecosts, ensures that essential elements have not been omitted. Appendix A presents the TLG Services, Inc.

Beauer Valley Power Station Docurnent F0 7-1696-001, Reu. 0 D ecommissio n ing Cost An aly sis Section 3, Page 2 of 31 detailed developmentof a typical unit factor. Appendix B provides the values contained within one set of factors developedfor this analysis. This analysis reflects lessons learned from TLG's involvement in the Shippingport Station decommissioning, completed in 1989, as well as the decommissioningof the Cintichem reactor, hot cells, and associatedfacilities, completed in 1997. In addition, the planning and engineering for the Rancho Seco,Trojan, Yankee Rowe, Big Rock Point, Maine Yankee, Humboldt Bay-3, Connecticut Yankee, San Onofre, and Crystal River nuclear units have provided additional insight into the process,the regulatory aspects,and the technical challenges of decommissioning commercial nuclear Work Difficult]' Factors TLG has historically applied work difficulty adjustment factors (WDFs) to account for the inefficienciesin working in a power plant environment. WDFs are assigned to each unique set of unit factors, commensurate with the inefficiencies associatedwith working in confi.ned,hazardous environments. The ranges used for the WDFs are as follows: a AccessFactor l0% to 20% a Respiratory Protection Factor I0o/oto 50Yo a Radiation/ALARA Factor 1.0%to 37% o Protective Clothing Factor l0% to 30o/o a Work Break Factor 8.33% The factors and their associatedrange of values were developedin conjunction with the AIF/NESP-036 study. The application of the factors is discussedin more detail in that publication. Schedulins Program Durations The unit factors, adjusted by the WDFs as describedabove,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 developmentof 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 decontaminationof the spent fuel TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1690-001, Reu. 0 D ecommissioning Cost An aly si s Section 3, Page 3 of 31 pools are also dependent upon the timetable for the transfer of the spent fuel assembliesfrom the poolsto the ISFSI. An activity duration critical path is used to determine the total decommissioningprogram schedule. The scheduleis 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 ensuresa high degreeof confidencein the reliability of the resulting costs. 3.3 IMPACT OF DECOMMISSIONING MULTIPLE REACTOR UNITS In estimating the near simultaneous decommissioningof two co-locatedreactor units, there can be opportunities to achieveeconomiesof scaleby sharing costs between units and coordinating the sequenceof 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 estimates, Units 1 and 2 are assumedto be essentially identical. Common facilities (including the Control, Service, Office, Primary Access Facility, Waste Handling, and Intake structures) have been assignedto Unit 2. A summary of the principal impacts are listed below. The sequenceof work generally follows the principal that the work is done at Unit 1 first, followed by similar work at Unit 2. This permits the experiencegained at Unit 1 to be applied by the workforce at the second unit. It should be noted however, that the estimates do not considerproductivity improvements at the secondunit, since there is little documented experience with decommissioning two units simultaneously. The work associated with developing activity specificationsand procedures can be consideredessentially identical between the two units; therefore, the secondunit costsare assumedto be a fraction of the first unit (- 43o/o). Segmenting the reactor vessel and internals will require the use of special equipment. The cost of procuring that equipment is assumed to be shared on an equal basis between the two units. In addition, the decommissioningproject will be scheduledsuch that Unit 2's reactor internals and vessel are segmentedimmediately after the activities at Unit t have been completed. Duplication of some program management and support costs, particularly costs associatedwith the more senior positions, can be TLG Services, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissio ning Cost An aly si s Section 3, Page 4 of 31 avoided with multiple 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 schedule is also affected by a two-unit decommissioningschedule.Trying to complete the final status survey of Unit 1, while Unit 2 still has ongoing radiological remediation work and waste handling in processis consideredimpractical. During the spent fuel storage period, program management costs are reduced accordingly. The final demolition of buildings at Units 1 and 2 are consideredto take place concurrently. Unit 1, as the first unit to enter decommissioning,incurs the majority of site characterization costs.

    . Shared systemsand structures are generally assignedto Unit 2.

o Station costs such as ISFSI operations, emergency response fees, regulatory agency fees, and insurance are generally allocated on an equal basis between the two units. 3.4 FINANCIAL COMPONENTS OF THE COST MODEL TLG's proprietary decommissioningcost model, DECCER, producesa number of distinct cost elements. These direct expenditures, however, do not comprise the total cost to accomplishthe project goal, i.e., licensetermination, spent fuel managementand site restoration. 3.4.1 Contingency Inherent in any cost estimate that does not rely on historical data is the inability to specifuthe precise sourceof costs imposedby factors such as tool breakage, accidents,illnesses,weather delays, and labor stoppages. In the DECCER cost model, contingencyfulfills this role. Contingencyis added to each line item to account for costs that are difficult or impossible to develop analytically. Such costs are historically inevitable over the duration of a job of this magnitude; therefore, this cost analysis includesfunds to coverthesetypes of expenses. The activity- and period-dependentcosts are combined to develop the total decommissioningcost. A contingencyis then applied on a line-item TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001, Reu. 0 D ecom.m.issioning Cost An aly si s Section 3, Page 5 of 31 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"[27]as "specific provision for unforeseeableelements of cost within the defined project scope;particularly important where previous experience relating estimates and actual costs has shown that unforeseeableevents which will increase costs are likelv 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 unforeseeableevents that are likely to occur in decommissioningare discussedand guidelines are provided for a contingency percentage in each category. It should be noted that contingency, as used in this analysis, doesnot account for price escalation and inflation in the cost of decommissioningover the remaining operating life of the station. Contingencyfunds are an integral part of the total cost to complete the decommissioningprocess. Exclusion of this component puts at risk a successfulcompletion 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 contingenciesranged from 10% to 75o/o, depending on the degree of difficulty judged to be appropriate from TLG's actual decommissioningexperience.The contingencyvalues used in this study are as follows: a Decontamination 50o/o a Contaminated ComponentRemoval 25% a Contaminated ComponentPackaging L0% a Contaminated ComponentTransport L5o/o o Low-Level RadioactiveWaste Disposal 25o/o O Low-Level RadioactiveWaste Processing ffi% o Reactor Segmentation 75% a Nuclear Steam Supply System ComponentRemoval 25% o ReactorWaste Packaging 25% a ReactorWaste Transport 25% o ReactorVesselComponentDisposal 50% o Greater Than ClassC Disposal $% a Non-RadioactiveComponentRemoval $% o Heavy Equipment and Tooling I5o/o TLG Seruices, Inc.

Beaver Valley Power Station Docurnent F07-1696-001,Reu. 0 D ecomm.issioning Cost An aly sis Section 3, Page 6 of 31 a Supplies 25% a Engineering 15% o Energy 7.5o/o a Insurance, Property Taxes and Fees L0% a Staffing r5% o Characterization and Termination Surveys 30% o Construction $% a Spent Fuel Capital Costs (Canisters and Overpacks) L5% o Spent Fuel Transfer Costs r5% a Operations and Maintenance Expenses 15% o ISFSI Decommissioning 25% The contingencyvalues are applied to the appropriate componentsof the estimates on a line item basis. A compositevalue is then reported at the end of each detailed estimate (as provided in AppendicesC, D and D). 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 changesin work scope,pricing, job performance, and other variations that could conceivably,but not necessarily,occur. Consideration is sometimesnecessaryto generate a level of confidence in the estimate, within a range of probabilities. TLG considers these types of costs under the broad term "financial risk." Included within the categoryoffinancial 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 packagesthroughout the decommissioningprogram, national or company-mandated retraining, and retention incentives for key personnel. Delays in approval of the decommissioning plan d.ue to intervention, public participation in local community meetings, Iegal challenges,and national and local hearings. Changes in the project work scopefrom 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 TLG Services, Inc.

Beaver Valley Power Station Docutnent F07-1696-001,Reu. 0 D ecomm.issioning Cost Analysis Section 3, Page 7 of 31 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 releasecriteria, waste transportation, and disposal. Policy decisions altering national commitments (e.g., in the ability to accommodatecertain waste forms for disposition, or in the timetable for such, or the start and rate of acceptanceof spent fuel by the Federal government). Pricing changes for basic inputs such as labor, energ:y, 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 will be revisited periodically and addressedthrough repeated revisions or updatesof the baseestimates. 3.5 SITE.SPECIFIC CONSIDERATIONS There are a number of site-specificconsiderationsthat affect the method for dismantling and removal of equipment from the site and the degree of restoration required. The cost impact of the considerationsidentified below' i s included in this cost study. 3.5.1 Spent Fuel Management The cost to disposeof the spent fuel generatedfrom plant operations is not reflected within the estimates to decommission Beaver Valley. Ultimate disposition of the spent fuel is within the province of the Federal government's Waste Management System, as defined by the Nuclear Waste Policy Act. Until recently, the disposal cost was financed by a 1 mill/kWhr surcharge paid into the DOE's waste fund during operations. On November 19, 2013, the U.S. Court of Appeals for the D.C. Circuit ordered the Secretary of the Department of Energy to suspend collecting annual fees for nuclear waste disposal from nuclear power plant operators until the DOE has conducteda legally adequate fee assessment. The NRC does, however, require licensees to establish a program to manage and provide funding for the managementof all irradiated fuel at the reactor site until title of the fuel is transferred to the Federal TLG Services, Inc.

Beauer Valley Power Station Docutnent F07-1696-001,Reu. 0 D ecommi ssioning Cost An aly sis Section 3, Page I of 31 government. This requirement is included through certain high-level waste cost elementswithin the estimates,as describedbelow. Completion of the decommissioningprocess is highly dependent upon the ability to remove spent fuel from the site. This analysis assumesthat the last of the spent fuel will be removed from the site within approximately forty years of the shutdown of Unit 1. This assumesthat spent fuel is off site prior to commencingdecommissioningoperations in the SAFSTORalternative. ISFSI An ISFSI has been constructed on site to support continued plant operations. The ISFSI is expected to operate throughout decommissioning,and beyond the conclusionof the remediation phasein the DECON decommissioningscenario,until such time that the transfer of spent fuel to an appropriate disposalfacility can be completed. Spent fuel transfer from the ISFSI is assumed to be complete by 2075. The scenario is similar for the SAFSTOR alternative; however, based upon the expectedcompletion date for fuel transfer, the ISFSI will be emptied prior to the commencementof decommissioningoperations. Operation and maintenance costs for the spent fuel pools and the ISFSI are included within the estimates and address the cost for staffing the facility, as well as security, insurance, and licensing fees. The estimates include the coststo purchase,load, and transfer the DSCs from the pools or from the ISFSI. Costs are also provided for the final dispositionof the facilities oncethe transfer is complete. Storage Canister Desisn The design and capacity of the ISFSI is based upon the Transnuclear NUHOMS system (with a 37-fuel assembly capacity). The system consists of a multi-purpose (storage and transport) dry shielded storage canister (DSC) and a horizontal storage module (HSM). The DOE is assumedto provide the shipping containers for fuel transferred directly from the pools to the DOE at no cost to the owner. Canister Loadine and Transfer An average cost of approximately $783,000 is used for the labor to load/transport the spent fuel from the pools to the ISFSI pad, based upon FirstEnergy experience.For estimating purposes, 50% of this cost TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu, 0 D ecomrnissio ning Cost An aly si s Section 3, Page I of 31 is used to estimate the cost to transfer the fuel from the ISFSI to the D OE . Operationsand Maintenance The estimates also include the cost of operating and maintaining the spent fuel pools and the ISFSI, respectively. PooI operations are expectedto continue approximately seven years after the cessation of operations of each unit. It is assumedthat the seven years provides the necessarycooling period for the final core to meet applicable transport system requirements for decayheat and/or the dry cask storagevendor's system. ISFSI operating costs are based upon the previously stated assumptionson fuel transfer expectations. ISFSI Decommissioning Ten HSMS are assumedto have somelevel of neutron-inducedactivation as a result of the long-term storage of the fuel, i.e., to levels exceeding free-releaselimits. This allowanceis equivalent to the number of HSMs required to accommodatethe final core off load from both units. The cost of the disposition of this material is included in the estimate. Appendix E details the costs necessaryto survey, decontaminate, and terminate the NRC license on the ISFSI facility. The estimates in AppendicesC, D and E also include the costs for the demolition of the ISFSI facility following NRC licensetermination (as a Site Restoration expense). GTCC The dismantling of the reactor internals is expected to generate radioactive waste consideredunsuitable for shallow land disposal (i.e., low-level radioactive waste with concentrations of radionuclides that exceedthe limits establishedby the NRC for Class C radioactive waste, or greater than Class C (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 reasonablecosts of disposing of such waste. Although the DOE is responsiblefor disposingof GTCC waste, any costs for that service have not been determined. For purposesof this estimate, the GTCC radioactive waste has been assumed to be packaged in the same canisters used to store spent fuel and disposed of as high-level waste, at a cost equivalent to that envisionedfor the spent fuel. TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Rev, 0 D ecommissioning Cost Analy sis Section 3, Page 10 of 31 It is assumed that the DOE would not accept this waste prior to completing the transfer of spent fuel. Therefore, until such time the DOE is ready to acceptGTCCwaste,it is reasonableto assumethat this material would remain in storage at the Beaver Valley site (for the DECON alternative). In the SAFSTOR scenario,the GTCC material is shipped directly to an appropriate disposal facility as it is generated since the fuel has been removed from the site prior to the start of decommissioning. 3.5.2 ReactorVesseland Internal Components The reactorpressurevesseland internal componentsare segmentedand shipped for disposal in shielded, reusable transportation casks. Segmentationis performed in the refueling canal, where a turntable and remote cutter are installed. The vessel is segmentedin 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 segmentationand packaging methodology. Intact disposal of reactor vessel shells has been successfully demonstrated at several of the sites that have been decommissioned. Accessto navigable waterways has allowed these large packagesto be transported to the Barnwell disposal site with minimal overland travel. Intact disposal of the reactor vessel and internal components can provide savings in cost and worker exposureby eliminating the complex segmentation requirements, isolation af 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 packagewas 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. TLG Seruices, Inc.

Beaver Valley Power Station Docum.entF07-1696-001,Reu. 0 D ecommission in g Cost An aly sis S e c t i o n S , P a g e1 1 o f 3 1 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 compliancewith land disposalregulations. It is not known whether this option will be available when the Beaver Valley plant ceasesoperation. 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 assumesthat the reactor vesselwill require segmentationas a bounding condition. 3.5.3 Primary SystemComponents In the Unit 2 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 expectedto have a significant AI"ARA impact, since in this scenariothe removal work is done within the fi.rst 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 "processliquid waste" charge. In the Unit 1 DECON and SAFSTOR scenarios, radionuclide 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 processingthese large components. TLG Seruices. Inc.

Beauer VaIIey Power Station Document F0 7-1696-001, Reu. 0 D ecommissioning Cost Analy sis Section 3, Page 12 of 31 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 storagearea. The generatorsare disassembledon-site with the outer shell and lightly contaminated subassembliesdesignated for off-site recycling. The more highly contaminated tube sheet and tube bundle are packagedfor direct disposal. Disposal costs are based upon the displaced volume and weight of the units. Each componentis then loaded onto a rail car for transport to the disposal facility. Reactor coolant piping is cut from the reactor vesselonce 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 zorte. The piping is boxed and transported by shielded van. The reactor coolant pumps and motors are lifted out intact, packaged, and transported for processingand/or disposal. 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 condensersare also disassembledand moved to a laydown area. Components are packaged and readied for transport in accordancewith the intended disposition. 3.5.5 Retired Components The estimates include the disposition of three retired steam generators and a reactor closure head from Unit 1. They are assumed to be stored on site in a shielded structure; they will be transported and disposedof in a similar fashion to the steam generatorsas discussedin Section 3.5.3 above. 3.5.6 TransportationMethods Contaminated piping, components, and structural material other than the highly activated reactor vessel and internal componentswill qualifr TLG Seruices, Inc.

Beauer Valley Power Station Docutnent F07-1696-001,Reu, 0 D ecomm issioning Cost An aly si s Section 3, Page 13 of 31 as LSA-I, II or III or Surface Contaminated Object, SCO-I or II, as describedin Title 49.t281The contaminated material will be packagedin Industrial Packages(IP-l, IP-z, or IP-3, as defined in subpart I73.4LI) for transport unless demonstrated to qualify as their own shipping containers.The reactor vessel and internal componentsare expectedto be transported in accordancewith 10 CFR Part 71, in Type B containers. It is conceivablethat the reactor, due to its limited specific activity, could quali$' 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 acceptablefor transport. Any fuel cladding failure that occurredduring the lifetime of the plant is assumedto have releasedfission products at sufficiently low levels that the buildup of quantities of long-lived isotopes (e.g., 137Qs,e0Sr, or transuranics) has been prevented from reaching levels exceedingthose that permit the major reactor componentsto be shipped under current transportation regulations and disposalrequirements. Transport of the highly activated metal, producedin the segmentationof the reactor vessel and internal components,will be by shielded truck cask. Cask shipments may exceed 95,000 pounds, including vessel 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 schemefor the vessel and internal segmentsis designedto meet these limits. The transport of large intact components (e.g., large heat exchangers and other oversizedcomponents)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 B and 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. Transportation costs for off-site waste processing are based upon the mileage to Oak Ridge, Tennessee.Truck transport costs were developed from published tariffs from Tri-State Motor Transit.[2e] TLG Seruices, Inc.

Beauer Valley Power Station Document F0 7-1696-001, Reu. 0 D ecommi ssioning Cost An aly si s Sectinn 3, Page 14 of 31 3.5.7 Low-LevelRadioactiveWaste Disposal To the greatest extent practical, metallic material generated in the decontamination and dismantling processesis processedto reduce the total cost of controlled disposal.Material meeting the regulatory and/or site release criterion, is released as scrap, requiring no further cost consideration. Conditioning (preparing the material to meet the waste acceptancecriteria ofthe disposalsite) and recovery ofthe waste stream is performed off site at a licensed processing center. Any material Ieaving the site that was removed from a contaminated or potentially contaminated area is subject to a survey and release charge, at a minimum. The mass of radioactive waste generated during the various decommissioningactivities at the site is shown on a line-item basis in the detailed Appendices C and D, 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 componentscan 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 componentsserving 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 burial 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 radionuclideslimit the capacity of the shipping canisters. Disposal fees are based upon estimated charges,with surchargesadded for the highly activated components, such as those generated in the segmentationof the reactor vessel.The cost to disposeof the lowest level and majority of the material generated from the decontamination and dismantling activities is based upon the current cost for disposal at EnergySolutions facility in Clive, Utah. Disposal costs for the higher activity waste (Class B and C) were based upon preliminary information from WCS for the Andrews Countv facilitv. TLG Seruices.Inc.

Beauer VaIIey Power Station Document F07-1696-001,Reu. 0 D ecommissioning Cost Analysis Section 3, Page 15 of 31 3.5.8 Site ConditionsFollowineDecommissionine The NRC will amend or terminate the site license if it determines that site remediation has been performed in accordancewith 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 decommissioningprocess,as well as owner's own future plans for the site. Only existing site structures are consideredin the dismantling cost. The electrical switchyard remains after Beaver Valley is decommissionedin support of the regional transmission and distribution system. Structures are removed to a nominal depth of three feet below grade. The voids are backfilled with clean debris and cappedwith 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 site restoration. Costs are included for the demolition of shoreline structures including the intake structure, the alternate, cooling towers and the cooling tower pump house. Costs are not included for general restoration of the riverbank. Concrete rubble generated from demolition activities is processedand made available as clean fill for the power block foundations. Additional clean fill is brought on site to backfill below grade voids as needed.The excavationswill be regraded such that the power block area will have a fi.nalcontour consistentwith adjacent surroundings. The estimates assume the remediation of contaminated soil in the vicinity of known historical onsite radioactive spills. 3.6 ASSUMPTIONS The following are the major assumptions made in the development of the estimates for decommissioningthe site. TLG Seruices. Inc.

Beauer Valley Power Station Document F07- I 696-001, Reu. 0 D ecommissioning Cost Analy sis Section 3, Page 16 of 31 3.6.1 Estimating Basis Decommissioningcostsare reported in the year of projectedexpenditure; however, the values are provided in 2OI4 dollars. Costs are not inflated, escalated,or discountedover the periods of performance. The plant inventory, the basis for the decontaminationand dismantling requirements and cost, and the decommissioningwaste streams, was taken from the 2009 analysis. The ISFSI recently constructed on site was also added to the structures inventory. 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 consideredin the costsfor engineering and planning, and in the developmentof activity specificationsand detailed procedures. Changes to worker exposure limits may impact the decommissioningcost 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 FirstEnergy. FirstEnergy will hire a DecommissioningOperations Contractor (DOC) to manage the decommissioning.The owner will provide site security, radiological health and safety, quality assurance and overall site administration during the decommissioning and demolition phases. Contract personnel will provide engineering services for preparing the activity specifications, work procedures, activation, and structural analysesunder the direction of FirstEnergy. Personnel costs are based upon average salary information provided by FirstEnergy. A utility labor payroll overhead rate of 36.60/ohas been included. TLG Seruices,Inc.

Beauer VaIIey Power Station Docurnent F07- 1696-001, Rev. 0 D ecommissio n ing Cost An aly sis Section 3, Page 17 of 31 Security, while reducedfrom operating levels, is maintained throughout the decommissioning for access control, material control, and to safeguardthe spent fuel. 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 secondarystaff level. The unit assignedthe primary staff will include common supervisory positions and positions that may be shared acrossboth units. The types of positions and staffing levels are adjusted basedupon the type of activity occurring in each sub-period. A profi.le of the staffing level for the two-unit decommissioning, including contractors and craft, is provided in Figures 3.1 and 3.2 for the DECON and SAFSTOR scenarios.Since the shutdowns of the two units are far apart, in the Integrated DECON scenario there will be a small peak around the time of Unit 1 shutdown, with a larger peak after Unit 2 shutdown, where the combined site then proceedsto decommissioning. Utility staffing levels will gradually decrease after completing the removal of physical systems at each of the units. Staffing levels and management support will vary based upon the amount and type of decommissioning work. Craft manpower levels decrease after systems removal and structures decontamination and drop substantially during the delay period and the license termination survey period. However, craft staff levels increase again during the site restoration period due to the work associated with structures demolition. 3.6.3 Desien Conditions Any fuel cladding failure that occurred during the lifetime of the plant is assumedto have releasedfission products at sufficiently low levels that the buildup of quantities of long-lived isotopes (e.g., 137Cs,eoSr, or transuranics) has been prevented from reaching levels exceedingthose that permit the major NSSS componentsto be shipped under current transportation regulations and disposalrequirements. The curie contents of the vessel and internals at final shutdown are derived from those listed in NUREG/CR-3474.I301 Actual estimates are derived from the curie/gram values contained therein and adjusted for the different mass of the Beaver Valley components,projected operating life, and different periods of decay.Additional short-lived isotopeswere TLG Seruices. Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissio ning Cost An aly si s Section 3, Page 18 of 31 derived from NUREG/CR_0130r311 and NUREG/CR_0672,trrland benchmarkedto the long-lived values from NUREG/CR-} 74. It is anticipated that there will be control element assemblies(CEAs)in the spent fuel pools at the cessationof operations,including those CEAs from the final core. This analysis assumes that the CEAs can be disposedof along with the spent fuel at no additional cost (in accordance with Appendix E of the Standard Contract). Neutron activation of the containment building structure is assumedto be confined to the biological shield adjacent to the reactor vessel and neutron shield tank. 3.6.4 General Transition Activities Existing warehousesare cleared of non-essential material and remain for use by FirstEnergy 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: o Drain and collect fuel oils, lubricating oils, and transformer oils for recycleand/or sale. r Drain and collect acids, caustics, and other chemical stores for recycleand/or sale.

           .      Process operating waste inventories. Disposal of operating wastes (e.9.,filtration media, resins) during this initial period is not considereda decommissioningexpense.

Scrap and Salvaee The existing plant equipment is considered obsolete and suitable for scrap as deadweight quantities only. FirstEnergy will make economically reasonable efforts to salvage equipment following final plant shutdown. However, dismantling techniques assumedby TLG for equipment in this analysis are not consistent with removal techniques required for salvage(resale)of equipment. Experiencehas 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 salvagevalue on this machinery and TLG Seruices, Inc.

Beauer VaIIey Power Station Docurnent F07-1696-001,Reu. 0 D ecommissioning Cost An aly sis Section 3, Page 19 of 31 equipment would be speculative, and the value would be small in comparisonto the overall decommissioningexpenses,this analysis does not attempt to quantify the value that an owner may realize based upon those efforts. It is assumed,for purposesof this analysis, that any value receivedfrom the sale of scrap generated in the dismantling processwould be more than offset by the on-site processingcosts. The dismantling techniques assumedin the decommissioningestimates 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 contaminatedinsulation, an added expense.With a volatile market, the potential profit margin in scrap recovery is highly speculative, regardless of the ability to free releasethis 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 decommissioningproject. Disposition may include relocation to other facilities. Spare parts are also made available for alternative use. Asbestos No allowance for remediation of asbestosin the plant has been included in this estimate. Energ.v For estimating purposes,the plant is assumedto 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 consumedduring decommissioningfor tooling, lighting, ventilation, and essential services. Insurance Costs for continuing coverage(nuclear liability and property insurance) following cessationof plant operations and during decommissioningare included and based upon current operating premiums. Reductions in premiums, throughout the decommissioningprocess,are based upon the guidanceprovided in SECY-00-0145,"Integrated Rulemaking Plan for TLG Services, Inc.

Beauer Valley Power Station Document F07- 1696-001, Reu. 0 D ecommi ssion ing Cost An aly sis Section 3, Page 20 of 31 Nuclear Power Plant Decommissioning."[33]The NRC's financial protection requirements are based on various reactor (and spent fuel) configurations. FirstEners.v CorporateOverhead A corporate support overhead cost has been included at a level commensuratewith the existing Beaver Valley corporate support costs for the first year after final shutdown, decreasingto I% of this level within six years (DECON scenario only). The SAFSTOR scenariosare more complicated, decreasing during dormancy, but increasing again during delayeddecommissioning. Site Non-Labor Overhead These estimates include costs for site non-labor overheadcharges.These costs include telephones,copy machines, computers, IT infrastructure, office supplies, janitorial supplies, training expenses,etc. FirstEnergy provided a site non-labor overhead allowance at $18,300per person per year to addressthesecosts. Taxes Property taxes are included for all decommissioning periods. FirstEnergy provided their current property tax payments for 20L4; these were assumed to continue for the first year following final shutdown. Beginning in the second year of decommissioning,the site incurs a minimum property tax payment of $1 million per year; this level is maintained for the balance of the decommissioningprogram. NRC Fees These estimates include charges from the NRC to support the Beaver Valley decommissioningprogram. Charges are included for the yearly licenses held by FirstEnergy for the Part 50 licenses, as well as engineering support charges by the NRC to review activities at the site. The Part 50 license fee for a reactor in a decommissioningor possession-only status and which has spent fuel onsite is $224 thousand per year. The hourly rate for NRC review is $279.00.The level of effort of NRC participation is commensurate with the decommissioning alternative and schedule; for example the Integrated DECON scenario has an estimated NRC support requirement of approximately 22,200 hours from Unit 1 shutdown until termination of the ISFSI license. TLG Seruices, Inc.

Beauer VaIIey Power Station Document F07-1696-001,Reu, 0 D ecomrnission ing Cost An aly sis Section 3, Page 21 of 31 EmergencyPlanning Fees These estimatesinclude costs for emergencyplanning support activities. There are three separate civil emergency planning organizations assumed to be supporting FirstEnergy during the decommissioning program. The Federal Emergency Management Agency (FEMA) yearly fees are estimated at $615,900 for the site from shutdown until approximately 12 months after each unit's shutdown, after which the FEMA fees are assumed to be eliminated. The fee is divided equally betweeneachunit. The combined Pennsylvania, Ohio, and West Virginia emergency management yearly fees are estimated at $2,060,000for the site from shutdown until approximately 12 months after each unit's shutdown, after which these state emergency agency fees are also assumedto be eliminated. The fee is divided equally betweeneach unit. The combined Beaver, Hancock, and Columbiana counties emergency agency fees, plus the Joint Information Center support costs, are estimated at $581,000for the site per year. These fees continue until the spent fuel has been removed from the site, assumed to be in the year 2075. Site Modifi.cations 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 stagesofthe project. 3.7 COST ESTIMATE

SUMMARY

A schedule of expenditures for each scenario and each unit is provided in Tables 3.1 through 3.4. Decommissioning costs are reported in the year of projected expenditure; however, the values are provided in thousands of 2014 dollars. Costs are not inflated, escalated, or discounted over the period of expenditure. The annual expenditures are based upon the detailed activity costs reported in Appendices C and D, along with the schedulesdiscussedin Section4. TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001, Reu. 0 D ecornrni ssion ing Cost An aly sis Section 3, Page 22 of 31 TABLE 3.1 INTEGRATED DECON ALTERNATIVE - UNIT 1 TOTAL ANNUAL DPENDITURES (thousands, 2074dollars) Equipment & Year Labor Materials Energy Burial Other 2036 _ 39,0_0_4 * * *q:8_8_6_ 11982_ 620 L2.75r 55.242 2037 _?7.W _ *_"-1_2,115_1.422 4.817 20.474 66.01 4 2038 7.435 6 .9 7 3 428 13 5.165 20.0L4 2039 7.435 6 ,9 7 3 428 13 5,165 20.0r4 2040 7.455 6.992 429 13 5,179 20.069 204r 7.435 6 .9 7 3 428 13 5.165 20.or4 2042 7.435 6 ,9 7 3 428 13 5.165 20.0r4 2043 2.956 812 230 7 3,118 7,L23 2044 2.591 300 2L5 6 2.956 6,068 2045 2.584 300 214 6 2.948 6.052 2046 32.8I2 2.329 1,939 30 3.382 40.492 2047 49.322 16,083 2,098 L3,796 7,1r4 88,4r4 2048 54.095 22.882 2.038 35.501 L2,357 t26.873 2049 33,386 9.428 1,648 15.592 8,880 68.934 2050 3 1 ,0 6 7 7"918 1.605 13.357 8,49t 62,438 2057 10.343 2,936 789 4,703 4.470 22.64L 2052 1,173 732 429 6 2.697 5.038 2053 1.169 730 428 6 2,690 5.024 2054 1.309 740 428 6 2.692 5,L7 5 2055 23.236 4 .6 1 0 375 2T 2,982 3L,223 2056 13.033 11 . 1 5 1 215 0 2.700 27.099 2057 9,792 8.661 r47 0 2.332 20.932 2058 1"990 1.013 0 0 1.537 4,540 2059 1 .9 9 0 1,013 0 0 1.537 4.540 2060 t.994 1.013 0 0 I.541 4,549 2067 1 .9 9 0 1,013 0 0 1.537 4.540 2062 i 1.877 676 0 0 1,537 4.090 2063 i 1.877 676 0 0 1.537 4.090 2064 1,882 676 0 0 1.54r 4.098 2065 i I.877 676 0 0 1.537 4,090 TLG Seruices.Inc.

Beauer Valley Power Station Document F07-1696-001,Reu, 0 D ecommission ing Cost An aly sis Section 3, Page 23 of 3I TABLE 3.1 (continued) INTEGRATED DECON ALTERNATIVE _ UNIT 1 TOTAL ANNUAL DPENDITURES (thousands,2014dollars) Equipment & Year Labor Materials Energy Burial 2066 r.877 ___q]q 0 0 1.537 4.090 2067 r.764 338 0 0 1.537 3.639 2068 1 .7 6 9 338 0 0 1,54I 3,648 2069 I,652 0 0 0 1.537 3,18 9 2070 r.652 0 0 0 1.537 3.189 2077 r.652 0 0 0 1.537 3,18 9 2072 1 ,6 5 6 0 0 0 1.541 3.797 2073 r.652 0 0 0 1,537 3.189 2474 r.652 0 0 0 1.537 3,189 2075 I.652 0 0 0 1.537 3.18 9 2076 603 1 ,8 9 1 36 1,316 11,294 15.14 0 Telal_t--02*gg-[__ 1_5Q:515 18,380 89,255 167.849 828.287 TLG Seruices, Inc.

Beaver VaIIey Pouter Station Docurnent F07-1696-001,Rev. 0 D ecommissioning Cost Analy sis Section 3, Page 24 of 31 TABLE 3.2 INTEGRATED DECON ALTERNATIVE - UNIT 2 TOTAL ANNUAL DGENDITURES (thousands. 2014dollars) Equipment & Year Labor Materials Energy Burial Other i 2_e_53+

  ?_0_4?__                   _+,_2!:7 !,7:8_4 ^ _2*?-*1-2*[qP " lJ,6_11 2048 i Se.rSS             1 3 .6 8 6     3.220     6.263        13,972         93.296 2049 i 65.773             23.446        2,033     26,003        II,492       128.747 2050      58.472          1 6 .0 1 9     1.809    18.033          9.759       r04.092 2057      57.820            9.253        1.605    r0.773          8,181        81.63 2 2052      50,012           8 ,9 3 6      1,609    r0,243          8.013        78,81 3 2053 _ t4,3:54              2.667        1.605         26         4.534        23,186 2054      25.528            4.686        1,153      4.872         5.372        41.611 2055      27.022           4,447           375         2L         2.927        34,792 2056      18.599          1 3 .2 5 8       2L5            0       2.70L        34.774 2057      1 3 ,3 5 2       9,093           I47            0       2.327        24.9L9 2058 i      1 .9 1 1             0           0            0       1.519         3.430 2059        1.911                0           0            0       1.519         3.430 2060        1 ,9 1 6             0           0            0       r.524         3,439 2061        1.911                0           0            0       1,519         3.430 2062       2,023              338            0            0       1,519         3,880 2063       2,023              338            0            0       1.519         3,880 2064       2.028              338            0            0       L.524         3,890 2065       2,023              338            0            0       1.519         3,880 2066       2.023              338            0            0       1,519         3.880 2067       2.136              676            0            0       1.519         4,331 2068       2.254            1.013            0            0       r.524         4.79r 2069       2.248            1.013            0            0       1,519         4.781 2070       2,248            1.013            0            0       1.519         4,78I 2071       2.248            1.013            0            0       1,519         4.781 2072 i     2.254            1.013            0            0       r.524         4.79r 2073       2.248            1.013            0            0       1.519         4.78r 2074 i     2.248            1.013            0            0       1.519         4.781 2075 i     2.136              676            0            0       1.519         4.331 2076 i        613 _         1,,-8,9,1       36       1.316      1r.294         1 5 15 0 i_m                       *_J27,73_!i*   _ F,qeli nn  -n, I l,ol+l i

uq4q6_i

rca_elql TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissioning Cost An aly si s Section 3, Page 25 of 31 TABLE 3.3 SAFSTORALTERNATIVE - UNIT 1 TOTAL ANNUAL DGENDITURES (thousands, 2014dollars) Equipment & Year Labor Materials Enerry Burial Other 2036 35,802 3,886 1.982 620 12.801 55,090 2037 28,492 9.704 1.422 1.973 20.082 61.66 3 2038 10.600 6 .9 9 5 428 15 4,84L 22.878 2039 10,600 6 ,9 9 5 428 15 4.84L 22,878 2040 10.629 7 .0 1 4 429 15 4.854 22,94r 204L 10.600 6,995 428 15 4.84L 22,878 2042 10,600 6,995 428 15 4.84L 22,878 2043 3.552 815 230 7 2.280 6,884 2044 2 .9 7 5 302 2t5 6 2,073 5,57r 2045 2.967 301 2t4 6 2.067 5,555 2046 2.967 301 214 6 2,067 5.55 5 2047 4 .0 7 7 3,613 214 6 2.067 9,971 2048 2 .9 7 5 302 215 6 2.073 5.571 2049 3,079 639 2t4 6 2,067 6,006 2050 3.079 639 214 6 2.067 6.006 2051 3.079 639 214 6 2,067 6,006 2052 3,200 978 2t5 6 2.073 6,472 2053 3.L92 977 214 6 2,067 6.456 2054 3,L92 977 214 6 2,067 6.456 2055 3,305 1.315 274 6 2.067 6.907 2056 3.313 1,316 215 6 2.073 6.922 2057 3.305 1.315 214 6 2.067 6.907 2058 3.305 1,315 2L4 6 2.067 6,907 2059 3,305 1.315 214 6 2.067 6.907 2060 3.313 1.316 215 6 2,073 6,922 206r 3,305 .l,p!5_ 214 6 2,067 6,907 2062 3 192 977 214 6 2,067 6,456 2063 3,r92 977 214 6 2,067 6,456 2064 3,200 978 215 6 2,073 6,472 2065 3.r92 977 214 6 2,067 6.456 TLG Seruices, Inc.

Beauer Valley Power Station Docurnent F07-1690-001,Reu. 0 D ecommissioning Cost Analy sis Section 3, Page 26 of 31 TABLE 3.3 (continued) SAFSTORALTERNATIVE _ UNIT 1 TOTAL ANNUAL EXPENDITURES (thousands. 2014dollars) Equipment & Year Labor Materials Energy Burial 2466 3,r92 977 214 6 2,067 6,456 2067 3,079 639 214 6 2.067 6.006 2068 3,088 640 2L5 6 2.073 6,021 2069 2,967 301 214 6 2,067 5,55 5 2070 2.967 301 214 6 2.067 5.55 5 2071 2,967 301 274 6 2,067 o,ooo 2072 2 ,9 7 5 302 2L5 6 2,O73 5,577 2073 2.967 301 214 6 2.067 5.55 5 2074 2.967 301 214 6 2.067 D.OOD 2075 2,967 301 2L4 6 2.067 5.55 5 2076 1,348 300 2L5 6 1,618 3,488 2077 1.344 300 214 6 1.614 3.47 8 2078 r.344 300 214 6 1,614 3.47 8 2079 r,344 300 214 6 1.614 3.47 8 2080 1.348 300 215 6 1,618 3.488 2081 r.344 300 2t4 6 L,6L4 3.47 8 2082 L,344 300 214 6 r,6t4 3,478 2083 t.344 300 214 6 1,614 3.47 8 2084 1 ,3 4 8 300 215 6 1.618 3"488 2085 r.344 300 274 6 1.614 3.478 2086 L.344 300 214 6 1.614 3.478 2087 r,344 300 214 6 1.614 3,47 8 2088 4,691 485 399 I 1,759 7,343 2089 37.277 3.002 2.t40 33 3,093 45,545 2090 52.020 18,320 2.077 23,509 t2,862 108,788 209r 46.443 1 7 ,8 6 5 1.876 30.398 L5,572 trz.I54 2092 31.283 7 .5 4 9 1,609 14.083 8.666 63.191 2093 ; 23.t64 5.560 t.292 10,314: 6,768 47,097 2094 i 966 119 428 6 1.589 3,108 2095 ;_ 1_Q,5,26 1,o32 428 22 1,858 21,,865 TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissio n in g Cost An aly sis Section 3, Page 27 of 31 TABLE 3.3 (continued) SAFSTORALTERNATIVE - UNIT 1 TOTAL ANNUAL EXPENDITURES (thousands, 2014dollars) Equipment & Year Labor Materials Enerry Burial Other 13,730 tt8l-2097 12,847 TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissioning Cost An aly si s Section 3, Page 28 of 31 TABLE 3.4 SAFSTORALTERNATIVE _ UNIT 2 TOTAL ANNUAL EXPENDITURES (thousands, 2014dollars) Equipment & Year Labor Materials Enerry Burial Other 2047 i 25,066 4.047 -- 1.,284i --^t,iet 402 7-,40_5 38,203 I,iazj l-2048 i 41.68G LO,II2 19.067 75.042 2049 1 3 ,5 3 4 2 ,5 4 4 428i 15 4,245 20.765 2 0 5 0 i 1 3 ,5 3 4 2.544 428 15 4.245 20"765 205t I 13.534 2.544 428 15 4,245 20.765 2052 1 3 .5 6 9 2,545 429 15 4.257 20,81 5 2053 1 3 .5 3 4 2 .5 4 4 428 15 4.245 20.765 2054 8,266 L.751 300 10 2.973 13,299 2055 4,453 322 214 7 2.124 7.12r 2056 4,466 323 2t5 7 2 130 7.I40 2057 4,453 322 214 7 2.r24 7.L21 2058 4,453 322 214 7 2,r24 7.r21 2059 4,453 322 214 7 2.L24 7.tzL 2060 4,466 323 215 7 2.130 7.t40 2 A6 L 4,453 322 214 7 2.124 7.727 2062 4,566 660 2L4 7 2.r24 7.571 2063 4,566 660 274 7 2,r24 7,577 2064 4 ,5 7 9 661 215 7 2,130 7.59L 2065 4.566 660 2t4 7 2.I24 7.577 2066 4,566 660 214 7 2,r24 7,57r 2067 4.679 998 214 7 2.r24 8,022 2068 4,803 1,336 2L5 7 2,r30 8.491 2069 4,791 1,336 214 7 2,r24 8.472 2070 4 ,7 9 1 1,336 214 7 2,r24 8.472 207r i 4.797 1.336 214 n, 2.124 8.472 2072 i 4.803 1.336 215 7 2.130 8,491 2 0 7 3. . 4,797 1,336 2t4 7 2,L24 8.472

  ?:-0J4                   4,791 _ -       _143-6 _       ?14            7-     2,!2"!         8,!A2_

2075 4 ,6 7 9 998 2t4 7 2.124 8.O22 2076 i 2.088 315 215 6 1.594 4.2L8 TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissio n ing Cost An aly sis Section 3, Page 29 of 31 TABLE 3.4 (continued) SAFSTORALTERNATIVE - UNIT 2 TOTAL ANNUAL EXPENDITURES (thousands, 2014dollars) Equipment & Year Labor Materials Energy Burial Other 2077 2,083 314 2M 6 1,589 4.207 2078 2,083 314 214 6 1.589 4.207 2079 2 ,0 8 3 314 214 6 1,589 4.207 2080 2,099 315 2t5 6 1.594 4.2r8 2081 2,093 314 214 6 1.589 4.207 2082 2,083 3t4 274 6 1,589 4.207 2083 i 2.083 314 214 6 1.589 4.207 2084 : 2.088 315 2t5 6 r.594 4.2I8 2085 i 2.083 314 214 6 1,589 4.207 2086 2,083 314 214 6 1.589 4.207 2087 2.083 314 214 6 1,589 4,207 2088 2,088 315 2L5 6 r.594 4.2t8 2089 9.150 931 847 T4 2,034 12,976 2090 25.75L 4 ,1 0 9 2,140 32 3.015 35.046 2091 52.944 2I,525 2.052 25.402 14,975 116.898 2092 46.339 12.350 1.744 16,995 10.356 87.784 2093 40,869 6 ,7 5 7 1,605 10,557 7.026 66.815 2094 40.869 6 .7 5 7 1,605 10,557 7.026 66.815 2095 3 1 ,9 4 9 3,134 789 3.259 3,371 42.502 2096 L 7 .2 3 7 12,597 228 2 1.869 31.922 2097 16.465 t3,292 214 0; 1,871 3r,842 TLG Seruices. Inc.

Beauer Valley Pouter Station Document F07-1696-001,Reu. 0 D ecommi ssion ing Cast Analy si s Section 3, Page 30 of 31 FIGURE 3.1 BEAVER VALLEY MANPOWER LEVELS INTEGRATED DE CON ALTERNATIVE c8.0 7n0_fi 608.S 5fl8.S g H 4$0n 388.8 2$*"0 188"il g-s s n$/

                .$.9 "d
                                  ^!P .E   .E    ."r*" .s    d                 ab
                                                                              'F Yeer TLG Services, Inc.

Beauer Valley Power Station Docurnent F07-1696-001,Reu. 0 D ecommissioning Cost Analy si s Section 3, Page 31 of 31 FIGURE 3.2 BEAVER VALLEY MANPOWER LEVELS SAFSTORALTERNATIVE

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Beaver Valley Power Station Document F07- I 696-001, Reu. 0 D ecommissioning Cost Analy sis Section 4, Page I of 7

4. SCHEDULE ESTIMATE The schedulesfor the decommissioningscenariosconsideredin this analysis follow the sequences presentedin the AIF/NESP-036study, with minor changesto reflect recent experienceand site-specificconstraints. In addition, the schedulinghas been revised to reflectthe spent fuel managementdescribedin Section3.5.1.

A schedule or sequenceof activities for the DECON alternative is presented in Figure 4.1. The scheduling sequenceis based on the fuel being removed from the spent fuel pools within sevenyears of each unit's shutdown. The key activities listed in the schedule do not reflect a one-to-onecorrespondencewith those activities in the cost tables, but reflect dividing some activities for clarity and combining others for convenience.The schedulewas prepared using the "MicrosoftProject Professional 2013"computersoftware.[34] 4.T SCHEDULE ESTIMATE ASSUMPTIONS The schedule reflects the results of a precedencenetwork developedfor 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 developmentof the decommissioningschedule: The fuel buildings are isolated until such time that all spent fuel has been discharged from the spent fuel pools to an appropriate disposal facility or to the ISFSI. Decontamination and dismantling of the storage pools is initiated once the transfer of spent fuel is complete (DECON option). o AII work (exceptvessel and internals removal) is performed during an 8-hour workday, 5 days per week, with no overtime. o Reactor and internals removal activities are performed by using separate crews for different activities working on different with a correspondingbackshift charge for the secondshift. o Multiple crews work parallel activities to the maximum extent possible, consistent with optimum efficiency, adequate accessfor cutting, removal and laydown space, and with the stringent safety measures necessary during demolition of heavy componentsand structures. TLG Seruices. Inc.

Bee.uerValley Power Station Document F07-1696-001,Rev. 0 D ecomrnissio n ing Cost An aly si s Section 4, Page 2 of 7 o For plant systems removal, the systems with the longest removal durations in areas on the critical path are consideredto determine the duration of the activity. 4.2 PROJECT SCHEDULE The period-dependentcostspresentedin the detailed cost tables are basedupon the durations developedin the schedules for decommissioning.Durations are establishedbetweenseveralmilestonesin eachprojectperiod;these durationsare 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-dependentcosts.A secondcritical path is shown for the spent fuel storageperiod, which determines the releaseof the fuel buildings for final decontamination. Projecttimelines are providedin Figures 4.2 and 4.3, with milestonedatesbased on the anticipated shutdown dates. The fuel pools are emptied approximately seven years after shutdown, while ISFSI operations continue until all spent fuel has been transferred to an appropriate disposal facility. Deferred decommissioningin the SAFSTOR scenarios are assumed to commenceso that the operating licensesare terminated within a 60-year period from the cessation of Unit l plant operations. TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001, Reu. 0 D ecomtnis sioning Cost An aly sis Section 4, Page 3 of 7 FIGURE 4.1 ACTIVITY SCHEDULE _INTEGRATED DE CON lask lianre s + l a e I a e I a f I e e l . { a I + s l + eI o s I ; : I x I o s l

g BVUr:it1&Sschedutre' Sl'rutd**'nLlnii 1 Period1aUnit1 - Shutdo',ff through transitior F' Cerl'filaieof peimailentcessaiionof operdionssubrnitted Ffiel storagepoolooerations M bry aretiiorage operations W Recsnfimr*d*nl w FSDiARsubnrittad l,ltritteficertificateof pernanentien',oval Ut:et suUrlrtted

             *q:"jl. deconrryllirnrngcost sijmatesubmrtted
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                                           - --                                                                     ,a DeconHSSS                                                                                                     N PenodG tnrf 1 - Largecomponenirernod                                                                              t F' PruFarsti:Bfi  tor RPV reBlosl n"ictor *Jirt i int+mats MoceVesselSegnreniation          Equipment                                                                      ir RemainlngfargilSSS conrpo;ients          disposrtion                                                           in Systemsrernovalnoi iupportingurrsel removal N

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      &y fud siorageaperations                                                                                        ffi l{sn-ese$lra+s}rstem$
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                                                                                                                      ,w Maincondenser                                                                                                   w
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      !-ic*fl 9e ter*linaii&n ;:l*n :pprr*ed                                                                          r+
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Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommi ssioning Cost An aly sis Section 4, Page 4 of 7 FIGURE 4.1 (continued) ACTIVITY SCHEDULE _INTEGRATED DECON lesk l{a:Be a"rla6 l ru I +o I r: l+* l +o l +e l ;': l ;: I er l ;s I st Unil 3 *Feralior*

   $hutdown      Unit2                                                                                  I Penod1aUnit2 - Shutdown         throuqhtransition                                                   I I

r: 1e *er9_ry;[$ryG;-' - &

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   -    Dtcon  f,iSSS                                                                                      N iiAate ipem ruel"eool                                                                              %

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   ..--,fs,xrrgjlg:If        9l:9ryr-*ti"{.-t_.di9ry-:1t"t                                                       B

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 . . fuel ltor-age-pool    operations                                                                            ww

_ qvs9119':q. nP-:3its,_, "* ffi ffi RuI-:;ly--*1t*_rFt:upFo'illg-yei*glstygr w@ Deconbuildingsfiot sirFportmg Licenseterminationpan wtfuel storage lpproved

                                                                                                                 %N  w i+

Fuel storagepoolavailaHe for decammissioning i+ Feriol 2i Un* r Spenttueldelaypnorio Sfp aecon ir t Spentfue{peol del*y i @ B' Feriod 2d Unit I - 8e*o*tarninationfdla*iing ws{ ful sto.age ;

     'gly.,g?lii9ll];@1.d-.':'-".--                                                                                        KI Remor*eremaining*ysleme necon'ilfu1ito'"g',"--'.
                                                                                                                         ,r e, w Fenod2e_Un_!.t_    2; Be-:layteforgLieengeTerrn                                                                           +

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      -bt                                                                                                                      I -t tu;i ;i;;ase operations                                                                                              w bL,itdingdemolitions. bacffill6ndl#ds;aping                                                                             ffit TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissioning Cost An aly si s Section 4, Page 5 of 7 FIGURE 4.1 (continued) ACTIVITY SCHEDULE -INTEGRATED DECON LEGEND

1. Red schedulingbars indicate critical path activities

2. Blue schedulingbars associatedwith major decommissioningperiods,.g.,Period 1a, indicate overall duration ofthat period

3. Diamond symbolsindicate major milestones

4. In the chart header, the "Y1", "Y4", et. ol. refers to the years of the decommissioning project.Therefore,"Y1" is the year of shutdown for Unit 1, or 2035.

TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissio n ing Cost An aly sis Section 4, Page 6 of 7 FIGURE 4.2 DE COMMISSIONINGTIMELINE INTEGRATED DECON (not to scale) U n i t1 Shrrtdown Period1 Period2 Period3 Period4 Perno 5 SAFSTOR Dormancy Preparatio16 Decommissioning Site Pleparatio16 Restoration Aug2037 Oct2055 Sep2057 Unit 1 FuelPool lan2043 Operations DrytudStorage Unit 2 FuelPool Operations Unit2 Shutdown Period3 Period2 Site Decommbsioning Restoration TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecomm.issioning Cost Analy sis Section 4, Page 7 of 7 FIGURE 4.3 DE COMMISSIONINGTIMELINE SAFSTOR (not to scale) UnitL Shrrtdown Period 1 Period5 Period2 Per'od3 Period4 Site SAFSTOR Dormancy Preparations Decommissioning Preparatio16

                                                                                                             .i,ffI irr<i
                                                                                                             =.:ii A

Aug2037 Nov2088 Jun2090 Jan2096

           ,                 ,."r..,                              I

_r-_:,

                                                  . .             I DrytuelstoraSe Unit2FuerPoor                                        I vav 20s+

l unit2 l Shtrtdown I

                       ?l li^llrill                I      period2          leerodrl           e e r i o a +l ' 1 l " j '

lereparatiorsl I Dormarry lPreparatioml DecommbsioninglRestoratic A May 2047 lan Sep2089 Mar 2091 TLG Seruices, fnc.

Beauer Valley Power Station Document F07- 1696-001, Rev. 0 D ecommi ssioning Cost An aly si s Section 5, Page 1 of 6

5. RADIOACTIVE WASTES The objectivesof the decommissioningprocess 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 excessof applicable legal limits. Under the Atomic Energy [gf,t35l fhs NRC is responsiblefor protecting the public from sourcesof 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 burial are categorizedas Low SpecificActivity (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 S173.411).For this study, commercially available steel containers are presumed to be used for the disposal of piping, small components, and concrete. Larger componentscan serve as their own containers, with proper closure of all openings, accessways, and penetrations. The destinations for the various waste streams from decommissioningare identified in Figures 5.1 and 5.2. The volumes are shown on a line-item basis in AppendicesC and D and summarized in Tables 5.1 and 5.2. The volumes are calculated based on the exterior dimensions for containerized material and on the displaced volume of componentsserving as their own waste containers. The reactor vessel and internals are categorizedas large quantity shipments and, accordingly,will be shipped in reusable,shielded truck caskswith disposableliners. In calculating disposal costs,the burial fees are applied against the liner volume, as well as the specialhandling requirements of the payload. Packagingefficienciesare 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 containers. No process system containing/handling radioactive substances at shutdown is presumed to meet material releasecriteria by decay alone (i.e., systemsradioactive at shutdown will still be radioactive over the time period during which the decommissioningis accomplished,due to the presenceof long-lived radionuclides). While the dose rates decrease with time, radionuclides such as 137Cswill still control the dispositionrequirements. TLG Seruices. Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecornmi ssioning Cost An aly sis Section 5, Page 2 of 6 The waste material produced in the decontamination and dismantling of the nuclear plants is primarily generatedduring Period 2 of DECON and Period 4 of SAFSTOR. Material that is considered potentially contaminated when removed from the radiological controlled area is sent to processingfacilities in Tennesseefor conditioning. Heavily contaminatedcomponentsand activated materials are routed for controlled disposal. The disposal volumes reported in the tables reflect the savingsresulting from reprocessingand recycling. For purposes of constructing the estimates, the current cost for disposal at EnergySolutions facility in Clive, Utah was used for a majority of the radioactive waste produced from the decommissioningactivities. A common rate was used for containerized waste and large components. Demolition debris including miscellaneoussteel, scaffolding,and concrete was disposedof at a bulk rate. The decommissioningwaste stream also included resins and dry active waste. Since EnergySolutions is not currently able to receive the more highly radioactive components generated in the decontamination and dismantling of the disposal costs for the Class B and C material were based upon preliminary information from WCS on the cost at the Andrews Countv. Texas facilitv. TLG Seruices. Inc.

Beaver VaIIey Power Station Document F07-16 96-001, Reu. 0 D ecommissioning Cost Analy sis Section 5, Page 3 of 6 FIGURE 5.1 RADIOACTIVE WASTE DISPOSITION Resin/ Filters i lclarsA)

  ,'---   o**oo*u-.-'4.,

Low-LevelRadioactiveWaste

              ':y'- --t' TLG Seruices, Inc.

Beaver Valley Power Station Document F07-1696-001,Reu. 0 D ecommissioning Cost An aly si s Section 5, Page 4 of 6 FIGURE 5.2 DE COMMISSIONINGWASTE DESTINATIONS RADIOLOGICAL TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 Decommissioning Cost Analysis Section 5, Page 5 of 6 TABLE 5.1 INTEGRATED DE CON ALTERNATIVE DECOMMISSIONINGWASTE

SUMMARY

I i rWasteVolume Weight Waste i CostBasis -----il J Classt1li (cubicfeet) lli i-*-& Low-Level Radioactive ! EnergySolutions i I talri225,172 19,074,413 Waste (near-surface ;i u-Yv-rflelll9{.r499 o n t a r n e r r z e c t , Ai_," i .{:* j disposal) i EnergS'Solutions i i I nrr I ^ i 229,537 17,279,765 266,793 t3t3tt Greater than ClassC Spent Fuel Jsfal tzl 460,746 37,294,930 off-site rng center 551.097 Scra Metal L54,252,000 tll Waste is classified accordingto the requirements as delineated Title 10 CFR,Part 61.55 Columns may not add due to rounding. TLG Services, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu, 0 D ecomrni ssion ing Cost An aly si s Section 5, Page 6 of 6 ui,'*rrvE sAFSr#N""rt DE COMMISSIONING WASTE

SUMMARY

i ! Waste Volume Weight CqstF_4s!p**Clssslll f -(*"bjs-f.sg unds iii ill rli *--@* +-. .""." j ..,,,,.,. - -.*@ Low-Level Radioactive j Energ}'Solutions i j tr;,Id:',ffi?i:1"' d;Li#*LL-a-j-- Ii E*;Ftys"l"rr# ooo^

                                                                                -"lTjf              18,579,255 disposal)                                                          ',

I "*"^'i:_;,_ I IJUIK I 1 A n 208,076 L5,625,r52 r---*--"----*f 111,789 WCS 130,371 Greater than ClassC Spent Fuel 34,990,155 i ScrapMetal i 154,964,000 t1l Waste is classified accordingto the requirements as delineated in Title 10 CFR,Part 61.55 Columns may not add due to rounding. TLG Seruices,Inc.

Beauer Valley Power Station Docutnent F07-1696-001,Reu. 0 D ecommissioning Cost Analy sis Section 6, Page 1 of 5

6. RESULTS The analysis to estimate the costs to decommissionBeaver Valley relied upon the site-specific, technical information provided by FirstEnergy. While not an engineering study, the estimates provide the owner with sufficient information to assesstheir financial obligations as they pertain to the eventual decommissioningof the nuclear station.

The estimates described in this report are based on numerous fundamental assumptions, including regulatory requirements, project contingencies,low-Ievel radioactive waste disposal practices, high-level radioactive waste management options, and site restoration requirements. The decommissioningscenariosassume continued operation of the spent fuel pools for a minimum of seven years following the cessationof each unit's operationsfor continued cooling of the assemblies. The cost projected to promptly decommissionthe station (Integrated DECOITI), dismantle the structures, and manage the spent fuel is shown in Table 6.1. The majority of the cost (approximately 70.8o/o)is associated with the physical decontaminationand dismantling of the nuclear plant so that the operating licenses can be terminated. Another 2l.lo/o is associatedwith the management, interim storage, and eventual transfer of the spent fuel. The remaining 8.1% is for the demolition of the designatedstructures and limited restoration of the site. The cost projectedfor deferred decommissioning(SAFSTOR)is shown in Table 6.2. The majority of this cost (approximately 72.4o/o)is associatedwith 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 2A.6% is associated with the management, interim storage, and eventual transfer of the spent fuel. The remaining 7.0% is for the demolition of the designated structures and limited restoration of the site. The primary cost contributors, identified in Tables 6.1 and 6.2, ate either labor-related or associatedwith the managementand disposition of the radioactive waste. Program management is the largest single contributor to the overall cost. The magnitude of the expenseis a function of both the size of the organization required to manage the decommissioning, as well as the duration of the program. This analysis assumesthat FirstEnergy will overseethe decommissioningprogram using a DOC to manage the decommissioning labor force and the associated subcontractors.The size and composition of the management organization varies with the decommissioningphase and associatedsite activities. However, once the operating licensesare amended or terminated, the staff is substantially reducedfor TLG Seruices, Inc.

Beaver VaIIey Power Station Document F07-1696-001,Reu. 0 Decomrnissioning Cost Analy sis Section 6, Page 2 of 5 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 seven years following the cessationof each unit's operations. The pools will be isolated and independent spent fuel islands created. This will allow decommissioningoperations to proceed in and around the pool areas. Over the seven year period, the spent fuel will be either shipped to DOE or packaged into transportable canisters for relocationto the ISFSI. The cost for waste disposal includes only those costs associatedwith the controlled disposition of the low-level radioactive waste generatedfrom decontamination and dismantling activities, including plant equipment and components, structural material, filters, resins and dry-active waste. As describedin Section 5, disposition of the majority of the low-level radioactive material requiring controlled disposalis at the EnergySolutions' facility. Highly activated componentsrequiring additional isolation from the environment (GTCC) are packagedfor geologicdisposal.The cost of geologicdisposal is basedupon a cost equivalent for spent fuel. A significant portion of the metallic waste is designatedfor additional processing and treatment at an off-site facility. Processing reduces the volume of material requiring controlled disposal through such techniques and processesas survey and sorting, decontamination, and volume reduction. The material that cannot be unconditionally released is packagedfor controlled disposal at one of the curuently operating facilities. The cost identified in the summary tables for processingis all-inclusive, incorporating the ultimate disposition of the material. Removalcosts reflect the labor-intensive nature of the decommissioningprocess,as well as the management controls required to ensure a safe and successfulprogram. Decontamination and packagrng costs also have a large labor component that is based upon prevailing wages. Non-radiological demolition is a natural extension of the decommissioning process. The methods employed in decontamination and dismantling are generally destructive and indiscriminate in inflicting collateral damage.With a work force mobilized to support decommissioningoperations, non-radiological demolition can be an integrated activity and a logical expansion of the work being performed in the processof terminating the operating licenses. The reported cost for transport includes the tariffs and surcharges associatedwith moving large componentsand/or overweight shielded casks overland, as well as the general expense, i.e., labor and fuel, of transporting material to the destinations identified in this report. For purposesof this analysis, material is primarily moved overland by truck. TLG Seruices, Inc.

Beauer Valley Pouter Station Document F07-1696-001,Rev. 0 D ecomm.i ssinning Cost Analy sis Section 6, Page 3 of 5 Decontamination is used to reduce the plant's radiation fields and minimize worker exposure.Slightly contaminatedmaterial or material locatedwithin a contaminated area is sent to an off-site processing center; this analysis does not assume that contaminated plant components and equipment can be decontaminated for uncontrolled release in-situ. Centralized processing centers have proven to be a more economicalmeans of handling the large volumes of material produced in the dismantling of a nuclear plant. License termination survey costs are associated with the labor intensive and complex activity of verif ing that contamination has been removed from the site to the levels specified by the regulating agency. 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 componentsand materials not removed in the decommissioningprocesswill also require confirmation and will add to the expenseof surveying the facilities alone. The remaining costs include allocations for heavy equipment and temporary services,as well as for other expensessuch as regulatory fees and the premiums for nuclear insurance. While site operating costs are greatly reduced following the fi.nal cessation of plant operations, certain administrative functions do need to be maintained either at a basic functional or regulatory level. TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Rev. 0 D ecommissio n ing Cost An aly si s Section 6, Page 4 of 5 TABLE 6.1 INTEGRATED DE CONALTERNATIVE DECOMMISSIONINGCOSTELEMENTS (thousands of 2014dollars) c-eelFLelqet! ** ^)i Total Percen Decontamination 29.136 1.8 Removal 252.115 15.6 Rqgkustng_ 44,r87 2.7 T19L4gp.q_r!-etiqn 34.309 2.7 Wasle---Diepqp+l." *_ fi "_"!24,417" '* '* 77 Off-siteWasteProcessing i 62.133 3.9 Prgs{aTlrMqq-a ggper-tj"t! 084 31.1 Site Securitv

       * -     .     . q *   , , " . , , " " _

139.991 8.7 nt Fuel Pool Isolation 20,724 1.3 nt Fuel @irect Expenditures) tzl 165.474 10.3 I n surance and $_e_gulg_! gly_Fees 54,318 3.4 I Energf,.. ... 33.470 2.7 Characterization and Licensing Surveys 39,352 2.4 Taxes 39,399 2.4 Miscellaneous 16.962 1.1

       ,C_grporate   A&G                                                54.L37           3.4 Total tsl                                                    r.612.204         100.0 CostElement                                                    Total       Percentage LicenseTermination                                            1.141.005          70.8
      $p_e  qt Fqp,l,-M   4nagement                                   340.745          2r.7 Site Restoration                                                130.453            8.1 Tohl tel                                                      r,6L2,204         100.0 t11   Includes engineeringcosts t?l   Excludesprogram managementcosts(staffrng)but includes costsfor spent fuel loading/transfercosts/spentfuel pool O&M and EP fees Columns may not add due to rounding TLG Seruices, Inc.

Beauer VaIIey Power Station Document F07-1696-001,Reu. 0 D ecomtnissioning Cost Analy sis Section 6, Page 5 of 5 TABLE 6.2 SAFSTORALTERNATIVE DECOMMISSIONINGCOSTELEMENTS (thousands of 2014dollars) CostElement Total Percentage Decontamination 28.340 1.5 Removal 254.016 13.5 P_ackagng 32,295 r.7 Transpo:tation 30.175 1.6 W*s!eQiqpqsal t05.677 5.6 Off-site Waste Processing 65,093 3.5 Program Management ul 599,909 31.9 Site Security 221.383 11.8 EUelPoolIsolation _S11e11!, 20.724 1.1 9p94_tFuel @irect Expenditures) tzt 161.618 8.6 [g--gurance and Regulatory Fees r08,220 5.8 Eqersv 50.101 2.7 Characterization and Licensins Survevs 39.644 2.1 Propertv Taxes 63,375 3.4 Miscellaneous 37"863 2.0 CorporateA&G 64,013 3.4 fetal tsl t.882,446 100.0 CostElement "" Tolal" r.362.296, r2"4 Spent Fuel Management 387,899 20.6 Site Restoration L32,250 7.0 Total t3l r.882.446 100.0 tl1 Includes engineeringcosts 12] Excludesprogram managementcosts(staffrng)but includes costsfor spent fuel loading/transfer costs/spentfuel pool O&M and EP fees t31 Columns may not add due to rounding TLG Seruices, Inc.

Beaver Valley Power Station Docurnent F07-1696-001,Reu. 0 D ecom.missioning Cost Analysis Section 7, Page I of 3

7. REFERENCES

1. "DecommissioningCost Analysis for the Beaver Valley Power Station," TLG ServicesDocumentNo. F07-1619-002. Rev. 0. November2009

2. U.S. Code of Federal Regulations,Title 10, Parts 30, 40, 50, 51, 70 and 72, "General Requirements for Decommissioning Nuclear Facilities," Nuclear RegulatoryCommission,53 Fed.Reg. 24018,June 27,1988

3. U.S. Nuclear Regulatory Commission,Regulatory Guide 1.159, "Assuring the Availability of Funds for DecommissioningNuclear Reactors,"Rev. 2, October 2017

4. U.S. Code of Federal Regulations, Title 10, Part 20, Subpart E, "Radiological Criteria for License Termination"

5. U.S. Code of Federal Regulations, Title 10, Parts 20 and 50, "Entombment Options for Power Reactors,"Advanced Notice of ProposedRulemaking, 66 Fed.

Reg.52551,October16,2001

6. 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

7. U.S. Code of Federal Regulations,Title 10, Parts 20, 30, 40, 50, 70, and 72, "Decommissioning Planning," Nuclear Regulatory Commission, Federal RegisterVolume 76, (p 35512et seq.),June 17,20LI

8. "Nuclear Waste Policy Act of 1982," 42 U.S. Code 10101, et seq.

http ://pbadunws.nrc.gov/docs/lVll,1 327lIVIL132744489.pdf#page=4 19.

9. United States Court ofAppeals for the District Of Columbia Circuit, In Aiken County, Et Al., August 2013, http://www.cadc.uscourts.gov/internet/opinions.nsf/BAE0CF34F762EBD985257 BC6004DEB1S/$fite/1 1-1271-1451347.pdf

10. Charter of the Blue Ribbon Commission on Nuclear Future, "Objectivesand Scopeof Activities,"

http ://www.brc.gov/index.php?q=paee/charter

11. "BIue Ribbon Commissionon America's Nuclear Future, Report to the Secretary of Energy,"http:/lwww.brc.qov/, p.32, January 2Ol2 TLG Seruices, Inc.

Beauer VaIIey Power Station Document F07-1696-001,Reu. 0 D ecomm.issioning Cost Analysis Section 7, Page 2 ofJ

7. REFERENCES (continued)

12. "Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level RadioactiveWaste,"U.S. DOE, January 71,2013

13. "AcceptancePriority Ranking & Annual Capacity Report," DOE/RW-0567,2004 14.U.S. Code of Federal Regulations,Title 10, Part 50, "Domestic Licensing of Production and Utilization Facilities," Subpart 54 ftb), "Conditions of Licenses" 1 5 . U.S. Code of Federal Regulations,Title 10, Pafi 72.40 Subpart K, "General Licensefor Storageof Spent Fuel at Power ReactorSites" 1 6 . "Low Level RadioactiveWaste Policy Act," Public Law 96-573, 1980 L 7 . "Low-Level RadioactiveWaste Policv Amendments Act of 1985."Public Law 99-240, 1986 1 8 . U.S. Codeof Federal Regulations,Title 10, Part 61.55 "Waste Classification"

19. U.S. Code of Federal Regulations, Title 10, Part 20, Subpart E, "Final RuIe, Radiological Criteria for License Termination," 62 Fed. Reg. 39058, July 21, r997

20. "Establishment of Cleanup Levels for CERCLA Sites with Radioactive Contamination,"EPA MemorandumOSWER No. 9200.4-18,August 22,1997 2 t . 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"

22. "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,October9, 2002

23. "Multi-Agency Radiation Survey and Site Investigation Manual (IVIARSSIM),"

NUREG/CR-1575,Rev. 1, EPA 402-R-97-016, Rev. 1, August 2000

24. T.S. LaGuardia et aI., "Guidelines for Producing Commercial Nuclear Power Plant DecommissioningCost Estimates,"AIF/NESP-036,May 1986 TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissioning Cost Analysis Section 7, Page 3 of 3

7. REFERENCES (continued)

25. W.J. Manion and T.S. LaGuardia, "Decommissioning Handbook,"

Department of Energy,DOE/EV/I0128-l, November 1980

26. "Building ConstructionCost Data 2OI4," Robert Snow Means Company, Inc.,

Kingston, Massachusetts

27. Project and Cost Engineers' Handbook, Second Edition, p. 239, American Associationof CostEngineers,Marcel Dekker, Inc., New York, New York, 1984

28. U.S. Department of Transportation,Title 49 of the Codeof Federal Regulations, "Transportation,"Parts 173 through 178

29. Tri-State Motor Transit Company, published tariffs, Interstate Commerce Commission (ICC), Docket No. MC-4277t9 Rules Tariff, March 2004, RadioactiveMaterials Tariff, August 2011

30. J.C. Evans et al., "Long-Lived Activation Products in Reactor Materials" NUREG/CR-3474, Pacific Northwest Laboratory for the Nuclear Regulatory Commission,August 1984

31. R.I. Smith, G.J. Konzek, W.E. Kennedy, Jr., "TechnologS', Safety and Costsof Decommissioning a Reference Pressurized Water Reactor Power Station,"

NUREG/CR-0130 and addenda, Pacific Northwest Laboratory for the Nuclear Regulatory Commission,June 1978

32. H.D. Oak, et al., "Technolog)r,Safety and Costsof Decommissioninga Reference Boiling Water Reactor Power Station," NUREG/CR-0672and addenda, Pacific Northwest Laboratory for the Nuclear Regulatory Commission,June 1980

33. SECY-00-0145, "Integrated Rulemaking Plan for Nuclear Power Plant Decommissioning,"June 2000."Microsoft Project Professional 2010," Microsoft Corporation, Redmond,WA

34. "Microsoft Project Professional 20 13," Microsoft Redmond.WA

35. "Atomic Energy Act of 1954,"(68 Stat. 919)

TLG Seruices,Inc.

Beauer Valley Power Station Docurnent F07- 1696-001, Reu. 0 D ecommissioning Cost Analysis Appendix A, Page 1 of 4 APPENDXA UNIT COSTFACTOR DEVELOPMENT TLG Seruices.Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissioning Cost Analysis Appendix $ Page 2 of 4 APPENDD(A UNIT COSTFACTORDEVELOPMENT Example: Unit Factorfor Removalof Contaminated Heat Exchanger < 3,000lbs.

1. SCOPE Heat exchangersweighing < 3,000 lbs. will be removedin one piece using a crane or small hoist. They will be disconnectedfrom the inlet and outlet piping. The heat exchangerwill be sent to the waste processingarea.

2. CALCUI"ATIONS Activity Critical Act Activity Duration Duration ID Description (minutes) (minutes)"

a Removeinsulation 60 o) b Mount pipe cutters 60 60 c Install contamination controls 20 (b) d Disconnectinlet and outlet lines 60 60 e Cap openings 20 (d) f Rig for removal 30 30 o b Unbolt from mounts 30 30 h Removecontamination controls 15 15 i Remove,wrap, send to waste processingarea 60 60 Totals (Activity/Critical) 355 255 Duration adjustment(s):

 + Respiratory protection adjustment (50%of critical duration)                                 r28
 + Radiationr/AL\Iil\ adjustment (37.1%of critical duration)                                     95 Adjusted work duration                                                                          478

Protective clothing adjustment (30%of adjusted duration) L43 Productive work duration 62L

 + Work break adjustment (S.33% of productiveduration)                                           52 Total work duration (minutes)                                                                   673
                            'r** Total duration = lI.2L7 hr #*

alpha designators indicate activities that can be performed in paraliel TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 Decommissioning Cost Analysis Append.ix A" Page 3 of 4 APPENDXA (continued)

3. LABOR REQUIRED Duration Rate Crew Number (hours) ($/hr) Cost Laborers 3.00 II.2T7 $41.34 $1,391.13 Craftsmen 2.00 tr.2r7 $63.31 $1,420.30 Foreman 1.00 tr.2r7 $67.33 $755.24 GeneralForeman 0.25 rt.2r7 $72.68 $203.81 Fire Watch 0.05 TI.2T7 $41.34 $23.19 Health PhysicsTechnician 1.00 r']-,.217 $48.36 8542.45 Total Labor Cost $4,336.12

4. EQUTPMENT& CONSUMABLESCOSTS Equipment Costs Consumables/lVlaterialsCosts

-UniversalSorbent50 @$0.62sq. ft. {4                                     $31.00
-Tarpaulins(7.5mils, oil resistant,fire retardant) 50 @        ft. {2}   $14.00
-Gastorch consumables1@ $19.65/hr.x t hr. {s}                            $19.65 Subtotal cost of equipment and materials                                  $64.65 Overhead& profit on equipment and materials @ 16.00%                      $10.34 Total costs,equipment & material                                          $74.99 TOTAL COST:

Removal of contaminated heat exchanger <3000 pounds: $4,411.11 Total labor cost: $4,336.12 Total equipment/materialcosts: 877.9e Total craft labor man-hoursrequired per unit: 81.88 TLG Seruices,Inc.

Beauer VaIIey Power Station Document F07-1696-001,Reu. 0 D ecommissioning Cost An aly sis Appendix A, Page 4 of 4 APPENDD(A (continued)

5. NOTESAND REFERENCES Work diffrculty factors were developed in conjunction with the Atomic Industrial Forum's (now NEI) program to standardizenuclear decommissioning cost estimates and are delineated in Volume 1, Chapter 5 of the "Guidelines for ProducingCommercialNuclear Power Plant DecommissioningCost Estimates,"

AIF/NESP-036.Mav 1986. Referencesfor equipment& consumablescosts:

1. www.mcmaster.comonline catalog,McMaster Carr Spill Control (71e3T88)

2. R.S.Means (201a)Division 01 56, Section13.60-0600, page 23

3. R.S.Means (201a)Division 01 54 33, Section40-6360,page 698 Material and consumable costs were adjusted using the regional indices for Pittsburgh, Pennsylvania.

TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1690-001,Reu. 0 D ecornmi ssionin g Cost An aly sis Appendix B, Page 1 of 7 APPENDD( B UNIT COSTFACTOR LISTING (DECON:Power Block Structures Only) TLG Services. Inc.

Beaver Valley Power Station Document F07-1696-001,Reu. 0 D ecommis sioning Cost Analy si s Append.ixB, Page 2 of 7 APPENDX B UNIT COSTFACTORLISTING (Power Block Structures Only) Unit Cost Factor Cost/Unit($) Removal of clean instrument and sampling tubing, $/linear foot a.48 Removalof cleanpipe 0.25to 2 inchesdiameter,$Ainearfoot 5.03 Removalof cleanpipe >2 to 4 inchesdiameter,$Ainearfoot 7. 34 Removalof cleanpipe >4 to 8 inchesdiameter,$/linear foot r4.79 Removalof cleanpipe >8 to 14 inchesdiameter,$/linear foot 28.05 Removalof cleanpipe >14 to 20 inchesdiameter,$/linear foot 36.55 Removalof cleanpipe >20 to 36 inchesdiameter,$/linear foot 53.76 Removal of clean pipe >36 inches diameter, $/linear foot 63.83 Removalof cleanvalve >2to 4 inches 97.67 Removalof cleanvalve >4to 8 inches I47.89 Removal of clean valve >8 to 14 inches 280.46 Removalof cleanvalve >14 to 20 inches 365.52 Removal of clean valve >20 to 36 inches 537.59 Removalof cleanvalve >36 inches 638.33 Removal of clean pipe hanger for small bore piping 33.76 Removal of clean pipe hanger for large bore piping 115.71 Removalof cleanpump, <300 pound 251.25 Removalof cleanpuffip, 300-1000pound 705.65 Removalof cleanpump, 1000-10,000pound 2,760.98 Removalof cleanpump, >10,000pound 5,345.91 Removalof cleanpump motor, 300-1000pound 294.r5 Removalof cleanpump motor, 1000-10,000pound 1,146.06 Removalof cleanpump motor, >10,000pound 2,578.62 Removalof cleanheat exchanger<3000pound L,488.24 Removalof cleanheat exchanger>3000pound 3,754.98 TLG Seruices, Inc.

Beaver VaIIey Power Station Document F07-1696-001,Reu. 0 D ecommissioning Cost Analysis Append.ix B, Page 3 of 7 APPENDX B UNIT COSTFACTORLISTING (Power Block Structures Only) Unit Cost Factor Cost/Unit($) Removalof cleanfeedwaterheater/deaerator r0,545.20 Removalof cleanmoisture separator/reheater 2I,626.30 Removalof cleantank, <300 gallons 322.99 Removalof cleantank, 300-3000gallon 1,014.99 Removalof clean tank, >3000 gallons, $/squarefoot surface area 8.68 Removalof cleanelectricalequipment,<300pound L35.32 Removalof cleanelectricalequipment,300-1000pound 478.89 Removalof cleanelectricalequipment, 1000-10,000 pound 957.79 Removalof cleanelectricalequipment,>10,000pound 2,299.44 Removal of clean electrical transformer < 30 tons 1,596.94 Removal of clean electrical transformer > 30 tons 4,598.88 Removalof clean standby dieselgenerator,<100 kW 1,631 .13 Removal of clean standby diesel generator, 100 kW to 1 MW 3,640.79 Removal of clean standby diesel generator,>1 MW 7,537.r5 Removal of clean electrical cable tray, $Ainear foot L2.78 Removal of clean electrical conduit, $/Iinear foot 5.59 Removalof clean mechanicalequipment,<300pound 135.32 Removalof cleanmechanicalequipment,300-1000pound 478.89 Removalof cleanmechanicalequipment,1000-10,000pound 957.79 Removalof cleanmechanicalequipment,>10,000pound 2,299.44 Removal of clean I{VAC equipment, <300 pound 163.64 Removalof cleanHVAC equipment,300-1000pound 575.43 Removalof cleanIIVAC equipment, 1000-10,000 pound 1,146.83 Removalof cleanHVAC equipment,>10,000pound 2,299.44 Removalof clean HVAC ductwork, g/pound 0.51 TLG Services, Inc.

Beaver Valley Power Station Document F07-1696-001,Reu, 0 D ecornmissioning Cost Analysis Appendix B, Page 4 of 7 APPENDX B UNIT COSTFACTOR LISTING (Power Block Structures Only) Unit Cost Factor Cost/Unit($) Removalof contaminated instrument and sampling tubing, $/linear foot L.49 Removalof contaminatedpipe 0.25to 2 inchesdiameter,g/linear foot 20.93 Removalof contaminatedpipe >2 to 4 inchesdiameter,$Ainearfoot 36.17 Removalof contaminated pipe >4 to 8 inches diameter, $Ainearfoot 58.39 Removalof contaminated pipe >8 to 14 inches diameter, $/linear foot 113.49 Removalof contaminated pipe >14 to 20 inches diameter, $/linear foot 136.31 Removalof contaminated pipe >20 to 36 inches diameter, $/linear foot 188.39 Removalof contaminated pipe >36 inches diameter, $/linear foot 222.51 Removalof contaminatedvalve >2to 4 inches 442.59 Removalof contaminatedvalve >4to 8 inches 533.95 Removalof contaminated valve >8 to 14 inches 1,082.7r Removalof contaminated valve >14 to 20 inches 1,376.28 Removalof contaminated valve >20 to 36 inches 1,831.75 Removalof contaminated valve >36 inches 2,L72.85 Removalof contaminated pipe hanger for small bore piping 141.39 Removalof contaminated pipe hanger for large bore piping 454.32 Removalof contaminatedpump, <300pound 954.51 Removalof contaminatedpump, 300-1000pound 2,242.09 Removalof contaminatedpump, 1000-10,000pound 7,282.75 Removalof contaminatedpump, >10,000pound 17,74r.50 Removalof contaminatedpump motor, 300-1000pound 955.45 Removalof contaminatedpump motor, 1000-10,000pound 2,965.93 Removalof contaminatedpump motor, >10,000pound 6,658.90 Removalof contaminatedheat exchanger<3000pound 4,4ll.lr Removalof contaminatedheat exchanger>3000pound 12,800.42 TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissio ning Cost An aly si s Appendix B, Page 5 of 7 APPENDD( B UNIT COSTFACTOR LISTING (Power Block Structures Only) Unit Cost Factor Cost/Unit($) Removalof contaminatedtank, <300 gallons 1,586.66 Removalof contaminatedtank, >300 gallons,$/squarefoot 31.42 Removalof contaminatedelectricalequipment,<300pound 735.30 Removalof contaminatedelectricalequipment,300-1000pound 1,814.81 Removalof contaminatedelectricalequipment, 1000-10,000 pound 3,494.74 Removal of contaminated electricalequipment,> 10,000pound 6,911.34 Removal of contaminated electrical cable tray, $Ainearfoot 35.62 Removal of contaminated electrical conduit, $Ainear foot 16.95 Removal of contaminated mechanicalequipment,<300pound 818.29 Removalof contaminated mechanicalequipment,300-1000pound 2,005.27 Removalof contaminatedmechanicalequipment,1000-10,000 pound 3,855.23 Removalof contaminatedmechanicalequipment,>10,000pound 6,911.34 Removal of contaminated HVAC equipment, <300 pound 818.29 Removalof contaminatedHVAC equipment,300-1000pound 2,005.27 Removalof contaminatedHVAC equipment, 1000-10,000 pound 3,855.23 Removalof contaminatedIIVAC equipment,>10,000pound 6,911.34 Removal of contaminated m/AC ductwork, g/pound 2. t5 RemovaVplasmaarc cut of contaminated thin metal components,$Ainear in. 3.97 Additional decontaminationof surface by washing, g/squarefoot 8.04 Additional decontaminationof surfacesby hydrolasing, $/squarefoot 37.72 Decontamination rig hook up and flush, g/ 250 foot length 6,919.30 Chemical flush of components/systems,g/gallon 19.89 Removal of clean standard reinforced concrete,$/cubicyard 151.90 Removal of grade slab concrete,$/cubicyard 198.43 Removal of clean concretefloors. $/cubicvard 400.54 TLG Seruices, Inc.

Beauer Valley Power Station Document F07- 1696-001, Reu. 0 D ecommissioning CostAnalysis Appendix B, Page 6 of 7 APPENDX B UNIT COSTFACTORLISTING (Power Block Structures Only) Unit Cost Factor Cost/Unit($) Removalof sectionsof cleanconcretefloors, $/cubicyard 1,181.88 Removalof cleanheavily rein concretew#9 rebar, $/cubicyard 260.18 Removal of contaminatedheavily rein concretewllfg rebar, $/cubicyard 2,277.06 Removalof cleanheavily rein concretew/#18 rebar, $/cubicyard 329.03 Removalof contaminatedheavily rein concretewi#18 rebar, $/cubicyard 3,013.15 Removalheavily rein concretewri#18rebar & steelembedments,$/cubicyard 490.08 Removal of below-gradesuspendedfloors, g/cubicyard 400.54 Removal of clean monolithic concretestructures, $/cubicyard 978.54 Removal of contaminatedmonolithic concretestructures, $/cubicyard 2,269.6I Removalof cleanfoundationconcrete,$/cubicyard 770.72 Removal of contaminatedfoundation concrete,$/cubicyard 2,1L5.02 Explosive demolition of bulk concrete,g/cubicyard 34.35 Removal of clean hollow masonry block wall, g/cubicyard 101.39 Removal of contaminatedhollow masonry block wall, g/cubicyard 331.09 Removal of clean solid masonry block wall, g/cubicyard 101.39 Removal of contaminated solid masonry block wall, g/cubicyard 331.09 Backfill of below-gradevoids, $/cubicyard 34.85 Removal of subterraneantunnels/voids. SAinearfoot 120.94 Placement of concretefor below-gradevoids, g/cubicyard L3L.42 Excavation of clean material, $/cubicyard 3.51 Excavation of contaminated material, $/cubicyard 45.73 Removal of clean concreterubble (tipping fee included), g/cubicyard 26.62 Removal of contaminated concreterubble, $/cubicyard 29.08 Removalof building by volume, g/cubicfoot 0.34 Removal of clean building metal siding, $/squarefoot 1.32 TLG Seruices. Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecornmissioning Cost Analysis AppendixB, Page 7 of 7 APPENDX B UNIT COSTFACTORLISTING (Power Block Structures Only) Unit Cost Factor Cost/Unit($) Removal of contaminatedbuilding metal siding, g/squarefoot 4.39 Removal of standard asphalt roofing, $/squarefoot 2.25 Removalof transite panels,$/squarefoot 2.24 Scarifuing contaminated concretesurfaces(drill & spall), $/squarefoot 13.18 Scabblingcontaminated concretefloors, $/squarefoot 7.94 Scabblingcontaminated concretewalls, $/squarefoot 20.92 Scabblingcontaminated ceilings, $/squarefoot 7L.73 Scabblingstructural steel, $/squarefoot 6.46 Removal of clean overheadcrane/monorail< 10 ton capacity 684.82 Removal of contaminated overheadcrane/monorail< 10 ton capacity 1,89r.2r Removal of clean overheadcrane/monorail>10-50ton capacity L,643.54 Removal of contaminated overheadcrane/monorail>10-50 ton capacity 4,538.12 Removal of polar crane > 50 ton capacity 6,919.46 Removal of gantry crane > 50 ton capacity 28,743.0t Removal of structural steel, $/pound 0.22 Removal of clean steel floor grating, $/squarefoot 5.19 Removal of contaminated steel floor grating, $/squarefoot t4.65 Removal of clean free standing steel liner, $/squarefoot 13.02 Removal of contaminated free standing steel liner, $/squarefoot 36.71 Removal of clean concrete-anchoredsteel liner, $/squarefoot 6.51 Removal of contaminated concrete-anchoredsteel liner, $/squarefoot 42.81 Placement of scaffoldingin clean areas, $/squarefoot 15.7t Placement of scaffoldingin contaminated areas, $/squarefoot 25.57 Landscapingwith topsoil, g/acre 25,599.00 Cost of CPC B-88 LSA box & preparation for use 2,120.2L TLG Seruices, Inc.

Beauer Valley Power Station Document F07-1696-001,Reu. 0 D ecommissio ning Cost An aly sis Appendix B, Page I of 7 APPENDX B UNIT COSTFACTOR LISTING (Power Block Structures Only) Unit Cost Factor CosUUnit($) Costof CPCB-25 LSA box & preparationfor use 1,937.89 Costof CPCB-12V 12 gaugeLSA box & preparation for use r,576.22 Costof CPC8-144 LSA box & preparationfor use 10,887.11 Cost of LSA drum & preparation for use 245.67 Costof caskliner for CNSI S 1204.cask (resins) 12,644.95 Cost of cask liner for CNSI 8 120.4.cask (filters) 9,062.22 Decontaminationof surfaceswith vacuuming, $/squarefoot 0.84 TLG Seruices,Inc.

Beauer VaIIey Power Station Doeument F07-1696-00L Rev, 0 D ecornmissioning Cost An alysis Append.ix C, Page I of 23 APPENDD( C DETAILED COSTANALY$S INTEGRATEDDECON Paee BeaverValley PowerStation,Unit 1 ........C'2 BeaverValley PowerStation,Unit 2 ......C'14 TLG Seruiceq Inc.

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Enclosure B L-15-101 DecommissioningCost Analysisfor the PerryNuclearPowerPlant, February2015 (127pagesfollow)

Document F07-1699-001.Reu. 0 DECOMMISSIONINGCOSTANALYSIS for the PERRY NUCLEAR POWER PLANT prepared for FirstEnergy Corp. prepared by TLG Services, Inc. Brid gewateroConnecticut February 2015

Perry Nuclear Power Plant Document F07-1699-001,Rev. 0 D ecommissinning Cost Analysis Page ii of xx APPROVALS Fr*j**tFlanag*r aet{ Dste / FralectSagin**r dtu tr*te Techniaal Maneger TLG Seruices. Inc.

Perry Nuclear Power Plant Docurnent F07-1699-001,Reu. 0 D ecommissio n ing Cost An aly sis Page iii of xx TABLE OF CONTENTS SECTION PAGE EXECUTI\IE

SUMMARY

........... .....vii-xx

1. INTRODUCTION ................1-1 1.1 Objectivesof Study ......1-1 I.2 SiteDescription....... .....1-1 1.3 RegulatoryGuidance ...1-3 1.3.1 High L,evelWaste ..............1-5 I.3.2 Low-LevelRadioactiveWaste ............1-8 1.3.3 RadiologicalCriteria for LicenseTermination............ .......1-9

2. DECOMMISSIONINGALTERNATIVES ...........2.7 2 . r D E C ON ... .....2- 2 2.L.1 Period1- Preparations .....2-2 2.t.2 Period2 - Decommissioning Operations............. ................2-4 2.I.3 Period3 SiteRestoration.............. ...2-8 2.1.4 ISFSI Operationsand Decommissioning ..........2-9 2.2 SAFSTOR ..2.IA 2.2.L Period1- Preparations ...2-L0 2.2.2 Period2 - Dormancy........... ..............2-LL 2.2.3 Periods3 and 4 - DelayedDecommissioning.. .2-I2 2.2.4 Period5 - Site Restoration.............. .2-L3 cosT ESTIMATES............ ...................3-1 3 . 1 B a si so f E sti ma te s........... .............3- 1 3.2 Methodology............ .....3-1 3.3 FinancialComponentsof the CostModel............... ......3-3 3 .3 .1 C o n ti n g e n cy

                                    ............                                  ......... ..3- 3 3.3.2 FinancialRisk.........                                            ...........3-5 3.4 Site-Specffic       Considerations.......                         ...................3-6 3.4.1 SpentFuelManagement..                                      ..................3-6 3.4.2 ReactorVesseland Internal Components.........               .................3-9 3.4.3 Primary SystemComponents..............                        .............3-10 3.4.4 Main Turbineand Condenser..........                       .................3-10 3.4.5 TransportationMethods                                                     .3-10 3.4.6 Low-LevelRadioactiveWasteDisposal                               ...........3-11 3.4.7 Site ConditionsFollowing Decommissioning                                 ..3-12 TLG Seruices. Inc.

Perry Nuclear Power Plant Docurnent F07-1699-001,Rev. 0 D ecommissio ning Cost Analy sis Page iu of xx TABLE OF CONTENTS (continued) SECTION PAGE 3.5 3.6

4. SCHEDULEESTIMATE............ ........4-7 4.L Schedule Estimate Assumptions............ ......4-t 4.2 ProjectSchedule.. .........4-2 D. RADIOACTIVEWASTES ...5-1

6. RESULTS ...........6-1

7. REFERENCES......... ............7-1 TABLES DECON Decommissioning CostElements........ xix SAFSTORDecommissioning CostElements......... xx 3.1 DECON Alternative,Total Annual Expenditures.......... ................3-20 3.2 SAFSTORAlternative,Total Annual Expenditures........... ............3-22 5.1 DECONAlternativeW'asteSummary ...............5-5 5.2 SAFSTORAlternative Waste Summary ...........5-6 6.1 DECON Decommissioning CostElements........ ................6-4 6.2 SAFSTORAlternativeDecommissioning CostElements......... ........6-5 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001, Reu. 0 D econtmi ssion ing Cost An aly si s Page u of xx TABLE OF CONTENTS (continued) SECTION PAGE FIGURES 3.1 M a n p o w e rL e ve l s-D E C ONA lter native.............. ............ .3- 25 3.2 ManpowerLevels- SAFSTORAlternative......... .............3-26 4.I Activity Schedule -DECON. ...............4-3 4.2 Decommissioning Timeline,DECON.. ...............4-5 4.3 Decommissioning Timeline,SAFSTOR .............4-G 5.1 R a d i o a cti ve Wa steD i sp o si ti on.............. ........... ..5- 3 5.2 Decommissioning Waste Destinations,Radiological ........5-4 APPENDICES A. Unit CostFactorDevelopment........... A-1 B. Unit CostFactorListing.... B-1 C. DetailedCostAnalysis,DECON.............. ......... C-1 D. DetailedCostAnalysis,SAFSTOR........... ........D-1 E. DetailedCostAnalvsis.ISFSI E-1 TLG Seruices. Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu, 0 D ecommissio n ing Cost An aly si s Page ui of xx REVISION LOG No. Date Item Revised Reason for Revision 0 2lL3l20L5 Original Issue TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Rev. 0 D ecommi ssioning Cost An aly si s Page uii of xx EXECUTIVE

SUMMARY

This report presentsestimates of the cost to decommissionthe Perry Nuclear Power Plant (Perry) for the selected decommissioningscenarios following the scheduled cessation of plant operations. The analysis relies upon site-specific, technical information from an evaluation prepared in 2010,t11 revised in20L4 to reflect changes in the spent fuel scenario and security levels, and now updated to reflect current assumptionspertaining to the disposition of the nuclear unit and relevant industry experience in undertaking such projects. The current estimates are designed to provide the FirstEnergy Corp. with the information to assess its current decommissioningliability, as it relates to Perry. 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 an estimate prepared in advance of the detailed engineering required to carry out the decommissioningof the nuclear unit. It may also not reflect the actual plan to decommissionPerry; the plan may differ from the assumptions made in this analysis based on facts that exist at the time of decommissioning. The primary goal of decommissioningis the removal and disposal of the contaminated systems and structures so that the operating licensescan be terminated. This analysis recognizesthat spent fuel will be stored at the site in the wet storagepool and/or in an independent spent fuel storage installation (ISFSI) until such time that it can be transferred to an appropriate disposal facility. Consequently, the estimates include those costsnecessaryto manage and subsequentlydecommissionthese interim storage facilities. The costs to decommissionPerry for the scenariosevaluated are tabulated at the end of this section.Costs are reported in 2014 dollars and include monies anticipated to be spent for radiological remediation and operating license termination, spent fuel management,and site restoration activities. A discussionof 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 timeline for each scenario. I "DecommissioningCost Analysis for the Perry Nuclear Power Plant," DocumentF07-1619-003,Rev. 1, TLG Services,Inc., December2014 TLG Services.Inc.

Perry Nuclear Power Plant Docutnent F07-1699-001,Reu. 0 D ecornrnissioning Cost Analy sis Page uiii of xx Detailed cost reports used to generate the summary tables contained within this documentare providedin AppendicesC, D and E. The cost estimates assume that the shutdown date of the nuclear unit is scheduled and pre-planned(i.e.,there is no delay in transitioning the plant and workforce from operationsor in obtaining regulatory relief from operating requirements,etc.). The estimates include the continued operation of the spent fuel pool as interim wet fuel storagefacility for approximately sevenyears afbercessationof operations.During this time period, it is assumedthat the spent fuel residing in the pool will be transferred to an independentspent fuel storageinstallation (ISFSI) locatedon the site. The ISFSI will remain operational until the spent fuel is transferred to an appropriate disposal facility.tzt The cost elements in the estimates for the decommissioning alternatives are assignedto one of three subcategories:U.S. Nuclear Regulatory Commission (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 assuranceregulations (i.e., 10 CFR Part 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 FueI Management" subcategory contains costs associated with the containerization and transfer of spent fuel from the wet storage pool to an appropriate transport cask or to the ISFSI for interim storage, as well as the transfer of the spent fuel in storage at the ISFSI to a disposal facility. Costs are included for the operation of the storage pool and the management of the ISFSI until such time that the transfer is complete (spent fuel pool will operate until sevenyears after shutdown, and the ISFSI until all fuel is transferred to a disposal facility by 2064).It does not include any spent fuel managementexpensesincurred prior to the cessationofplant operations,nor doesit include any costsrelated to the final disposalof the spent fuel. "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 exposedto radioactive materials, as well as those 2 Projected expenditures for spent fuel management identified in the cost analyses do not consider credit for DOE's payment of damagesto FirstEnergy for DOE's failure to perform under the terms of the disposalcontract betweenDOE and FirstEnergy. Collectionof spent fuel damages from the DOE is expected to provide the majority of funds neededfor spent fuel management following shutdown. TLG Seruices, Inc.

Perry Nuclear Power Plant Docum.ent F07- 1699-001, Rev, 0 D ecommissio ning Cost An aly si s Page ix of xx facilities that have been decontaminated to appropriate levels. Structures are removedto a depth of three feet and backfilled to conformto local grade. It should be noted that the costs assigned to these subcategoriesare allocations. Delegationof cost elementsis for the purposeof comparison(i.e.,with NRC financial guidelines)or to permit specificfinancial 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 decideto remove non-contaminated structures early in the project to improve accessto highly contaminated facilitiesor plant components.In these instances,the non-contaminatedremoval 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 expectedto be incurred for the specific subcomponentsof the total estimatedprogram cost,if executedas described. Alternatives and Resulations The Nuclear Regulatory Commission (NRC) provided general decommissioning requirements in a rule adopted on June 27, L988. telIn this rule, the NRC set forth technical and financial criteria for decommissioning licensed nuclear facilities. The regulations addressedplanning needs, timing, funding methods, and environmental review requirements for decommissioning. The rule also defined three decommissioningalternatives as being acceptableto the NRC: DECON, SAFSTOR, and ENTOMB. DECON is defi.ned as "the alternative in which the equipment, structures, and portions of a facility and site containing radioactive contaminants are removed or decontaminatedto a level that permits the property to be released for unrestricted use shortly after cessation of oPerations."[41 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.'r[5] Decommissioningis required to be completed within 60 years, although U.S. Codeof Federal Regulations,Title 10,Parts 30, 40, 50, 51, 70 and 72 "GeneralRequirementsfor DecommissioningNuclear Facilities," lJ.S. Nuclear Regulatory Commission,Federal Register Volume 53, Number 123 (p 24018et seq.),June 27, 1988 4 Ibid. Page FR24022, Column 3 5 Ibid. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Rev. 0 D ecommi ssioning Cost Analy si s Page x of xx Ionger time periodswill be consideredwhen necessaryto protect public health and safety. ENTOMB is defined as "the alternative in which radioactive contaminants are encasedin 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 umestricted release of the property."t6lAs with the SAFSTORalternative, decommissioningis currently required to be completed within 60 years, although longer time periods will also be consideredwhen necessaryto 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 Commissiondirected its staff to re-evaluate this alternative and identifu 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 completionof additionalresearchstudies (e.g.,on engineeredbarriers). In 1996,the NRC published revisions to its general requirements for decommissioning nuclear power plants to clarift ambiguities and codi$rproceduresand terminology as a means of enhancing efficiency and uniformity in the decommissioningprocess.t4The amendments allow for greater public participation and better define the transition process from operations to decommissioning. Regulatory Guide 1.184, issued in October 2013, further describedthe methods and proceduresthat are acceptableto the NRC staff for implementing the requirements of the 1996 revised rule that relate to the initial activities and the major phasesof the decommissioningprocess. The costs and schedulespresented in this analysis follow the general guidance and sequencein the amendedregulations. The format and content of the estimates is also consistent with the recommendations of Regulatory Guide I.202, issued February 2005.t81 6 Ibid. Page FR24023, Column 2 7 U.S. Codeof Federal Regulations,Title 10, Parts 2,50, and 51, "Decommissioningof Nuclear Power Reactors,"Nuclear Regulatory Commission,Federal RegisterVolume 61, (p 39278et seq.),July 29, 1996 "Standard Format and Content of DecommissioningCost Estimates for Nuclear Power Reactors," RegrrlatoryGuide 1.202,Nuclear Regulatory Commission, February 2005 TLG Services, Inc.

Perry Nuclear Power Plant Document F07-1699-001, Reu. 0 Decommissioning Cost Analysis Page xi of xx DecommissioninsScenarios Two decommissioningscenarios were evaluated for the Perry nuclear unit. The scenariosselectedare representative of alternatives available to the owner and are defined as follows:

1. The first scenario (DECON alternative) assumes that the unit is promptly decommissionedat the end of its operating life. Spent fuel is relocatedto the ISFSI so as to facilitate decontaminationand dismantling activities within the fuel handling building. Spent fuel storage operations continue at the site, independent of decommissioningoperations,until the transfer of the fuel to the DOE is complete,assumedfor purposesof this study to be in the year 2064.At that time, the ISFSI is decommissionedand the site released for alternative use.

2. The unit is placed into safe-storage in the second scenario (SAFSTOR alternative). Decommissioningis deferredbeyondthe fuel storageperiod to the maximum extent permitted by the current regulations. Similar to the DECON alternative, the spent fuel is relocated to the ISFSI for interim storage.Spent fuel storage operations continue at the site until the transfer of the fuel to an appropriate disposal facility is complete,assumedto be in the year 2064. The unit remains in protective storage following the removal of spent fuel from the site. Decommissioningoperations commencesuch that license termination is completedwithin the required 60-year period.

Methodologv The methodology used to develop the estimates follows the basic approach originally presented in the cost estimating guidelines Isl developed by the Atomic Industrial Forum (now Nuclear Energ5rInstitute). This reference describes a unit cost factor method for estimating decommissioningactivity costs. The unit cost factors used in this analysis incorporate site-specificcosts 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 assemblingdecommissioning estimates ensuresa high degreeof confrdencein the reliability of the resulting costs. e T.S. LaGuardia et al., "Guidelinesfor Producing CommercialNuclear Power Plant Decommissioning CostEstimates,"AIF/I.{ESP-036, May 1986 TLG Seruices. Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 Decommissioning Cost Analysis Page xii of xx Contingencv Consistent with cost estimating practice, contingencies are applied to the decontamination and dismantling costs developed as "specific provision for unforeseeableelementsof 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."ttOlThe cost elements in the estimates are based on ideal conditions; therefore, the types of unforeseeableevents 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, does not account for price escalation and inflation in the cost of decommissioningover the remaining operating life of the station. Contingencyfunds are expectedto be fully expendedthroughout the program. As such, inclusion of contingencyis necessaryto provide assurancethat sufficient funding will be available to accomplishthe intended tasks. Low-Level RadioactiveWaste 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 passageof the "Low-Level Radioactive Waste Disposal Act in 1980 and its Amendments of 1985, tttl the states becameultimately responsible for the disposition of low-level radioactive waste generated within their own borders. It was expected that groups of states would combine together to jointly deal with their radioactive wastes;these organizationsare referred to as waste disposalcompacts. Few approved facilities for the disposal of LLW are currently available. Construction of the newest facility, in Texas, is now complete and the facility was declared operational by the operator, Waste Control Specialists @CS), in November 2011. The facility will be able to accept limited quantities of non-Compact waste; however, at this time the cost for non-Compactgeneratorsis being negotiated on an individual basis. Project and Cost Engineers'Handbook, SecondEdition, American Associationof Cost Engineers, Marcel Dekker, Inc., New York, New York, p. 239. l l "Low-Level RadioactiveWaste Policy AmendmentsAct of 1985,"Public Law 99-240,January 15, 1986 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Rev. 0 D ecommissioning Cost Analy sis Page xiii of xx All options and services currently available to FirstEnergy for disposition of the various waste streams producedby the decommissioningprocesswere considered. The majority of the low-level radioactivewaste designatedfor direct disposal (Class A t12l)can be sent to EnergySolutions'facility in Clive, Utah. Therefore, disposal costsfor ClassA waste were based upon FirstEnergy's Life of Plant Agreemenfwith EnergySolutions.This facility is not licensed to receive the higher activity portion (ClassesB and C) of the decommissioning waste stream. The Texas facility is licensed to receivethe higher activity waste forms (ClassesB and C). As such, for this analysis, disposal costs for the Class B and C waste were based upon the preliminary and indicative information on the cost for such from W C S. The dismantling of the components residing closest to the reactor core generates radioactive waste that may be consideredunsuitable for shallow-Iand disposal (i.e., low-level radioactive waste with concentrations of radionuclides that exceed the limits establishedby the NRC for Class C radioactive waste, or greater than Class C (GTCC)). The Low-Level Radioactive Waste Policy Amendments Act of 1985 assignedthe federal government the responsibility for the disposalof this material. The Act also stated that the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonablecosts of disposing of such waste. However, to date, the federal government has not identified a cost for disposingof GTCC or a schedulefor 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 packagedin the same canisters used for spent fuel and either stored on site or shipped directly to a disposal facility as it is generated (depending upon the timing of the decommissioningand whether the spent fuel has been removed from the site prior to the start of decommissioning). A significant portion of the waste material generated during decommissioningmay only be potentially contaminated by radioactive materials. This waste can be analyzed on site or shipped off site to licensed facilities for further analysis, processing and/or conditioning/recovery. Reduction in the volume of low-Ievel radioactive waste requiring disposal in a licensed low-level radioactive waste disposal facility can be accomplished through a variety of methods, including analysesand surveys or decontaminationto eliminate the portion of waste that does not require disposal as radioactive waste, compaction, incineration or metal melt. The estimates reflect the savings from waste recovery/volumereduction. rz Waste is classifiedin accordancewith U.S. Codeof Federal Regulations,Titie I0, Patt 67.55 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F0 7-I 6I g-001, Reu. 0 D ecom.missioning Cost Analy sis Page xiu of xx Material removed during decommissioningthat is less than the site release criteria will be designatedfor conventionaldisposalor reuse / recovery. Hieh-Level RadioactiveWaste Manaeement Congresspassedthe "Nuclear Waste Policy Acf"[13](NWPA) in 1982, assigning the federal government'slong-standing responsibility for disposalof the spent nuclear fuel createdby the commercialnuclear generatingplants 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 servicesfor that material. NWPA, along with the individual contracts with the utilities, specifiedthat 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. Delays continue and, as a result, generatorshave initiated legal action against the DOE in an attempt to obtain compensationfor DOE's partial breach of contract. To date no spent fuel has been acceptedfrom commercial generating sites for disposal. The NRC's review of DOE's license application to construct a geologicrepository at Yucca Mountain was suspended in 2011 when the Administration slashed the budget for completing that work. However, the US Court of Appeals for the District of Columbia Circuit issued a writ of mandamus (in August 2013) [1a]ordering NRC to comply with federal law and restart its review of DOE's Yucca Mountain repository license application to the extent of previously appropriated funding for the review. That review is now underway. The current schedulecalls for completion and publication of the safety evaluation report by January 2015. The adjudicatory hearing, which must be completedbefore a licensing decisioncan be made, remains suspended. In 2010 the administration appointed a Blue Ribbon Commission on America's Nuclear Future (Blue Ribbon Commission) to make recommendationsfor a new 13 "Nuclear Waste Policy Act of 1982and Amendments,"DOE's Offrceof Civilian Radioactive Management,1982 l4 United States Court of Appeals for the District Of Columbia Circuit, In Re: Aiken County, et al, August 2013 http:i/www.cadc.uscourts.eov/internet/opinions.nsf/BAE0CF34F762EBD9B52578C6004DEB 18/$file/1 1-1271-1451347.pdf TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecomntissio n ing Cost An aly si s Page xu of xx plan for nuclear waste disposal.The Blue Ribbon Commission'scharter includes a requirement that it consider "[o]ptions for safe storage of used nuclear fuel while final disposition pathways are selectedand deployed."[1ri On January 26, 20L2, the Blue Ribbon Commission issued its "Report to the Secretary of Energy" containing a number of recommendationson nuclear waste disposal.Two of the recommendationsthat may impact decommissioningplanning are: o "[T]he United States [should] establish a program that leads to the timely developmentof one or more consolidatedstoragefacilities"[16]

    . "[T]he United States should undertake an integrated nuclear waste managementprogram that leads to the timely developmentof one or more permanent deep geologicalfacilities for the safe disposal of spent fuel and high-level nuclearslasf,s."[171 In January 2013, the DOE issuedthe "StrategS'forthe Managementand Disposal of Used Nuclear Fuel and High-Level Radioactive Waste," in response to the recommendationsmade by the Blue Ribbon Commission and as "a framework for moving toward a sustainable program to deploy an integrated system capable of transporting, storing, and disposingof used nuclear fqel..."[l8]This documentstates:

"With the appropriate authorizations from Congress,the Administration currently plans to implement a program over the next 10 years that: o Sites, designs and licenses, constructs and begins operations of a pilot interim storage facility by 2021 with an initial focus on accepting used nuclear fuel from shut-down reactor sites; o Advances toward the siting and licensing of a larger interim storage facility to be available by 2025 that will have sufficient capacity to provide flexibility in the waste management system and allows for acceptanceof enough used nuclear fuel to reduce expectedgovernmentliabilities; and 15 Ibid. 16 "Blue Ribbon Commission on America's Nuclear Future, Report to the Secretary of Energy," gov/,p. 32,January 2012 http ://wr.vw.brc. L7 Ibid., p.27 18 "Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste."U.S. DOE. Januarv 11. 2013 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07- I 69900 1, Reu. 0 Decommissioning Cost Analysis Page xui of xx

    . Makes demonstrable progress on the siting and characterization of repository sites to facilitate the availability of a geologic repository by 204g.Dtrel FirstEnergy'scurrent spent fuel managementplan for the Perry spent fuel is basedin generalupon:

1) Fuel transferred from the pool to the ISFSI within 7 years of final shutdown;

2) Fuel will be shipped in the Holtec International dry shielded storage canisters(MPCs), and

3) Availability of a DOE storage repository by 2O25. First shipment of fuel from the Perrv site occursin 2034.

Completion of the Perry decommissioningprocess is dependent upon the DOE's ability to remove spent fuel from the site in a timely manner. DOE's repository program assumesthat spent fuel allocations will be acceptedfor disposal from the nation's commercial nuclear plants, with limited exceptions, in the order (the "queue")in which it was dischargedfrom the reactol.tzoll'ilsfEnergy's current spent fuel management plan for Perry spent fuel assumed in this estimate is based in general upon: l) a 2025 start date for DOE initiating transfer of commercial spent fuel to a federal facility (not necessarily a final repository), and 2) expectationsfor spent fuel receipt by the DOE for the Perry fuel. The DOE's generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. Assuming a maximum rate of transfer of 3,000 metric tons of uranium (MTl)/year,[2rl 16" removal of spent fuel from the site is completedin 2064.Different DOE acceptanceschedulesresult in different completion dates. 19 Ibid., p.2 20 In 2008,the DOE issued a report to Congressin which it concludedthat it did not have authority, under present law, to acceptspent nuclear fuel for interim storagefrom decommissionedcommercial nuclear power reactor sites.However,the Blue Ribbon Commission, in its final report, noted that:

   "[A]ccepting spent fuel according to the OFF [Oldest Fuel First] priority ranking instead of giving priority to shutdown reactor sites could greatly reduce the cost savings that could be achieved through consolidatedstorage ifpriority could be given to accepting spent fuel from shutdown reactor sites beforeacceptingfuel from still-operating plants. .... The magnitude of the cost savings that could be achieved by giving priority to shutdown sites appears to be large enough (i.e., in the billions of dollars) to warrant DOE exercising its right under the Standard Contract to move this fuel first."

2r "AcceptancePriority Ranking & Annual Capacity Report," DOEIRW-0567,July 2004 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001, Reu. 0 D ecomm.i ssioning Cost Analy si s Page xuii of xx The NRC requires that licenseesestablish a program to manage and providefunding for the caretaking of all irradiated fuel at the reactor site until title of the fuel is transferred to the Secretaryof Energy, pursuant to 10 CFR Part 50.54@b).t2zl This requirement is prepared for through inclusion of certain cost elements in the decommissioningestimates,for example,associatedwith the isolation and continued operationof the spentfuel pool and the ISFSI. The spent fuel pool is expectedto contain freshly dischargedassemblies(from the most recent refueling cycles) as well as the final reactor core at shutdown. Over the following seven years, the assembliesare packagedinto MPCs for transfer to the ISFSI for interim storage.It is assumedthat this period providesthe necessarycooling for the final core to meet the storagerequirements for decayheat. An ISFSI, operatedunder a Part 50 General License (in accordancewith 10 CFR 72, Subpart Kt23l),has been constructedto support continued plant operations.The facility is assumed to be expanded to support decommissioning. This wilI allow decommissioningactivities to proceedwithin the fuel handling building. FirstEnergy's position is that the DOE has a contractual obligation to acceptPerry's fuel earlier than the projections set out above consistent with its contract commitments. No assumption made in this study should be interpreted to be inconsistent with this claim. However, including the cost of storing spent fuel in this study is appropriate to ensure the availability of suffi.cient decommissioningfunds at the end of the station's life if the DOE has not met its obligation. 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 unreasonableto 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 processis deferred. This estimate assumes that some site features will remain following the decommissioningproject. These include the existing electrical switchyard, which is U.S. Codeof Federal Regulations,Title 10,Part 50, "DomesticLicensing of Productionand Utilization Facilities," Subpart 54 (bb),"Conditions of Licenses" U.S. Codeof Federal Regulations,Title 10, Part 72, Subpart K, "General Licensefor Storageof Spent FueI at Power ReactorSites." TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommissioning Cost Analy sis Page xuiii of xx assumed to remain functional in support of the regional electrical distribution system. The existing shoreline,canals and ponds will also be left intact. Consequently,this study assumesthat non-essentialsite structures addressedby this analysis are removed to a nominal depth of three feet below the local grade level wherever possible.The site is then graded and stabilized. Summary The estimates to decommissionPerry assumethe removal of all contaminated and activated plant componentsand 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 commercialprocessorfor treatment/conditioning or to a controlled disposalfacility. Decommissioningis accomplishedwithin 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 an appropriate disposal facility is complete. Once emptied, the storagefacility can also be decommissioned. The alternatives evaluated in this analysis are described in Section 2. The assumptionsare presentedin Section3, along with schedulesof annual expenditures. The major cost contributors are identified in Section 6, with detailed activity costs, waste volumes,and associatedmanpowerrequirementsdelineatedin AppendicesC, D and E. The major cost componentsare also identified in the cost summary provided at the end of this section. As noted within this document, the estimates were developedand costs are presented in 2014 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 decommissioningperiod. TLG Seruices, Inc.

Perry Nuclear Pouer Plant Document F07-I 699-001, Reu, 0 D ecommissioning Cost Analysis Page xix of xx DECONDECOMMISSIONINGCOSTNLEMANTS (thousands of $2014) ent Fuel Pool 12.434 ent Fuel Ma msnf [21 Insurance and Re Fees Ene Characterization and Lic-elqi_Ug*$lltyg Taxes MiscellaneousEquipment Cost Element LicenseTermination 877,925 Spent Fuel Management 423.356 Site Restoration 88,772 fefal tal 1,390,053 tll Includes engineering costs I2l Excludesprogram managementcosts(staf6.ng)but includes costsfor spent fuel loading/transfer/spentfuel pool O&M and EP fees t31 Columns or rows may not add due to rounding TLG Seruices. Inc.

Perry Nuclear Power Plant Docutnent F07- 1699-001, Rev. 0 D ecornmissioning Cost An alysis Page xx of xx SAFSTORDECOMMISSIONINGCOSTELEMENTS (thousands of $2014) ilFX I CostElement I Total il

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                                                            --"*,. - .* *- j --- - ?Eq,gql i Securrtv                                                                      i       ?3prle_-q nt Fuel Pool Isqlation                                                          !2_,!?1 nt Fuel Manasemsnf [zl                                                         222.605 Insurance and Resulatorv Fees                                                        85.077 Energy                                                                               40.527 Characterization and Licensing Surveys                                               29,338 P1ope,r,ty, Taxes                                                                    150,807 MiscellaneousEquipment                                                                29.289 Qqqp-grate_ -G&A                                                                     63,644 Total tsl                                                                          r,660,404 Cost Element LicenseTermination                                                              1.054.131 Spent Fuel Management                                                             514,538 Site Restoration                                                                    91,735 Total t31                                                                       1.660.404 tu Includes engineering costs l2l Excludesprogram managementcosts(staffing) but includescostsfor spent fuel loading/transfer/spentfuel pool O&M and EP fees t31 Columns or rows may not add due to rounfing TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecom.missio n in g Cost Analy sis Section 1, Page 1 of 10

1. INTRODUCTION This report presents estimatesof the cost to decommissionthe Perry Nuclear Power Plant (Perry) for the selected decommissioning scenarios following the scheduled cessation of plant operations. The analysis relies upon site-specific, technical information from an evaluationprepared in 2010,t11. revisedin 2Al4 to reflect changes in the spent fuel scenario and security levels, and now updated to reflect current assumptions pertaining to the disposition of the nuclear unit and relevant industry experience in undertaking such projects. The current estimates are designedto provide the FirstEnerry Corp. with the information to assess its current decommissioningliability, as it relates to Perry.

The analysis relies upon site-specific, technical information compiled by TLG from information provided by FirstEnergy. The analysis reflects current assumptions pertaining to the disposition of nuclear power plants and relevant industry experience in undertaking such projects.The costs are basedon several key assumptionsin areas of regulation, component characterization, high-Ievel radioactive waste management, low-level radioactive waste disposal, performance uncertainties (contingency)and site restorationrequirements. The analysis is not a detailed engineering evaluation, but estimates prepared in advanceof the detailed engineering required to carry out the decommissioningof the nuclear unit. It may also not reflect the actual plan to decommissionPerry; the plan may differ from the assumptionsmade 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 Perry, to provide a sequence or schedule for the associated activities, and to develop waste stream projections from the decontaminationand dismantling activities. The operating license for the nuclear unit was issued on March 18, 1986. For purposes of this analysis, Perry is assumed to ceaseoperations on March 18, 2026, after approximately 40 years of operations. L.2 SITE DESCRIPTION The Perry site is located approximately 35 miles northeast of Cleveland,Ohio, on the southern shore of Lake Erie. Although the station is comprisedof two References provided in Section 7 of the document TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001, Rev. 0 D ecommi ssioning Cost An aly si s Section 7,Page 2 of 10 nuclear units, only Unit 1 is currently in operation and consideredwithin the scopeof this costestimate.Figure 1.1 showsthe Perry site environs. The nuclear steam supply system (NSSS) includes a single cycle, forced circulation, General Electric boiling water reactor producing steam for direct use in the steam turbine. The rated core thermal output was increasedin year 2000 from 3579megawatts(thermal) to 3758 megawatts,this correspondsto a net design electrical rating of 1268 MWe (megawatts-electric)with the reactor at rated power. The NSSS is within a pressure-suppressioncontainment which houses the reactor vessel, the recirculation loops, and branch connectionsof the reactor primary system. The containment system consists of a drywell that encloses the reactor pressure vessel, the reactor recirculation loops and pumps, and other branch connections of the reactor primary system. The drywell is a cylindrical reinforced concretestructure with a removable steel head.Also part of the containment system is the suppressionpool, containing a large amount of water used to rapidly condensesteam from a reactor vessel blowdown or from a break in a major pipe. The third part of the containment system is the leak-tight containment vessel surrounding the drywell and the suppression pool. The containment vessel is a cylindrical steel structure with a dome top and flat bottom supported by a reinforced concretefoundation mat. The shield building is a cylindrical concrete structure enclosing the containment vessel, providing shielding from direct radiation under normal and accident conditions, and also providing missile protection for the containment vessel. Figure 1.2 is an excerpt from the Perry UFSAR, showing a Containment Vessel section view. The unit utilizes a power conversion system, including a turbine-generator, a main condenser,air ejector and turbine steam packing exhausting condensers, condensate filter-demineralizers, and a feedwater system. The power conversion system produces electrical power from the energy of the steam coming from the reactor, condensesthe steam into water, and returns the feedwater to the reactor. The heat rejected to the main condenseris removed by the circulating water system. The turbine is a General Electric tandem compound,six-flow, reheat, 1800rpm unit, consisting of one double-flow high pressure turbine and three double-flow low pressure turbines. Exhaust steam from the high-pressure turbine passes through moisture separator/reheatersbefore entering the three low-pressure turbines. Reheated steam is also supplied to two reactor feed pump drive turbines. Turbine steam is also extracted for six stagesof feedwaterheating. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 Decommissioning CostAnalysis Sectinn 1, Page 3 of 10 1.3 REGULATORY GUIDANCE The Nuclear Regulatory Commission (NRC or Commission) provided initial decommissioning requirements in its rule "General Requirements for Decommissioning Nuclear Facilities,"issuedin June 1988.t21This rule set forth financial criteria for decommissioninglicensed 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 decommissioningwould be accomplishedin a safe and timely manner and that adequate funds would be available for this purpose. Subsequentto the rule, the NRC issuedRegulatoryGuide 1.159,"Assuringthe Availability of Funds for Decommissioning Nuclear Reactors,"[31which 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 assurancemechanismsindicated in the rule. The rule defined three decommissioningalternatives as being acceptableto 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 decontaminatedto levels that permit the site to be releasedfor unrestricted use shortly after the cessationofplant operations, while the SAFSTORand ENTOMB alternatives defer the process. The rule also placed limits on the time allowed to complete the decommissioningprocess. For all alternatives, the process is restricted in overall duration to 60 years, unless it can be shown that a longer duration is necessaryto protect public health and safety. At the conclusionof 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 releaselimits for licensetermination. 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,tal the NRC did re-evaluate the 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 neededbefore this option could be treated as a generic alternative. TLG Seruices. Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. A D ecornmi ssioning Cost An aly si s Section 1, Page 4 of 10 The NRC had consideredrulemaking to alter the 60-year time for completing decommissioningand to clarify the use of engineered barriers for reactor entombmenfs.tsl However,the NRC'sstaff has subsequentlyrecommendedthat rulemaking be deferred, based upon several factors (e.g., no licensee has committed to pursuing the entombment option, the unresolved issues associatedwith 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 plants.t6l When the decommissioning regulations were adopted in 1988, it was assumed that the majority of licenseeswould decommissionat the end of the facility's operating licensedlife. Since that time, several licenseeshad permanently and prematurely ceased operations. Exemptions from certain operating requirements were required oncethe reactor was defueledto facilitate the decommissioning.Each casewas handled individually, without clearly defined generic requirements. The NRC amended the decommissioningregulations in 1996 to clarifii ambiguities and codifi' procedures and terminology as a means of enhancing efficiency and uniformity in the decommissioningprocess.The amendments allow for greater public participation and better define the transition processfrom operations to decommissioning. Under the revised regulations, licenseeswill 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 licenseeto 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 describesthe planned decommissioningactivities, the associatedsequenceand schedule, and an estimate of expected costs. Prior to completing decommissioning,the licenseeis required to submit an application to the NRC to terminate the license,which includes a licensetermination plan (LTP). In 2011,the NRC published amendedregulationsto improve decommissioning planning and thereby reduce the likelihood that any current operating facility will become a legacy site.lzt The amended regulations require licensees to conduct their operations to minimrze the introduction of residual radioactivity into the site, which includes the site's subsurface soil and groundwater. Licenseesalso may be required to perform site surveys to determine whether residual radioactivity is present in subsurfaceareas and to keep records of TLG Seruices. Inc.

Perry Nuclear Power Plant Docum.entF07-1699-001,Reu. 0 D ecomrnission ing Cost An aly si s Section 1, Page 5 of 10 these surveys with records important for decommissioning.The amended regulations require licensees to report additional details in their decommissioning cost estimate as well as requiring additional financial reporting and assurances. These additional details, including the ISFSI decommissioningestimate, are included in this analysis. 1.3.1 Hieh Level Waste Congress passed the "Nuclear Waste Policy Acf,"[81(NWPA) in 1982, assigning the federal government's long-standing responsibility for disposal of the spent nuclear fuel created by the commercial nuclear generatingplants to the DOE. The NWPA providedthat 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 servicesfor that material. NWPA, along with the individual contracts with the utilities, specifiedthat the DOE was to begrn acceptingspent fuel by January 31, 1998. Since the original legislation, the DOE has announcedseveral 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. Delays continue and, as a result, generatorshave initiated legal action against the DOE in an attempt to obtain compensationfor DOE's partial breach of contract. To date no spent fuel has been acceptedfrom commercial generating sites for disposal. The NRC's review of DOE's license application to construct a geologic repository at Yucca Mountain was suspended in 20tL when the Administration slashedthe budget for completing that work. However, the US Court of Appeals for the District of Columbia Circuit issued a writ of mandamus (in August 2013) [e]ordering NRC to comply with federal law and restart its review of DOE's Yucca Mountain repository license application to the extent of previously appropriated funding for the review. That review is now underway. The current schedule calls for completion and publication of the safety evaluation report by January 2015. The adjudicatory hearing, which must be completedbefore a licensing decision can be made,remains suspended. In 2010 the administration appointed a Blue Ribbon Commission on America's Nuclear Future (Blue Ribbon Commission) to make recommendationsfor a new plan for nuclear waste disposal. The Blue Ribbon Commission'scharter includes a requirement that it consider

            "[o]ptions for safe storage of used nuclear fuel while final disposition pathways are selectedand deployed."ttol TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07- I 699-001, Reu. 0 D ecommissioning Cost Analy sis Section 7, Page 6 of 10 On January 26, 2012, the Blue Ribbon Commissionissued its "Report to the Secretary of Energ;t" containing a number of recommendationson nuclear waste disposal. TWo of the recommendationsthat may impact decommissioning planning are: o "[T]he United States [should]establisha program that leadsto the timely developmentof one or more consolidatedstoragefacilities"

               .    "[T]he United States should undertake an integrated nuclear waste managementprogram that leadsto the timely development of one or more permanent deep geologicalfacilities for the safe disposalof spent fuel and high-levelnuclearr61asf,s."[111 In January 2013,the DOE issued the "Strategy for the Managementand Disposal of Used Nuclear Fuel and High-Level Radioactive Waste," in responseto the recommendationsmade by the Blue Ribbon Commission and as "a framework for moving toward a sustainable program to deploy an integrated system capable of transporting, storing, and disposing of used nuclear fuel..."[121This documentstates:
           "With the appropriate authorizations from Congress,the Administration currently plans to implement a program over the next 10 years that:

Sites, designs and licenses,constructs and begins operations of a pilot interim storage facility by 202L with an initial focus on acceptingused nuclear fuel from shut-down reactor sites; Advances toward the siting and licensing of a larger interim storage facility to be available by 2025 that will have sufflrcient capacity to provide flexibility in the waste management system and allows for acceptanceof enough used nuclear fuel to reduce expectedgovernment liabilities; and Makes demonstrableprogresson the siting and characterization of repository sites to facilitate the availability of a geologicrepository by 2048;' FirstEnerry's current spent fuel managementplan for the Perry spent fuel is basedin generalupon:

1) Fuel transferred from the pool to the ISFSI within 7 years of final shutdown;

2) Fuel will be shipped in the Holtec International multi-pu{pose storagecanisters(A4PCs),and TLG Seruices, Inc.

Perry Nuclear Power Plant Docurnent F07-1699001,Reu. 0 D ecom.ntission ing Cost Analy sis Section 7, Page 7 of 10

3) Availability of a DOE storage repository by 2025. First shipment of fuel from the Perry site occursin 2034.

Completionof the Perry decommissioningprocessis dependentupon the DOE's ability to removespent fuel from the site in a timely manner.DOE's repository progyamassumesthat spent fuel allocations will be acceptedfor disposal from the nation's commercial nuclear plants, with limited exceptions,in the order (the "queue") in which it was dischargedfrom the reactor. FirstEnergSt'scurrent spent fuel managementplan for Perry spent fuel assumedin this estimate is basedin generalupon: l) a2025 start date for DOE initiating transfer of commercial spent fuel to a federal facility (not necessarily a frnal repository), and 2) expectations for spent fuel receipt by the DOE for the Perry fuel. The DOE's generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. Assuming a maximum rate of transfer of 3,000 metric tons of uranium (MTt)/year,[13] 1h" removal of spent fuel from the site is completedin 2064. Different DOE acceptanceschedulesresult in different completiondates. The NRC requires that licensees establish a program to manage and provide funding for the caretaking of all irradiated fuel at the reactor site until title of the fuel is transferred to the Secretary of Energ;r,pursuant to 10 CFR Part 50.54@b).t141 This requirement is prepared for through inclusion of certain cost elements in the decommissioningestimates, for example, associatedwith the isolation and continued operation of the spent fuel pool and the ISFSI. The spent fuel pool is expected to contain freshly discharged assemblies (from the most recent refueling cycles)as well as the final reactor coresat shutdown. Over the following seven years, the assemblies are packaged into dry shielded storage canisters for transfer to the ISFSI for interim storage.It is assumedthat this period provides the necessarycoolingfor the final coresto meet the storagerequirements for decayheat. An ISFSI, operated under a Part 50 General License (in accordancewith 10 CFR 72, Subpart Ktl5l),has beenconstructedto support continuedplant operations. The facility is assumed to be expanded to support decommissioning.This will allow decommissioning activities to proceed within the fuel handling building. FirstEnerry's position is that the DOE has a contractual obligation to accept Perry's fuel earlier than the projections set out above consistent with its contract commitments. No assumptionmade in this study should be interpreted to be inconsistentwith this claim. However, including the TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommissioning Cost Analy sis Section 7,Page I of 10 cost of storing spent fuel in this study is appropriate to ensure the availability of sufficient decommissioningfunds at the end of the station's life if the DOE has not met its obligation. 1.3.2 Low-LevelRadioactiveWaste 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 passageof the "Low-Level Radioactive Waste Policy Act" in 1980,t161and its Amendments of 1985,t171 the states became ultimately responsiblefor the dispositionof low-level radioactive waste generatedwithin their own borders. It was expectedthat groups of states would combinetogether to jointly deal with their radioactive wastes; these organizations are referred to as waste disposalcompacts. Few approvedfacilities for the disposal of LLW are currently available. Construction of the newest facility, in Texas, is now complete and the facility was declared operational by the operator, Waste Control Specialists (WCS),in November 2011. The facility will be able to accept limited quantities of non-Compactwaste; however, at this time the cost for non-Compactgeneratorsis being negotiatedon an individual basis. AII options and services currently available to FirstEnerg5r for disposition of the various waste streams produced by the decommissioningprocesswere considered.The majority of the low-level radioactive waste designatedfor direct disposal (ClassA t181) can be sent to Energ;'Solutions'facility in Clive, Utah. FirstEnergy provided the disposal rates for Class A waste disposal at EnerrySolutions. T}nis facility is not licensed to receive the higher activity portion (ClassesB and C) of the waste stream. The Texas facility is licensed to receive the higher activity waste forms (ClassesB and C). As such, for this analysis, disposal costsfor the Class B and C waste were based upon the preliminary and indicative information on the cost for such from WCS. The dismantling of the componentsresiding closest to the reactor core generates radioactive waste that may be considered unsuitable for shallow-land disposal (i.e., low-level radioactive waste with concentrationsof radionuclides that exceedthe limits establishedby the NRC for Class C radioactive waste, or greater than Class C (GTCC)). The Low-Level Radioactive Waste Policv Amendments Act of 1985 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommi ssioning Cost An aly si s Section 1, Page 9 of 10 assignedthe federal government the responsibility for the disposal of this material. The Act also stated that the beneficiariesof the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste. However, to date, the federal governmenthas not identified a cost for disposingof GTCC or a schedule for acceptance. For purposesof this analysis, the GTCC radioactive waste is assumedto be packagedand disposedof in a similar manner as high-level waste and at a cost equivalent to that envisioned for the spent fuel. The GTCC is packagedin the same canisters used for spent fuel and either stored on site or shipped directly to a disposal facility as it is generated (depending upon the timing of the decommissioningand whether the spent fuel has been removed from the site prior to the start of decommissioning). A significant portion of the waste material generated during decommissioningmay only be potentially contaminated by radioactive materials. This waste can be analyzed on site or shipped off site to licensed facilities for further analysis, processing andlor conditioning/recovery.Reduction in the volume of low-level radioactive waste requiring disposal in a licensed low-level radioactive waste disposal facility can be accomplished through a variety of methods, including analyses and surveys or decontamination to eliminate the portion of waste that does not require disposal as radioactive waste, compaction, incineration or metal melt. The estimates reflect the savingsfrom waste recovery/volumereduction. 1.3.3 RadioloeicalCriteria for LicenseTermination In L997, the NRC published Subpart E, "Radiological Criteria for License Termination,"[1e]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 releasedfor unrestricted use if radioactivity levels are such that the averagemember of a critical group would not receive a Total Effective Dose Equivalent (TEDE) in excessof 25 millirem per year, and provided that residual radioactivity has been reduced to levels that are As Low As ReasonablyAchievable (AI"ARA). The decommissioning estimates assume that the Perry site will be remediated to a residual level consistentwith the NRC-prescribedlevel. It should be noted that the NRC and the Environmental Protection Agency (EPA) differ on the amount of residual radioactivity considered acceptablein site remediation. The EPA has two limits that apply to TLG Seruices. Inc.

Perry Nuclear Power Plant Docum.ent F07-1699-001,Reu. 0 D ecommissioning Cost Analysis Section 7, Page 10 of 10 radioactive materials. An EPA limit of 15 millirem per year is derived from criteria established by the Comprehensive Environmental Response,Compensation,and Liability Act (CERCI"A or Superfund).tzoJ An additional and separatelimit of 4 millirem per year, as defined in 40 CFR Part L4I.L6, is applied to drinking water.l2U On October 9, 2002, the NRC signed an agreementwith the EPA on the radiological decommissioning and decontamination of NRC-licensed sites. The Memorandum of Understanding (MOU)1221 provides that EPA will defer exercise of authority under CERCI"A for the majority of facilities decommissionedunder 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 licenseesand should reduce the involvement of the EPA with NRC Iicenseeswho are decommissioning.Most sites are expectedto meet the NRC criteria for unrestricted use, and the NRC believes that only a few sites will have groundwater or soil contamination in excessof the levels specifiedin 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.

Perry Nuclear Power Plant Document F07- I 699-001, Reu. 0 Decornrnissioning Cost Analy sis Section 2, Page 1 of 13

2. DECOMMISSIONING ALTERNATIVES Detailed cost estimates were developedto decommissionPerry based upon the approved decommissioning alternatives: DECON and SAFSTOR. Although the alternatives differ with respectto technique, process,cost,and schedule,they attain the same result: the ultimate releaseof the site for unrestricted use.

Two decommissioning scenarios were evaluated for the Perry nuclear unit. The scenariosselectedare representativeof alternatives available to the owner and are defined as follows:

1. The first scenario (DECON alternative) assumes that the unit is promptly decommissionedat the end of its operating life. Spent fuel is relocated to the ISFSI so as to facilitate decontaminationand dismantling activities within the fuel handling building. Spent fuel storage operations continue at the site, independent of decommissioningoperations,until the transfer of the fuel to the DOE is complete,assumedfor purposesof this study to be in the year 2064.At that time, the ISFSI is decommissionedand the site released for alternative use.

2. The unit is placed into safe-storage in the second scenario (SAFSTOR alternative). Similar to the DECON alternative, the spent is relocated to the ISFSI for interim storage. Spent fuel storage operations continue at the site until the transfer of the fuel to an appropriate disposal facility is complete, assumed to be in the yeat 2064. The unit remains in protective storage following the removal of spent fuel from the site, with decommissioning deferred beyond the fuel storage period to the maximum extent permitted by the current regulations. Decommissioning operations commence such that licensetermination is completedwithin the required 60-yearperiod.

The following sectionsdescribethe basic activities associatedwith each alternative. Although detailed proceduresfor each activity identified are not provided, and the actual sequenceof work may vary, the activity descriptionsprovide a basis not only for estimating but also for the expectedscopeof work, i.e., engineering and planning at the time of decommissioning. The conceptual approach that the NRC has described in its regulations divides decommissioninginto three phases. The initial phase commenceswith the effective date of permanent cessationof operations and involves the transition of both plant and licenseefrom reactor operations (i.e., power production) to facility de-activation and closure. During the first phase, notification is to be provided to the NRC TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecomtnissioning Cost Analysis Section 2, Page 2 of 13 certifying the permanent cessationof operations and the removal of fuel from the reactorvessel. The licenseeis then prohibited from reactoroperation. The secondphase encompassesactivities during the storageperiod or during major decommissioningactivities, or a combination of the two. The third phase pertains to the activities involved in license termination. The decommissioningestimates developedfor Perry are also divided into phasesor periods;however, demarcationof the phasesis based upon major milestoneswithin the project or significant changes in the projectedexpenditures. 2 . I D E C ON The DECON alternative, as defined by the NRC, is "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 releasedfor unrestricted use shortly after cessation of operations." This study doesnot addressthe cost to disposeof 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 to an off-site disposal facility. 2.I.I 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 staffi.ng transition plan, the organization required to manage the intended decommissioningactivities is assembledfrom 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 developmentof the PSDAR. Engineering and Plannine The PSDAR, required prior to or within two years of permanent cessationof operations, provides a description of the licensee'splanned decommissioning activities, a timetable, and the associated financial requirements of the intended decommissioningprogram. 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. TLG Services, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommi ssioning Cost An aly si s Section 2, Page 3 of 13 Ninety days following submittal and NRC receipt of the PSDAR, the licenseemay begin to perform major decommissioningactivities under a modified 10 CFR Part 50.59 procedure(10 CFR Part 50.59 establishes the conditionsunder which licenseesmay make changesto the facility or procedures and conduct test or experiments without prior 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 Part

61. Major components are further defined as comprising the reactor vesseland internals, large bore reactor recirculation system piping, and other large components that are radioactive. The NRC includes the following additional criteria for use of the modified Part 50.59processin decommissioning.The proposedactivity must not:

foreclosereleaseof the site for possibleunrestricted use, significantly increase decommissioning costs, causeany significant environmental impact, or violate the terms of the licensee'sexisting license Existing operational technical specificationsare reviewed and modified to reflect plant conditions and the safety concerns associated with permanent cessationof operations.The environmental impact associated with the planned decommissioning activities is also considered. Typically, a licenseewill not be allowed to proceedif the consequences of a particular decommissioningactivity are greater than that boundedby previously evaluated environmental assessmentsor impact statements. In this instance, the licenseewould have to submit a licenseamendment for the specificactivity and update the environmental report. The decommissioningprogram outlined in the PSDAR will be designed to accomplish the required tasks within the ALARA guidelines (as defined in 10 CFR Part 20) for protection of personnel from exposureto 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-benefi.tand safety analyses, work packages,and procedureswould be assembledto support the proposed decontaminationand dismantling activities. TLG Seruices, Inc.

Perry Nuclear Power Plant Docurnent F07-1699-001, Reu. 0 D ecorntnission ing Cost An aly sis Section 2, Page 4 of 13 Site Preparations Following fi"nal plant shutdown, and in preparation for actual decommissioningactivities, the following activities are initiated: o Characterization of the site and surrounding environs. This includes radiation surveys of work areas, major components (including the reactor vesseland its internals), internal piping, and primary shield cores.

               . Isolation of the spent fuel storage pool and fuel handling systems, such that decommissioningoperations can commence on the balance of the plant. The pool will remain operationalfor approximately seven years following the cessationof the unit's 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.

o Development of procedures for occupational exposure control, control and release ofliquid and gaseouseffluent, processingof radwaste (including dry-active waste, resins, fiIter media, metallic and non-metallic components generated in decommissioning),site security and emergency programs, and industrial safety.

               . Perform chemical decontamination of the NSSS to reduce radiation levels in support of removal operations.

2.1.2 Period 2 - DecommissionineOperations This period includes the physical decommissioningactivities associated with the removal and disposal of contaminated and activated componentsand structures, including the successfulrelease of the site from the 10 CFR Part 50 operating license, exclusive of the ISFSI. Significant decommissioningactivities 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. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecomm issioning Cost An aly si s Section 2, Page 5 of 13 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 accessof large/heavy equipment. Modifications will also be required to the refueling area of the reactor building to support the segmentationof the reactor vesselinternals and componentextraction. 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. Procurement (lease or purchase) of shipping canisters, cask liners, and industrial packages for the transportation and disposal of low-level radioactive wastes generated during decommissioning. Decontamination of componentsand piping systemsas required to control (minimize) worker exposure. Removal of piping and components no longer essential to support decommissioningoperations. Transfer of the steam separator and dryer assembliesto the dryer-separator pool for segmentation. Segmentationby weight and activity maximizes the loading of the shielded transport casks. The operations are conducted under water using remotely operatedtooling and contamination controls. Disconnection of the control blades from the drives on the vessel lower head. Blades are transferred to the drver-separator pool for packaging. Disassembly, segmentation, and packaging of the core shroud and in-core guide tubes. Some of the material is expected to exceedClass C disposal requirements. As such, those segments are packaged in a modified fuel storage canister for geologic disposal. Removal and segmentationof the remaining internals including the jet pump assemblies,orificed fuel supports, and core plate assembly. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommissioning Cost An aly si s Section 2, Page 6 of 13 Draining and decontamination of the reactor well and the permanent sealing of the spent fuel transfer gate. Install a shielded platform for segmentation of the reactor vessel. Cutting operations are performed in air using remotely operated equipment within a contamination control envelope, with the water level maintained just below the cut to minimize the working area dose rates. Sections are transferred to the dryer-separatorpool for packaging and interim storage. Disconnection of the control rod drives and instrumentation tubes from reactor vessel lower head. The lower reactor head and vesselsupporting structure are then segmented. Removal of the reactor recirculation pumps. Exterior surfaces are decontaminated and openings covered. Components can serve as their own burial containers provided that all penetrationsare properly sealed. Demolition of the primary shield activated concrete by controlled demolition. Transfer of the spent fuel from the storage pool to the ISFSI pad for interim storage. Spent fuel storage operations continue throughout the active decommissioningperiod. At least two years prior to the anticipated date of license termination, a license termination plan (LTP) is required. Submitted as a supplement to the UFSAR or its equivalent, the plan must include: a site characterization, description of the remaining dismantling activities, plans for site remediation, procedures for the fi.nal 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 approval will be subject to any conditions and limitations as deemed appropriate by the Commission.The licenseemay then commencewith the final remediation of site facilities and services,including: Removal of remaining plant systems and associated components as they become nonessential to the decommissioningprogram or worker health and safety (e.g., waste collection and treatment systems, electrical power and ventilation systems). TLG Seruices. Inc.

Perry Nuclear PouserPlant Document F07-1 69900 1, Reu. 0 D ecommi ssioning Cost An aly si s Section 2, Page 7 of 13 Removal of the steel liners from drywell, disposing of the activated and contaminated sections as radioactive waste. Removalof any activated/ contaminatedconcrete. Removal of the steel liners from the steam separator and dryer pool and refueling pool. Surveys of the decontaminated areas of the containment structure. Remediation and removal of the contaminated equipment and material from the fuel handling and auxiliary buildings 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 systemsand componentsftoth clean and contaminated) located within these buildings. This activity facilitates surface decontamination and subsequentverification surveys required prior to obtaining releasefor demolition. Removal of the remaining components,equipment, and plant servicesin support ofthe area releasesurvey(s). Routing of material removed during decontamination and dismantling to a central processingarea. Material certified to be free of contamination is releasedfor unrestricted disposition, as scrap, recycle, or for general disposal. Contaminated material is characterized and segregatedfor additional off-site processing (disassembly,chemical cleaning, volume reduction, and waste treatment), and/or packaged for controlled disposal at a low-level radioactive waste disposalfacilitv. Incorporated into the LTP is the Final Survey Plan. This plan identifies the radiological surveys to be performed once the decontamination activities are completedand is developedusing the guidanceprovided in the "Multi-Agency Radiation Survey and Site Investigation Manual (MARSSIM)."[z3]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 confidencethat applicable NRC criteria are satisfied. Once the survey is complete, the results are provided to the NRC in a format that can be verified. The NRC then reviews and evaluates the information, TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecotnm issioning Cost Analy si s Section 2, Page 8 of 13 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 unrestricteduse). The NRC will amend the operating licenses if it determines that site remediation has been performed in accordancewith 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 decommissioningoperations, site restoration activities can begin. Efficient removal of the contaminated materials and verification that residual radionuclide concentrationsare below the NRC limits may 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, auxiliary, fuel handling, and turbine buildings. Under certain circumstances, verifying that subsurface radionuclide concentrationsmeet NRC site releaserequirements will require removal of grade slabs and lower floors, potentially weakening footings and structural supports. This removal activity will be necessaryfor those facilities and plant areas where historical records, when available, 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 subsurfaceprocessand drain lines were not breachedover 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 processis deferred. This cost study presumes that non-essentialstructures 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 establishedfor erosion control. Site areas affected by the dismantling activities are TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecornmissio ning Cost An aly sis Sectinn 2, Page I of 13 restoredand the plant area gradedas required to prevent ponding and inhibit the refloating of subsurfacematerials. Non-contaminatedconcrete rubble produced by demolition activities is processedto remove reinforcing steel and miscellaneousembedments. The processedmaterial is then used on site to backfill foundation voids. Excess non-contaminated materials are trucked to an off-site area for disposalas construction debris. 2.1.4 ISFSI Operationsand Decommissioning For purposesonly of this estimate, transfer of spent fuel to a repository or interim facility is assumedto be exclusively from the ISFSI once the fuel pool has been emptied and the fuel handling building has been releasedfor decommissioning.The ISFSI will continue to operate under a general license (10 CFR Part 50) following the amendment of the operating licenseto releasethe adjacent (power block) property. Completion of the decommissioning process is dependent upon the ability to remove spent fuel from the site in a timely manner. This analysis assumesthat the last of the spent fuel will be removedfrom the site within approximately thirty-six years of the shutdown of the unit. This assumption assumesthat spent fuel is off site prior to commencing decommissioningoperations in the SAFSTOR alternative. Spent fuel transfer operations from the ISFSI to the DOE are assumed to be completedby 2064. At the conclusion of the spent fuel transfer process,the ISFSI will be decommissioned.The Commissionwill terminate the Part 50 licenseif it determines that the remediation of the ISFSI has been performed in accordancewith an ISFSI license termination plan and that the fi.nal radiation survey and associated documentation demonstrate that the facility is suitable for release. Once the requirements are satisfi.ed,the NRC can terminate the licensefor the ISFSI. The design of the ISFSI is based upon the use of an MPC and a concrete shield (overpack) for pad storage. It is assumed that once the inner canisters containing the spent fuel assemblieshave been removed, any required decontamination is performed on the overpacks (some minor neutron activation is assumed), and the license for the facility terminated, the overpacks can be dismantled using conventional techniques for the demolition of reinforced concrete. The concrete storagepad is then removedand the area regraded. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommission ing Cost Analy si s Section 2, Page 10 of 13 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. 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 securedto provide controlled accessfor inspection and maintenance. The engineering and planning requirements are similar to those for the DECON alternative, although a shorter time period is expected for these activities due to the more limited work scope. Site preparations are also similar to those for the DECON alternative. However, with the exceptionof the required radiation surveys and site characterizations, the mobilization and preparation of site facilities is less extensive. 2.2.I Period 1 - Preparations Preparations for long-term storage include the planning for permanent defueling of the reactor, revision of technical specificationsappropriate to the operating conditions and requirements, a characterization of the facility and major components,and the developmentof the PSDAR. The process of placing the plant in safe-storageincludes, but is not limited to, the following activities: Isolation of the spent fuel storage services and fuel handling systems so that safe-storageoperations may commenceon 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 systemsto 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. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecom.missioning Cost An aly si s Section 2, Page 11 of 13 Disposing of contaminatedfilter elements and resin beds not required for processingwastes from layup activities for future operations. Draining of the reactor vessel, with the internals left in place and the vesselhead secured. Draining and de-energizing non-essential systems, decontaminating them 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 FIVAC systemswhose continued use is not required.

             . Cleaning of the loose surface contamination from building accesspathways.
             . 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, &s required.

2.2.2 Period 2 - Dormanc]' The secondphase identified by the NRC in its rule addresseslicensed activities during a storage period and is applicable to the dormancy period 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 TLG Seruices,Inc.

Perry Nuclear Power Plant Document F07- I 699-001, Reu. 0 D ecommissioning Cost Analysis Section 2, Page 12 of 13 emergency procedures are established and initiated for potential releases that exceedprescribed limits. The environmental surveillance program constitutes an abbreviated version of the program in effect during normal plant operations. Security during the dormancy period is conductedprimarily to prevent unauthorized entry and to protect the public from the consequencesof its own actions. The security fence, sensors, alarms, and other surveillance equipment are maintained throughout the dormancy period. Fire and radiation alarms are also functional. Consistent with the DECON scenario, the spent fuel storage pool is emptied within seven years of the cessationof operations, with the fuel transferred to the ISFSI. Spent fuel transfer from the ISFSI to an appropriate disposal facility is assumed to be complete by 2064. Once emptied, the ISFSI is secured for storage and decommissionedalong with the power block structures in Period 4. After a period of storage (such that license termination is accomplished within 60 years of final shutdown), it is required that the licensee submit an application to terminate the license, along with a LTP (describedin Section2.1.2),thereby initiating the third phase. 2.2.3 Periods3 and 4 - Dela]'edDecommissionine Corresponding to the DECON Periods 1 and 2, Delayed Decommissioningfollowing a SAFSTOR dormancy period is similar to the DECON counterparts,with the following considerations. Prior to the commencementof decommissioningoperations,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 and the assembly of activity specifications and detailed work 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 associatedwith this phase and the follow-on decontamination and dismantling processesare detailed in Sections2.1.1 and 2.1.2.The primary difference between the sequencesanticipated for the DECON and this deferred scenariois the absence,in the latter, of any constraint TLG Seruices, Inc.

Perry Nuclear Power Plant Docutnent F07-1699-001,Rev. 0 D ecomm.issioning Cost Analy sis Section 2, Page 13 of 13 on the dismantling processdue to the operation of the spent fuel pool in the DECON option. Variations in the length of the dormancy period are expectedto have some effect upon the quantities of radioactive wastes generated from system and structure removal operations. Given the levels of radioactivity and spectrum of radionuclidesexpectedfrom forty years of plant operation, no plant process system identified as being contaminated upon final shutdown are assumed to become releasable due to the decayperiod alone. However, due to the lower activity levels, a greater percentageof the waste volume can be designated for off-site processingand recovery. The delay in decommissioningalso yields lower working area radiation levels. As such, the estimate for this delayed scenario incorporates reduced ALARA controls for the SAFSTOR's lower occupational exposurepotential. Although the initial radiation levels due to 60Co will substantially decreaseduring 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 presenceof long-lived radionuclides such as e4Nb,5eNi, and 63Ni.Therefore, the dismantling proceduresdescribedfor the DECON alternative would still be employed during this scenario. Portions of the primary shield will still be radioactive due to the presence of activated trace elements with long half-lives (152Euand 1548u).Decontamination will require controlled removal and disposal.It is assumedthat radioactive corrosion products on inner surfaces of piping and componentswill not have decayedto 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 processis a cost-effectiveoption, as describedin Section2.L.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 Seruices. Inc.

Perry Nuclear Power Plant Document F 0 7-16I 9-001, Reu. 0 D ecommissio n ing Cost An aly sis Section 3, Page 1 of 26

3. COSTESTIMATES The cost estimates prepared for decommissioning Perry 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 describedin this section.

3.1 BASIS OF ESTIMATES The analysis relies upon site-specific,technical information from an earlier evaluation prepared in 2010, updated to reflect current assumptionspertaining to the disposition of nuclear power plants and relevant industry experiencein undertaking such projects. This information was reviewed for the current analysis and updated as deemed appropriate. The site-specificconsiderations and assumptions used in the previous evaluations were also revisited. Modifications were incorporated where new information was available or experience from ongoing decommissioning programs provided viable alternatives or improved processes. 3.2 METHODOLOGY The methodolory used to develop the estimates follows the basic approach originally presented in the AIF/NESP-036 study report, "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates,"[2al and the DOE "Decommissioning flanfllsok.'tt25l These documents present a unit factor method for estimating decommissioning activity costs, which simplifies the estimating calculations. Unit factors for concreteremoval ($/cubicyard), steel removal ($/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), developedfrom plant drawings and inventory documents.Removalrates and material costsfor the conventional disposition of components and structures rely upon information available in the industry publication, "Building Construction Cost Data," publishedby R.S.N[gans.[261 The unit factor method provides a demonstrablebasis for establishing reliable cost estimates. The detail provided in the unit factors, including activity duration, labor costs (by craft), and equipment and consumablecosts,ensures that essential elements have not been omitted. Appendix A presents the TLG Seruices. Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecomrni ssioning Cost An aly sis Section 3, Page 2 of 26 detailed developmentof a typical unit factor. Appendix B provides the values containedwithin one set of factors developedfor this analysis. This analysis reflects lessons learned from TLG's involvement in the Shippingport Station decommissioning,completed in 1989, as well as the decommissioningof the Cintichem reactor, hot cells, and associatedfacilities, completed in 1997. In addition, the planning and engineering for the Rancho Seco,Trojan, Yankee Rowe, Big Rock Point, Maine Yankee, Humboldt Bay-3, Connecticut Yankee, San Onofre, and Crystal River nuclear units have provided additional insight into the process,the regulatory aspects,and the technical challengesof decommissioningcommercialnuclear units. Work Difficultlz Factors TLG has historically applied work difficulty adjustment factors (WDFs) to account for the inefficienciesin working in a power plant environment. WDFs are assigned to each unique set of unit factors, commensurate with the inefficiencies associatedwith working in confined, hazardous environments. The ranges used for the WDFs are as follows: AccessFactor l0% to 20% Respiratory Protection Factor lUVoto 50o/o Radiation/ALARA Factor I0o/oto 37% Protective Clothing Factor l}Yo to 30o/o Work Break Factor 8.33% The factors and their associatedrange of values were developedin conjunction with the AIF/NESP-036 study. The application of the factors is discussedin more detail in that publication. SchedulineProsram Durations The unit factors, adjusted by the WDFs as describedabove,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 developmentof 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 decontaminationof the spent fuel TLG Services, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommissioning Cost Analysis Section 3, Page 3 of 26 pool is also dependent upon the timetable for the transfer of the spent fuel assembliesfrom the pool to the ISFSI. An activity duration critical path is used to determine the total decommissioningprogram schedule. The scheduleis 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 degreeof confidencein the reliability of the resulting costs. 3.3 FINANCIAL COMPONENTS OF THE COST MODEL TLG's proprietary decommissioningcost model, DECCER, producesa number of distinct cost elements. These direct expenditures, however, do not comprise the total cost to accomplishthe project goal, i.e., licensetermination, spent fuel managementand site restoration. 3.3.1 Contineency Inherent in any cost estimate that does not rely on historical data is the inability to specifirthe precise sourceof costs imposedby factors such as tool breakage, accidents,illnesses,weather delays, and labor stoppages. In the DECCER cost model, contingencyfulfills this role. Contingencyis added to each line item to account for costs that are difficult or impossible to develop analytically. Such costs are historically inevitable over the duration of a job of this magnitude; therefore, this cost analysis includes funds to cover these types of expenses. The activity- and period-dependentcosts are combined to develop the total decommissioningcost. A contingencyis 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"l2Tlas "specific provision for unforeseeableelements of cost within the defined project scope;particularly important where previous experience relating estimates and actual costs has shown that unforeseeableevents 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 unforeseeableevents that are likely to occur in decommissioningare discussedand guidelines are provided for a contingency percentage in TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommissio n in g Cost Analy sis Section 3, Page 4 of 26 each category. It should be noted that contingency, as used in this analysis, doesnot accountfor price escalationand inflation in the cost of decommissioningover the remaining operating life of the station. Contingency funds are an integral part of the total cost to complete the decommissioningprocess.Exclusion of this component puts at risk a successfulcompletionof 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 contingenciesranged from 10% to 75o/o, depending on the degree of difficulty judged to be appropriate from TLG's actual decommissioningexperience.The contingencyvalues used in this study are as follows: a Decontamination 50% O Contaminated ComponentRemoval 25o/o o Contaminated ComponentPackaging n% o Contaminated ComponentTransport r5% o Low-Level RadioactiveWaste Disposal 25% a Low-Level RadioactiveWaste Processing I5o/o o Reactor Segmentation 75o/o o Nuclear Steam Supply System ComponentRemoval 25% o ReactorWaste Packaging 25% o ReactorWaste Transport 25o/o o ReactorVessel ComponentDisposal 50o/o a Greater Than Class C Disposal 75% a Non-RadioactiveComponentRemoval I5o/o a Heavy Equipment and Tooling t5o/o o Supplies 25% o Engineering I5o/o o Energy l5o/o a Insurance, Property Taxes and Fees L0% o Staffing l5o/o o Characterization and Termination Survevs 30% o Construction I5o/o a Spent Fuel Capital Costs (Canisters and Overpacks) 15% a Spent Fuel Transfer Costs 75% a Operationsand MaintenanceExpenses I5% a ISFSI Decommissioning 25% TLG Seruices, Inc.

Perry Nuclear Power Plant Docutnent F07-1699-001,Reu. 0 D ecomntissio n ing Cost An aly si s Section 3, Page 5 of 26 The contingencyvalues are applied to the appropriate componentsof the estimateson a line item basis. A compositevalue is then reportedat the end of eachdetailedestimate (as providedin AppendicesC, D and E). 3.3.2 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 necessaryto generate a level of confrdence in the estimate, within a range of probabilities. TLG considers these types of costsunder the broad term "financial risk." Included within the categoryoffinancial 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 packagesthroughout the decommissioningprogram, 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. Changesin the project work scopefrom 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 releasecriteria, waste transportation, and disposal. Policy decisions altering national commitments (e.g., in the ability to accommodatecertain waste forms for disposition, or in the timetable for such, or the start and rate of acceptanceof spent fuel by the Federal government). Pricing changes for basic inputs such as labor, energy, materials, and waste disposal. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001, Reu. 0 D ecommissioning Cost Analy sis Section 3, Page 6 of 26 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 will be revisited periodically and addressedthrough repeated revisions or updatesof the baseestimates. 3.4 SITE-SPECIFIC CONSIDERATIONS There are a number of site-specificconsiderationsthat affect the method for dismantling and removal of equipment from the site and the degree of restoration required. The cost impact of the considerationsidentified below is included in this cost study. 3.4.1 Spent Fuel Manasement The cost to disposeof the spent fuel generatedfrom plant operationsis not reflected within the estimates to decommission Perry. Ultimate disposition of the spent fuel is within the province of the Federal government's Waste Management System, as defined by the Nuclear Waste Policy Act. The disposal cost was financed by a 1 milVkWhr surcharge paid into the DOE's waste fund during operations. On November 19, 2013, the U.S. Court of Appeals for the D.C. Circuit ordered the Secretaryof the Department of Energy to suspendcollecting annual fees for nuclear waste disposal from nuclear power plant operators until the DOE has conducted a legally adequate fee assessment. The NRC does, however, require licensees to establish a program to manage and provide funding for the managementof all irradiated fuel at the reactor site until title of the fuel is transferred to the Federal government. This requirement is included through certain high-level waste cost elementswithin the estimates.as describedbelow. Completion of the decommissioningprocess is highly dependent upon the ability to remove spent fuel from the site. This analysisassumesthat the last of the spent fuel will be removed from the site within approximately thirty-six years of the final shutdown. This assumesthat spent fuel is off site prior to commencing decommissioningoperations in the SAFSTORalternative. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001, Reu. 0 D ecommissioning Cost Analy sis Section 3, Page 7 of 26 ISFSI An ISFSI has been constructed on site to support continued plant operations. The ISFSI is expected to operate throughout decommissioning,and beyond the conclusionof the remediation phase in the DECON decommissioningscenario,until such time that the transfer of spent fuel to an appropriate disposalfacility can be completed. Spent fuel transfer from the ISFSI is assumed to be complete by 2064. The scenario is similar for the SAFSTOR alternative; however, based upon the expectedcompletion date for fuel transfer, the ISFSI will be emptied prior to the commencementof decommissioningoperations. The design and capacity of the ISFSI is based upon the Holtec International Hi-Storm 1005 system (with a 68-fuel assemblycapacity). The system consists of a multi-purpose (storage and transport) canister (MPC) and a concreteshield (overpack). Operation and maintenance costs for the spent fuel pool and the ISFSI are included within the estimates and address the cost for staffing the facility, as well as security, insurance, and licensing fees.The estimates include the coststo purchase,load, and transfer the MPCs from the pool or from the ISFSI. Costs are also provided for the final disposition of the facilities oncethe transfer is complete. Canister Loading and Transfer An average cost of approximately $834,000 is used for the labor to load/transport the spent fuel from the pool to the ISFSI pad, basedupon FirstEnergy experience. For estimating purposes, 50% of this cost is used to estimate the cost to transfer the fuel from the ISFSI to the DOE. Operations and Maintenance The estimates also include the cost of operating and maintaining the spent fuel pool and the ISFSI, respectively.Pool operations are expected to continue approximately seven years after the cessationof operations of each unit. It is assumed that the seven years provides the necessary cooling period for the final core to meet applicable transport system requirements for decay heat and/or the dry cask storage vendor's system. ISFSI operating costs are based upon the previously stated assumptionson fuel transfer expectations. TLG Seruices. Inc.

Perry Nuclear Power Plant Docum.entF07-1699001,Reu. 0 D ecornmissio ning Cost An aly si s Section 3, Page 8 of 26 ISFSI Decommissionine Eleven overpacks 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 exceedingfree-releaselimits. This allowanceis equivalent to the number of overpacksrequired to accommodatethe final core off load from Perry. The cost of the disposition of this material is included in the estimate. Appendix E details the costs necessaryto survey, decontaminate,and terminate the NRC license on the ISFSI facility. The estimates in AppendicesC, D and E also include the costs for the demolition of the ISFSI facility following NRC license termination (as a Site Restoration expense). GTCC The dismantling of the reactor internals is expected to generate radioactive waste consideredunsuitable for shallow land disposal (i.e., Iow-level radioactive waste with concentrations of radionuclides that exceedthe limits establishedby the NRC for Class C radioactive waste, or greater than Class C (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 reasonablecosts of disposing of such waste. Although the DOE is responsiblefor disposing of GTCC waste, any costs for that service have not been determined. For purposesof this estimate, the GTCC radioactive waste has been assumed to be packaged in the same canisters used to store spent fuel and disposed of as high-level waste, at a cost equivalent to that envisionedfor the spent fuel. It is assumed that the DOE would not accept this waste prior to completing the transfer of spent fuel. Therefore, until such time the DOE is ready to acceptGTCC waste, it is reasonableto assumethat this material would remain in storage at the Perry site (for the DECON alternative). In the SAFSTOR scenario, the GTCC material is shipped directly to an appropriate disposal facility as it is generated since the fuel has been removed from the site prior to the start of decommissioning. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommission ing Cost An aly sis Section 3, Page 9 of 26 3.4.2 ReactorVesseland Internal Components The reactor pressurevesseland internal componentsare segmentedand shipped for disposal in shielded, reusable transportation casks. Segmentationis performed in the refueling canal, where a turntable and remote cutter are installed. The vessel is segmentedin 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 segmentationand packaging methodology. Intact disposal of reactor vessel shells has been successfully demonstrated at several of the sites that have been decommissioned. Accessto navigable waterways has allowed these large packagesto be transported to the Barnwell disposal site with minimal overland travel. Intact disposal of the reactor vessel and internal components can provide savings in cost and worker exposureby 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, Iimited 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 compliancewith land disposalregulations. It is not known whether this option will be available when the Perry plant ceasesoperation. 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 TLG Seruices, Inc.

Perry Nuclear Pouer Plant Document F07-169L001,Reu. 0 D ecom.missioning Cost An aly si s Section 3, Page 10 of 26 that the reactor vessel will require segmentation as a bounding condition. 3.4.3 Primarv SvstemComponents The NSSS (reactor vessel and reactor recirculation system components) will be decontaminated using chemical agents prior to the start of cutting operations (DECON scenario only). 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 "processliquid waste"charge. Reactor recirculation piping is cut from the reactor vesseloncethe water level in the vessel (used for personnel shielding during dismantling and cutting operations in and around the vessel)is droppedbelow the nozzle zone. The piping is boxed and transported by shieldedvan. The reactor recirculation pumps and motors are lifted out intact, packaged, and transported for processingand/or disposal. 3.4.4 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 condensersare also disassembledand moved to a laydown area. Material is then prepared for transportation to an off-site recycling facility where it is surveyed and designated for either decontamination or volume reduction, conventional disposal, or controlled disposal. Componentsare packagedand readied for transport in accordancewith the intended disposition. 3.4.5 Transportation Methods Contaminated piping, components, and structural material other than the highly activated reactor vessel and internal componentswill qualifu as LSA-I, II or III or Surface Contaminated Object, SCO-I or II, as describedin Title 49.t281The contaminated material will be packagedin 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 componentsare expectedto be transportedin accordancewith 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 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommi ssioning Cost An aly si s Section 3, Page 11 of 26 outer surface would require that additional shielding be incorporated within the packaging so as to attenuate the dose to levels acceptablefor transport. Any fuel cladding failure that occurredduring the lifetime of the plant is assumedto have releasedfission products at sufficiently low levels that the buildup of quantities of long-lived isotopes (e.g., 137Qs,e0Sr,or transuranics) has been prevented from reaching levels exceedingthose that permit the major reactor componentsto be shipped under current transportation regulations and disposalrequirements. Transport of the highly activated metal, produced in the segmentationof the reactor vessel and internal components,will be by shielded truck cask. Cask shipments may exceed 95,000 pounds, including vessel 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 schemefor the vessel and internal segmentsis designedto meet these limits. The transport of large intact components (e.g., large heat exchangers and other oversizedcomponents)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 costsfor the higher activity Class B and 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. Transportation costs for off-site waste processing are based upon the mileage to Oak Ridge, Tennessee.Truck transport costswere developed from published tariffs from Tri-State Motor Transit.tzel 3.4.6 Low-Level RadioactiveWaste Disposal To the greatest extent practical, metallic material generated in the decontamination and dismantling processesis processedto reduce the total cost of controlled disposal. Material meeting the regulatory and/or site release criterion, is released as scrap, requiring no further cost consideration. Conditioning (preparing the material to meet the waste acceptancecriteria ofthe disposalsite) and recoveryofthe waste stream is performed off site at a licensed processing center. Any material TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001, Reu. 0 D ecommissioning Cost An alysis Section 3, Page 12 of 26 leaving the site that was removed from a contaminated or potentially contaminated area is subject to a survey and release charge, at a minimum. The mass of radioactive waste generated during the various decommissioningactivities at the site is shown on a line-item basis in the detailedAppendicesC, D and E, and summarizedin Section5. The quantified waste summaries shown in these tables are consistent with 10 CFR Part 61 classifications.Commercially available steel containers are presumedto be used for the disposalof piping, small components, and concrete.Larger componentscan 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 componentsserving 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 burial fees are applied against the liner volume, as weII 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 radionuclideslimit the capacity of the shipping canisters. Disposal fees are based upon estimated charges,with surchargesadded for the highly activated components, such as those generated in the segmentationof the reactor vessel.The cost to disposeof the lowest level and majority of the material generated from the decontamination and dismantling activities is based upon the current cost for disposal at EnergySolutions facility in Clive, Utah. Disposal costs for the higher activity waste (Class B and C) were based upon preliminary information from WCS for the Andrews Countv facilitv. 3.4.7 Site Conditions Following Decommissionine 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 decommissioningprocess,as well as owner's own future pians for the site. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Rev. 0 D ecommissioning Cost Analy sis Section 3, Page 13 of 26 Only existing site structures are consideredin the dismantling cost. The electrical switchyard remains after Perry is decommissionedin support of the regional transmission and distribution system. Structures are removed to a nominal depth of three feet below grade. The voids are backfilled with clean debris and capped with soil. The site is then re-gradedto conform to the adjacentlandscape.Vegetation is establishedto inhibit erosion. These "non-radiologicalcosts" are included in the total cost of site restoration. Costs are included for the demolition of shoreline structures including the intake structure, the alternate, cooling towers and the cooling tower pump house. Costs are not included for general restoration of the lake shoreline. Concrete rubble generated from demolition activities is processedand made available as clean fiII for the power block foundations. Additional clean fill is brought on site to backfill below grade voids as needed.The excavationswill be regraded such that the power block area wiII have a final contour consistentwith adjacent surroundings. The estimates do not assume anv remediation of contaminated soil at Perry. 3.5 ASSUMPTIONS The following are the major assumptions made in the development of the estimates for decommissioningthe site. 3.5.1 Estimatine Basis Decommissioningcostsare reported in the year of projectedexpenditure; however, the values are provided in2014 dollars. Costs are not inflated, escalated,or discountedover the periods of performance. The plant inventory, the basis for the decontamination and dismantling requirements and cost, and the decommissioningwaste streams, was taken from the 2010 analysis. The ISFSI recently constructed on site was also added to the structures inventory. 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 TLG Seruices. Inc.

Perry Nuclear Power Plant Document F0 7-169900 1, Reu. 0 D ecornmi ssioning Cost An aly si s Section 3, Page 14 of 26 lengthen a task's duration, increasing costs and lengthening the overall schedule.AI"ARA planning is consideredin the costsfor engineering and planning, and in the developmentof activity specificationsand detailed procedures. Changes to worker exposure limits may impact the decommissioning costand project schedule. 3.5.2 Labor Costs The craft labor required to decontaminate and dismantle the nuclear unit 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 FirstEnergy. FirstEnergy will hire a DecommissioningOperations Contractor (DOC) to manage the decommissioning.The owner will provide site security, radiological health and safety, quality assurance and overall site administration during the decommissioning and demolition phases. Contract personnel will provide engineering services for preparing the activity specifications, work procedures, activation, and structural analysesunder the direction of FirstEnergy. Personnel costs are based upon average salary information provided by FirstEnergy. A utility labor payroll overhead rate of 36.6% has been included. Security, while reduced from operating levels, is maintained throughout the decommissioning for access control, material control, and to safeguardthe spent fuel. A profi.le of the staffing level for the decommissioning, including contractors and craft, is provided in Figures 3.1 and 3.2 for the DECON and SAFSTOR scenarios.Utility staffing levels will gradually decrease aftet completing the removal of physical systems. Staffing levels and management support will vary based upon the amount and type of decommissioning work. Craft manpower levels decrease after systems removal and structures decontamination and drop substantially during the delay period and the license termination survey period. However, craft staff levels increase again during the site restoration period due to the work associated with structures demolition. TLG Seruices, Inc.

Perry Nuclear Power Plant Docurnent F07- I 699-001, Reu. 0 D ecornrnissioning Cost Analy sis Section 3, Page 15 of 26 3.5.3 Desisn Conditions Any fuel cladding failure that occurredduring the lifetime of the plant is assumedto have releasedfission products at sufficiently low levels that the buildup of quantities of long-lived isotopes (e.g., 137Cs,eoSr,or transuranics) has been prevented from reaching levels exceedingthose that permit the major NSSS componentsto be shipped under current transportation regulations and disposalrequirements. The curie contents of the vessel and internals at final shutdown are derived from those listed in NUREG/CR-347{.tsolfisfual estimates are derived from the curie/gram values contained therein and adjusted for the different mass of the Perry components,projectedoperating life, and different periods of decay. Additional short-lived isotopes were derived from NUREG/CR-0130Igland NUREG/CR-0672.t321 and benchmarkedto the long-lived values from NUREG/CR-}474. It is anticipated that there will be control element assemblies(CEAs) in the spent fuel pool at the cessationof operations,including those CEAs from the final core. This analysis assumes that the CEAs can be disposedof along with the spent fuel at no additional cost (in accordance with Appendix E of the Standard Contract). Neutron activation of the reactor building structure is assumed to be confined to the primary shield adjacentto the reactor vessel. 3.5.4 General Unit 2 While this estimate includes Unit 1 and shared facilities with the adjacent Unit 2, it does not include the license termination survey or demolition and removal of those structures identified as Unit 2 facilities under the terms of the PUC agreement regarding the termination of construction activities at Unit 2. Transition Activities Existing warehouses are cleared of non-essential material and remain for use by FirstEnergy 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: TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699001,Rev. 0 D ecomm.ission ing Cost An aly sis Section 3,Page 16 of 26

            .      Drain and collect fuel oils, lubricating oils, and transformer oils for recycleand/or sale.
            .      Drain and collect acids, caustics, and other chemical stores for recycleand/or sale.

o Process operating waste inventories. Disposal of operating wastes (e.g.,filtration media, resins) during this initial period is not considereda decommissioning expense. Scrap and Salvage The existing plant equipment is considered obsolete and suitable for scrap as deadweight quantities only. FirstEnergy wiII make economically reasonable efforts to salvage equipment following final plant shutdown. However, dismantling techniques assumedby TLG for equipment in this analysis are not consistent with removal techniques required for salvage(resale)of equipment. Experiencehas indicated that some buyers wanted equipment stripped down to very specifi.c requirements before they would consider purchase. This required expensive rework after the equipment had been removed from its installed location. Since placing a salvagevalue on this machinery and equipment would be speculative, and the value would be small in comparisonto the overall decommissioningexpenses,this analysis does not attempt to quantiS/ the value that an owner may realize basedupon

           -thoseefforts.

It is assumed,for purposesof this analysis, that any value receivedfrom the sale of scrap generated in the dismantling process would be more than offset by the on-site processingcosts.The dismantling techniques assumedin the decommissioningestimates 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 releasethis 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 decommissioningproject. Disposition may include relocation to other facilities. Spare parts are also made available for alternative use. TLG Services, Inc.

Perry Nuclear Power Plant Document F07-169L001,Reu. 0 D ecomrnissio ning Cost An aly sis Section 3, Page 17 of 26 Asbestos Theseestimates do not include anv costsfor remediation of asbestos. Energ.v For estimating purposes,the plant is assumedto 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 consumedduring decommissioningfor tooling, lighting, ventilation, and essentialservices. Insurance Costs for continuing coverage(nuclear liability and property insurance) following cessationof plant operations and during decommissioningare included and based upon current operating premiums. Reductions in premiums, throughout the decommissioningprocess,are basedupon the guidance provided in SECY-00-0145,"Integrated Rulemaking Plan for Nuclear Power Plant Decommissioning."[33]The NRC's fi.nancial protection requirements are based on various reactor (and spent fuel) confi.gurations. FirstEners.vCorporate Overhead A corporate support overhead cost has been included at a level commensuratewith the existing Perry corporate support costs for the first year after final shutdown, decreasingto I% of this level within ten years (DECON scenario only). The SAFSTOR scenarios are more complicated, decreasing during dormancy, but increasing again during delayeddecommissioning. Site Non-Labor Overhead These estimates include costs for site non-labor overheadcharges.These costs include telephones, copy machines, computers, IT infrastructure, office supplies, janitorial supplies, training expenses,etc. FirstEnergy provided a site non-laboroverheadallowanceat $18,300per personper year to addressthese costs. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F0 7-169*00 1, Reu. 0 D ecommi ssioning Cost An aly si s Section 3,Page 18 of 26 Propertv Taxes Property taxes are included for all decommissioningperiods. Property taxes for the site are $4.448 million for the fi.rst year following final shutdown. This is decreased by 50o/ofor the following years until demolition of the power block structures commence.Property taxes are then ramped down over the two year demolition period. In the DECON scenario, while spent fuel storage continues at the on-site ISFSI, the property taxes are maintained at $835 thousand annually (land value only). In the SAFSTOR scenario,property taxes are reduced to zero at the end of the demolitionperiod. NRC Fees These estimates include charges from the NRC to support the Perry decommissioningprogram. Charges are included for the yearly licenses held by FirstEnergy for the Part 50 license, as well as engineering support chargesby the NRC to review activities at the site. The Part 50 license fee for a reactor in a decommissioningor possession-onlystatus and which has spent fuel onsite is $224 thousand per year. The hourly rate for NRC review is $279.00.The level of effort of NRC participation is commensurate with the decommissioningalternative and schedule; for example the DECON scenario has an estimated NRC support requirement of approximately 6,800 hours from shutdown until termination of the ISFSI license. EmergencvPlanning Fees Theseestimates include costsfor emergencyplanning support activities. There are three separate civil emergency planning organizations assumed to be supporting FirstEnergy during the decommissioning program. The Federal Emergency Management Agency (FEMA) yearly fees are estimated at $615,900 for the site from shutdown until approximately 12 months after each unit's shutdown, afber which the FEMA fees are assumedto be eliminated. The Ohio emergencymanagementyearly fees are estimated at $865,300 for the site from shutdown until approximately 12 months after shutdown, after which these state emergency agency fees are also assumedto be eliminated. The combinedAshtabula, Geauga,and Lake Counties emergencyagency feesare estimated at $580,900for the site per year. Thesefeescontinue TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699001,Reu. 0 D ecommissioning Cost An aly si s Section 3, Page 19 of 26 until the spent fuel has been removed from the site, assumedto be in the year 2064. 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 stagesofthe project. 3.6 COST ESTIMATE

SUMMARY

A scheduleof expendituresfor each scenariois providedin Tables 3.1 and 3.2. Decommissioning costs are reported in the year of projected expenditure; however, the values are provided in thousands of 2014 dollars. Costs are not inflated, escalated, or discounted over the period of expenditure. The annual expenditures are based upon the detailed activity costs reported in Appendices C, D and E, along with the schedulesdiscussedin Section4. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F0 7-1699-001, Reu. 0 D ecommissioning Cost Analy sis Section 3, Page 20 of 26 TABLE 3.1 DECONALTERNATIVE TOTAL ANNUAL EXPENDITURES (thousand s, 2014dollars) Equipment & Year Labor Materials Enerry Burial Other 2026 48.225 11,758_ _-2,-93-8_

_31 t9.776 82.428 2027 75,090 Lr:_2*77 4.964 22,930 26 188 160.450 2028 76.925 39,559 3.r74 60.228 17.551 r97.437 2029 77,99_q 34.740 _ ^2$5__0 46,428 15,693 r77.405 2030 78.783 29,'rL 2,499 31.295 13.685 r55,773 2031 61.795 24,399 499 22.2t4 12.226 r23 13 3 2032 20.341 11.941 2.506 26 8,687 43.501 2033 34.472 7 .6 7 4 1,505 8.652 8.970 6L.273 2034 3 6 .9 7 5 7.884 550 19 5.399 50.827 2035 26.935 1 5 , 111 333 0 5.462 47.84r 2036 l7,927 9,149 202 0 4.609 3L.787 2037 3,822 0 0 0 3,277 7,099 2038 4,301 1 .4 3 8 0 0 3.277 9.016 2039 4.301 1 .4 3 8 0 0 3.277 9.016 2040 4.}Lr 1,438 0 0 3.286 9.035 204r 4.301 1 .4 3 8 0 0 3,277 9.016 2042 3_,922 0 0 0 3.277 7,099 2043 3,922 0 0 0 3.277 7,099 2044 4,I91 1 .0 7 8 0 0 3,286 8.556 2045 4,I8L 1 ,0 7 8 0 0 3,277 8,536 2046 4.181 1 .0 7 8 0 0 3.277 8,536 2047 4.181 1 ,0 7 8 0 0 3,277 8,536 2048 4,191 1 .0 7 8 0 0 3.286 8,556 2049 4.181 1 ,0 7 8 0 0 3,277 8.536 2050 4.181 1 ,0 7 9 0 0 3.277 8,53 6 2051 4 181 078 0 0 3,277 8.536 2052 4,lgl _ 1 ,0 7 9 __0_ I 3,286 q,556

 ?"9[?_ _ _4,18_!           _L-q?8        _0              I      ?47            9,53E 2054       4,181            1 ,0 7 8         0          0      3.277          8.536 2055       4,I8L            1 .0 7 8i        0          0      3.277          8,53 6 TLG Seruices.Inc.

Perry Nuclear Power Plant Document F 0 7-I 6I 9-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 21 of 26 TABLE 3.1 (continued) DECON ALTERNATIVE TOTAL ANNUAL EXPENDITURES (thousands.2014dollars) Equipment & Year Labor Materials Energ5' Burial Other Total 2056 4.T9I 1 ,0 7 8 0 0i 3.286 556 2057 4.181 1 ,0 7 8 0_ 0 3.277 8,53 6 2058 4,181 1 ,0 7 8 0 0 3.277 8,536 2059 4.181 1 ,0 7 9 0 0 3.277 8,536 2060 4.r91 1 ,0 7 8 0 0 3,286 8,556 206r **_4J8_1 1 ,0 7 8 0 0 3.277 8.536 2062 4.181 1 .0 7 8 0 0 3.277 8,536 2063 4.181 1 .0 7 8 0 0 3.277 8,536 2064 4.072 7t9 0 0 3.286 8,077 2065 2.666 3.729 56 2.r77 13,291 2r.9L9 TLG Seruices, Inc.

Perry Nuclear Power Plant Docum.ent F07-1699-001,Reu, 0 D ecommissioning Cost Analysis Section 3, Page 22 of 26 TABLE 3.2 SAFSTORALTERNATIVE TOTAL ANNUAL EXPENDITURES (thousand s. 2014dollars) Equipment & Year Labor Materials Energ;r Burial Other Total 2026 3_9,996_ 11 . 3 5 3 2.638 31 t9.776 73.494 2027 49.928 22,945 2,565 I,527 26.970 103.929 2028 20.482 1 5 ,5 6 0 668 15 9,430 46,15 5 2029 20,427 15.517 666 15 9.404 46,029 2030 20.427 15,517 666 15 9.404 46.029 2031 20.427 L5.5r7 666 15 9.404 46.029 2032 20.482 1 5 .5 6 0 668 15 9.430 46,r55 2033 9,638 4.r75 402 I 5,752 19.975 2034 7.266 2.493 333 7 4.807 14,906 2035 6.906 L,4T5 333 7 4.807 13.469 2036 6.924 1,416 334 7 4.820 13,502 2037 6.547 337 333 7 4,807 12.031 2038 7.026 r.775 333 7 4,807 13.948 2039 7.026 r.775 333 7 4.807 13.948 2040 7.O44 1.776 334 7 4,820 13.981 204I 7,026 r.775 333 7 4,907 13,948 2042 6 .5 4 7 337 333 7 4.807 12.031 2043 6.547 337 333 7 4,847 12,03r 2044 6.924 r,416 334 7 4.820 13.502 2045 6 .9 0 6 1.4t5 333 7 4.807 13.469 2046 6,906 r.4t5 333 7 4,807 13,469 2047 6.906 1.415 333 7 4.807 13,469 2048 6.924 t.416 334 7 4.820 13.502 2049 6.906 1.415 333 7 4.807 13,469 2050 6.906 T,4L5 333 7 4.807 13.469 2051 6,906 1.415 333 7 4.807 13,469 2052 6.924 1.416 334 7 4.820 13.502 2053 6.906 1 . 4 1 5______?_?3 7 4,807 13,469 2054 6 .9 0 6 1.415 333 7 4.807 13.469 2055 6 ,9 0 6 1 .4 1 5 333 nt 4,807 13.469 TLG Seruices. Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecornmissioning Cost Analy sis Section 3, Page 23 of 26 TABLE 3.2 (continued) SAFSTOR ALTERNATIVE TOTAL ANNUAL EXPENDITURES (thousands, 2074 dollars) Equipment & Year Labor Materials Energy Burial Other Total 2056 6,924 I.4T6 334 7 4.820 13.502 2057 6,906 1.415 333 nt 4.807 13.469 2058 6.906 t,4r5 333 7 4.807 13.469 2059 E,q_qQ I.4I5 333 7 4.807 13.469 2060 6,924 t.4t6 334 7 4,820 13.502 206r 906 I.4t5 333 7 4.807 13,469 2062 6,906 1,4r5 333 7 4.807 13.469 2063 6,906 1.415 333 7' 4.807 13.469 2064 6,804 1 ,0 5 7 334 7 4.820 13.023 2065 2,700 330 333 6 3.955 7.324 2066 2 .7 0 0 330 333 6 3.955 7.324 2067 2.700 330 333 6 3.955 7.324 2068 2.707 331 334 6 3,966 7.345 2069 2.700 330 333 6 3.955 7.324 2070 2.700 330 333 6 3,955 7.324 207r 2,700 330 333 6 3.955 7.324 2072 2.707 331 334 6 3,966 7,345 2073 i 2.700 330 333 6 3.955 7.324 2074 ! 2.700 330 333 6 3.955 7.324 2075 2,700 330 333 6 3.955 7.324 2076 2 .7 0 7 331 334 6 3.966 7.345 2077 2,700 330 333 6 3.955 7.324 2078 2,700 330 333 6 3,955 7,324 2079 2,700 330 333 6 3.955 7.324 2080 24.650 1,515 2,374 24 5,581 34,084 2081 i 45.978 L0,627 3.307 1 0 . 11 3 8,951 78,976 2082 61.446 27.469 3,166 65,720l 20,830 r78.632

- ZPss-r 6-0-: 16_? * *1L45_9 _.-?,-6_QQ I AG,It4_j _14.4_ry TilAU L-?9e1-i- -qQ,{s-? __*uJqg _*-2AAA_ L___ql'4ls_ l?-lqq usJzq I zoss i 47,s98 6.562 1.490i ra,noi 7.74s 77.79 9 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommissioning Cost Analy sis Section 3, Page 24 of 26 TABLE 3.2 (continued) SAFSTORALTERNATIVE TOTAL ANNUAL EXPENDITURES (thousands,2014dollars) Equipment & Labor Materials Enerry Burial Other Total

                             -1*0,9p9       402\

12,935 333i 4 .7 8 4 t23 Total i 8 1 1 , 3 3 4 265,r25 ggQ.5-q4J 194 ___1,-6_90, TLG Seruices.Inc.

Perry Nuclear Power Plant Document F07-1699-001,Rev. 0 D ecommissioning Cost An aly sis Section 3, Page 25 of 26 FIGURE 3.1 PERRY MANPOWER LEVELS DECON ALTERNATIVE se$stty

                                                                  *&her    stsfl

I.-s,9! .

                                          -$"              ,r$       "s Yecr TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecomtnissioning Cost Analy sis Section 3, Page 26 of 26 FIGURE 3.2 PERRY MANPOWER LEVELS SAFSTORALTERNATIVE 506,0 450-D 4ilD-$ 350-* gF.s 25S-S tro"0 1sil-& 1gE$ 5E,G 0"{} at tt$" .S 'd* .f ,"" .o& ,r$ ,$. "S- d *f "#

                     "S         "S "d,t     "$.

YEar TLG Seruices. Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu, 0 D ecommissioning Cost Analysis Section 4, Page I of 6

4. SCHEDULE ESTIMATE The schedulesfor the decommissioningscenariosconsideredin this analysis follow the sequencespresentedin the NF/NESP-036 study, with minor changesto reflect recent experienceand site-specificconstraints. In addition, the schedulinghas been revised to reflect the spent fuel managementdescribedin Section3.4.I.

A schedule or sequenceof activities for the DECON alternative is presented in Figure 4.1. The scheduling sequenceis based on the fuel being removed from the spent fuel pool within seven years of shutdown. The key activities listed in the scheduledo not reflect a one-to-onecorrespondencewith those activities in the cost tables, but reflect dividing some activities for clarity and combining others for convenience.The schedulewas prepared using the "Microsoft Project Professional 2013"computersoftware.[34] 4.L SCHEDULE ESTIMATE ASSUMPTIONS The schedule reflects the results of a precedencenetwork developedfor 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 assumptionswere made in the developmentof the decommissioningschedule: o The fuel handling building is isolated until such time that aII spent fuel has been dischargedfrom the spent fuel pool to an appropriate disposal facility or to the ISFSI. Decontamination and dismantling of the storage pool is initiated once the transfer of spent fuel is complete (DECON option). o All work (exceptvessel and internals removal) is performed during an 8-hour workday, 5 days per week, with no overtime. o Reactor and internals removal activities are performed by using separate crews for different activities working on different shifts, with a correspondingbackshift charge for the secondshift.

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

TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Rev. 0 D ecommi ssioning Cost An aly sis Section 4, Page 2 of 6 o For plant systems removal, the systems with the longest removal durations in areas on the critical path are consideredto determine the duration of the activity. 4.2 PROJECT SCHEDULE The period-dependentcostspresentedin the detailed cost tables are based upon the durations developed in the schedulesfor decommissioning.Durations are establishedbetweenseveralmilestonesin eachproject period;thesedurations 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-dependentcosts.A secondcritical path is shown for the spent fuel storageperiod, which determines the release of the fuel handling building for final decontamination. Projecttimelines are provided in Figures 4.2 and 4.3, with milestonedatesbased on the anticipated shutdown dates. The fuel pool is emptied approximately seven years after shutdown, while ISFSI operations continue until all spent fuel has been transferred to an appropriate disposalfacility. Deferred decommissioningin the SAFSTOR scenariosare assumedto commenceso that the operating licenses are terminated within a 60-year period from the cessationof plant operations. TLG Seruices. Inc.

Perry Nuclear Power Plant Document F07-I 699-001, Reu. 0 D ecomrnissin ning Cost Analy si s Section 4, Page 3 of 6 FIGURE 4.1 ACTIVITY SCHEDULE -DECON la.k )iace nmr l ratn l mr* l.n* l rnsr l mr, I *ora l rnrr Pen1. -\ucJ.ear Power Plent ffi i:ttiElll'-ll:TlTlTii-Ft ffi trl

                                                                                                                                         ?qG.r:Slll$

Shqrdm'n L;r!t I j

P*;iod la Unit 1 Shutdorvn thrcugh trareition @

t*;r&;";* ;apur***"*, cssrstlon of operxtLcrrs subuirt+d t r uer :rolRge llml operatlons W Reronfigw plan_t W Flxpare adi.f ij-q M Per{orn slt charactrizstion W PSFAR *ul:mitt*rl + tr{'.rxr** sei-tificaie cf pernrRilffit re*}o!-alaf fuei subnurtecl I

       $it*   rperi{ic    deensrmissiexiug         (ssl e:tif,r$tte : u}:nii!ec}                      +

ilOi siaiT $obilized +

  -i.-oJ tl U*t L - Demmmissioning                       prepuati.ou                                   a t;;i-&;;;p*t;;'"ii"*                                                                              w

. . fi;mnsg"t; planr lmnrlnueit) w Pgepgg detg'd.e w Demn )iSSS- ua Imlste spent fue1pol w i;Ji"U;; I .L*#co,ap"nenr remval l"vrtTt

                                                                                                          '-:'---'t
 .-* ry":L*:xff -n99!             9-9::*-!91,E-..      "

Prep*ation for re_a_ctorvesel rep-o_ysl ...... I y9sp1& rnrcI4al v.??74 lesctor i, Heru*inrrrg large l(SSS componenis dispoaition Noo-e*senal ry"t*ns lg[sin 1s']iaq/gg&gaanog

    --14**-*:{s,rx:--.             ..-* - --..
      .{,ie gig }e19111_t1en          BJ*1*bxit**d                                                        il Pgnod2bUro11 . Deo__niaminabon                        {wetfue})                                        i ' a ,zV7rEirl Fuet porls_g ro*! apg_rgtips_                                                                      ii rw ryry A"*9:.:-.--ry:F#l a,ot:uppo,ggg se-tfue] _sforage-i; Deon buildingsn6t supportingwetfre.I storgse                                                         , L Li-c-*grylerm1Fpllg& hr"rgf.p,{pi"ed                                                                                    t Fuei siorage_pm1 delay                                                                                                  a Fuei stcr*ge pml svsrlsble fqr Cecom*rssionrng l*::g4.-r*.

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fuel pml delaS-DsJa; P49"e'fiFF-D*sr-"+. w v7v"v) Period 2d - Demntaminaiion following ret fueI storage i@ Rercve remeiriug Demn $et fuel stora_ge area sysiems ii ww Perrod !e - Plani.liense termimtion a Dqt: fu"t =tot"g" op""*tio* i Final Srte Sm'ev a

      \T.C reuew_& approlll
                                            ....                                                                                         iw Far"t 5N hcense teyruinater{                                                                                                       i+

Penod 3b - Site restor*tion :TM t BuLldrng de*;Ltton=, b*"kfrll anil landsapug iw 4 Eurldrng demoiition im w Landmpe,S;te il TLG Seruices, Inc.

Perry Nuclear Pouer Plant Document F07- 1699-001, Reu. 0 D ecommissioning Cost Analy sis Section 4, Page 4 of 6 FIGURE 4.1 (continued) ACTIVITY SCHEDULE _DECON LEGEND 1 . Red scheduling bars indicate critical path activities 2 . Blue schedulingbars associatedwith major decommissioningperiods,e.8.,Period la, indicate overall duration ofthat period

    ,1. Diamond symbolsindicate major milestones TLG Services. Inc.

Perry Nuclear Pouter Plant Document F0 7-16I 9-001, Reu. 0 D ecom.missioning Cost Analy si s Section 4, Page 5 of 6 FIGURE 4.2 DECOMMISSIONINGTIMELINE DECON (not to scale) Unit Shutdown Period3 Period1 Period2 Site ISFSI ISFSI Preparations Decommbsioning Restoraton Operations D&D

                         ,                                                      I?IBJi
                ,j;                                                                                !   =::=

ti$lIr;ll l Mar2026 Jul Sep2O27 I nre 2034 Aug2036 Dec2064 FuelPoolOoeratioN Mar2033 Dry tuel Storage TLG Seruices, Inc.

Perry Nuclear Power Plant Docutnent F07-1699-001,Reu, 0 D ecommissio n ing Cost An aly si s Section 4, Page 6 of 6 FIGURE 4.3 DECOMMISSIONINGTIMELINE SAFSTOR (not to scale) Unit Shutdown END Period2 Period3 Period4 Period Site

                                                                                                       'l Dorrnarrcy                 Preparations   Decommissioning Restorat May2080    Nov2081 FuelPoolOoeration5Mar 2033 TLG Seruices, Inc.

Perry Nuclear Power Plant Docurnent F07-1699-001,Reu. 0 D ecomrni ssioning Cost An aly sis Section 5, Page 1 of 6

5. RADIOACTIVE WASTES The objectives of the decommissioningprocess 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 excessof applicable legal limits. Under the Atomic Energy {s1,[351thg NRC is responsiblefor protecting the public from sourcesof 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 burial are categofizedas Low SpecificActivity (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-1, IP-2 or IP-3, as defined in 10 CFR Part I73.4LI). For this study, commercially available steel containers are presumed to be used for the disposal of piping, small components, and concrete. Larger componentscan serve as their own containers,with proper closure of all openings, accessways, and penetrations. The destinations for the various waste streams from decommissioningare identified in Figures 5.1 and 5.2. The volumes are shown on a line-item basis in AppendicesC D and E, and summarizedin Tables 5.1 and 5.2. The volumes are calculatedbased on the exterior dimensions for containerized material and on the displacedvolume of componentsserving as their own waste containers. The reactor vessel and internals are categorizedas large quantity shipments and, accordingly,will be shipped in reusable,shieldedtruck caskswith disposableliners. In calculating disposalcosts,the burial fees are applied against the liner volume, as well as the specialhandling requirements of the payload. Packagingefficienciesare Iower for the highly activated materials (greater than Type A quantity waste), where high concentrations of gamma-emitting radionuclides limit the capacity of the shipping containers. No process system containing/handling radioactive substances at shutdown is presumed to meet material release criteria by decay alone (i.e., systemsradioactive at shutdown will still be radioactive over the time period during which the decommissioningis accomplished,due to the presenceof long-lived radionuclides). While the dose rates decrease with time, radionuclides such as 137Cswill still control the dispositionrequirements. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001.Reu. 0 D ecommissio ning Cost An aly si s Section 5, Page 2 of 6 The waste material produced in the decontamination and dismantling of the nuclear plants is primarily generatedduring Period 2 of DECON and Period 4 of SAFSTOR. Material that is considered potentially contaminated when removed from the radiologicalcontrolled area is sent to processingfacilities in Tennesseefor conditioning. Heavily contaminated componentsand activated materials are routed for controlled disposal. The disposal volumes reported in the tables reflect the savings resulting from reprocessingand recycling. For purposes of constructing the estimates, the current cost for disposal at EnergySolutions facility in Clive, Utah was used for a majority of the radioactive waste produced from the decommissioningactivities. A common rate was used for containerized waste and large components. Demolition debris including miscellaneoussteel, scaffolding, and concrete was disposedof at a bulk rate. The decommissioningwaste stream also included resins and dry active waste. Since EnergySolutionsis not currently able to receive the more highly radioactive components generated in the decontamination and dismantling of the reactor, disposal costs for the Class B and C material were based upon preliminary information from WCS on the cost at the Andrews Countv. Texas facilitv. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F0 7-1699-001, Reu. 0 D ecommissin n ing Cost An aly si s Section 5, Page 3 of 6 FIGURE 5.1 RADIOACTIVE WASTE DISPOSITION {ContafiinatedSoil and concrete) Reactor Waste (classA) i GeologicDisposal TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecomrnissioning Cost An alysis Section 5, Page 4 of 6 FIGURE 5.2 DE COMMISSIONINGWASTE DESTINATIONS RADIOLOGICAL Waste Control Specialists Andrews County, TX TLG Seruices, Inc,

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommissio ning Cost An aly sis Section 5, Page 5 of 6 DECor$t?lEEi,louu, DE COMMISSIONINGWASTE

SUMMARY

Waste Volume Weight Waste CostBasis class tu i- "Jqllbiq.fpet)-- j Low-LevelRadioactive EnergySolutions , Ai Containerized : rl' Waste (near-surface I 1 216,835 " 14,qq?,9eQ disposal) EnergySolutions , Al nl

                               ----""*F*slk--- . : ,.,*-.*"-***i l

_f,",)49_ _?,9*,Fq-? Bl W9"$ r ?,!4?i " ?q[,"?-ql C] WCS 1,066i 88,406 Greater than ClassC Spent Fuel (geologicrepository) GTCC 739 Equivalent 2.042 Total t2l 289,240 19,290,047 Processed/Conditioned Recycling A (qff-silg _re-cy,clin g center) Vendors 720.883 30,659,730 Scrap Metal 89,718,000 tU Waste is classified accordins to the requirements as delineated in Title 10 CFR,Part 61.55 Columns may not add due to rounding. TLG Seruices. Inc.

Perry Nuclear Power Plant Document F07-1699-001, Reu, 0 D ecommissioning Cost Analy sis Section 5, Page 6 of 6 IABLE 5.2 SAFSTORALTERNATIVE DE COMMISSIONING WASTE

SUMMARY

Waste Volume Weight Waste -classl!-i Low-Level Radioactive EnergStSolutions Waste (near-surface Al

                             *,_9--,q"ll!ea9-{r_zed_                              lQ,1_1.9,05,q disposal)                     Energ;'Solutions Al Bulk                            69.600         4"004.337 B:               a WCS                    ,          u92l           188.596 C

WCS 281 43.559 Greater than ClassC Spent Fuel (g"p qlqgrq qepoqilory) GTCC 2,042 398.739 Equivalent J6fal tzl 217,750 14,754,787 Processed/Conditioned Recycling (off-site recyclin g_,ce,nte A 795,L76 33,749,640 r) Vendors ScrapMetal 89,710,000 tll Waste is classified accordingto the requirements as delineated in Title 10 CFR,Part 61.55 l2l Columns may not add due to rounding. TLG Seruices.Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu, 0 D ecomrnissio ning Cost An aly si s Section 6, Page 1 of 5

6. RESULTS The analysis to estimate the costs to decommissionPerry relied upon the site-specific, technical information provided by FirstEnergy. While not an engineering study, the estimates provide the owner with sufficient information to assesstheir financial obligationsas they pertain to the eventual decommissioningof 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 decommissioningscenariosassume continued operation of the spent fuel pool for a minimum of seven years following the cessationof operationsfor continued coolingof the assemblies. The cost projected to promptly decommissionthe station (DECON), dismantle the structures, and manage the spent fuel is shown in Table 6.1. The majority of the cost (approximately 63.2%) is associatedwith the physical decontamination and dismantling of the nuclear plant so that the operating licensescan be terminated. Another 30.5o/o is associatedwith the management, interim storage, and eventual transfer of the spent fuel. The remaining 6.4% is for the demolition of the designatedstructures and limited restoration of the site. The cost projectedfor deferred decommissioning(SAFSTOR)is shown in Table 6.2. The majority of this cost (approximately 63.50/o) is associatedwith 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 31.0% is associated with the management, interim storage, and eventual transfer of the spent fuel. The remaining 5.5% is for the demolition of the designated structures and limited restorationof the site. The primary cost contributors, identified in Tables 6.1 and 6.2, are either labor-related or associatedwith the managementand disposition of the radioactivewaste. Program management is the largest single contributor to the overall cost. The magnitude of the expenseis a function of both the size of the organization required to manage the decommissioning, as well as the duration of the program. This analysis assumesthat FirstEnergy will overseethe decommissioningprogram using a DOC to manage the decommissioning labor force and the associated subcontractors.The size and composition of the management organization varies with the decommissioningphase and associatedsite activities. However, once the operating license is amended or terminated, the staff is substantially reduced for TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommi ssion ing Cost An aly sis Section 6, Page 2 of 5 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 pool will remain operational for a minimum of seven years following the cessation of operations. The pool will be isolated and an independent spent fuel island created. This will allow decommissioningoperations to proceedin and around the pool area. Over the seven year period, the spent fuel will be packaged into transportable canisters for relocation to the ISFSI. The cost for waste disposal includes only those costs associatedwith 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 describedin Section5, disposition of the majority of the low-level radioactive material requiring controlled disposal is at the Energy,Solutions'facility. Highly activated componentsrequiring additional isolation from the environment (GTCC) are packagedfor geologicdisposal.The cost of geologicdisposalis based upon a cost equivalent for spent fuel. A significant portion of the metallic waste is designated for additional processing and treatment at an off-site facility. Processing reduces the volume of material requiring controlled disposal through such techniques and processesas survey and sorting, decontamination, and volume reduction. The material that cannot be unconditionally released is packagedfor controlled disposal at one of the currently operating facilities. The cost identified in the summary tables for processingis all-inclusive, incorporating the ultimate disposition of the material. Removal costsreflect the labor-intensive nature of the decommissioningprocess,as well as the management controls required to ensure a safe and successfulprogram. Decontamination and packaging costs also have a large labor component that is based upon prevailing wages. Non-radiologicaldemolition is a natural extension of the decommissioning process. The methods employed in decontamination and dismantling are generally destructive and indiscriminate in inflicting collateral damage.With a work force mobilized to support decommissioningoperations, non-radiological demolition can be an integrated activity and a logical expansion of the work being performed in the processof terminating the operating licenses. The reported cost for transport includes the tariffs and surchargesassociatedwith moving large componentsand/or overweight shielded casks overland, as well as the general expense,i.e., labor and fuel, of transporting material to the destinations identified in this report. For purposesof this analysis, material is primarily moved overland by truck. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommissioning Cost Analy sis Section 6, Page 3 of 5 Decontaminationis used to reducethe plant's radiation fields and minimize worker exposure.Slightly contaminated material or material locatedwithin a contaminated area is sent to an off-site processingcenter; this analysis does not assume that contaminated plant components and equipment can be decontaminated for uncontrolled release in-situ. Centralized processing centers have proven to be a more economicalmeans of handling the large volumes of material produced in the dismantling of a nuclear plant. License termination survey costs are associated with the labor intensive and complexactivity of verifying that contamination has been removed from the site to the levels specified by the regulating agency. This processinvolves 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 componentsand materials not removed in the decommissioningprocess will also require confirmation and will add to the expenseof surveying the facilities alone. The remaining costs include allocations for heavy equipment and temporary services,as well as for other expensessuch as regulatory fees and the premiums for nuclear insurance. While site operating costs are greatly reduced following the final cessationof plant operations, certain administrative functions do need to be maintained either at a basic functional or regulatory level. TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecornrni ssioning Cost An aly sis Section 6, Page 4 of 5 TABLE 6.1 DECONALTERNATIVE DECOMMISSIONINGCOSTELEMENTS (thousands of 2014dollars) 9osl Total

                                                                 -ti,ses Decontamination                                   1-*-*                      1.5 Removal                                                                    14.0 Baql.esl+-                                                                  -2,9 Transportatiq!*_                                                             L.4 Waste Disposal Off- site Waste Processi_n    g*_*...                     90,262             6.5 u M++esen"en!-      !11                         295,597           2I.3 167,115           L2.0 nt Fuel Pool Isolation                               12.434             0.9 nt Fuel Managemsnf [21 Insurance and Regulato.r.yFeeS .*              --

E{tsrgx."" ","""" . " " " """""" ."""" Characterization and Licensi Surve MiscellaneousEquipment LicenseTermilaton FqelMpnegeueql Site Restoration t1l Includes engineering costs l2l Excludesprogram managementcosts(staffing) but includes costsfor spent fuel loading/transfer costs/spentfuel pool O&M and EP fees t31 Columns may not add due to rounding TLG Services, Inc.

Perry Nuclear Power Plant Document F07-1699001,Rev. 0 D ecommissin ning Cost Analysis Section 6, Page 5 of 5 TABLE 6.2 SAFSTORALTERNATIVE DECOMMISSIOMNGCOSTELEMENTS (thousands of 2014dollars) Cost.ple_ment ..-, - . , - _Jq!cl*"""-j-"---P-9-ryscJ-rIesg l Decontamination --*--^*--?q,_631l 1.8 R;;";ul-* lqe,_qe7i -- 1L4 25,602i_ 1,0_ Trerr"gppr!allol]-.-*--,- _*--:l?",gffi ^- "- * ' ,8- {qp!e Qiq.pssa"l j-Ee,_3_42 !'? 9_ff:s:L*WeplePrscgsp_irr_s - 99,359i --"-- g'q Program Managemsnf t11 36&e01I 22.2 Securit 230.193 13.9 Spent Fuel Pool Isolation t2.434 0.8

       $p-e_nt FueI Managemsnfi [21                             222,605            13.4 Insurance and Regulatory Fees                            85.077              5.1 Ene,rgy                                                  40.52r              2.4 Characterization and Licensing Survevs                                                  29.338              1.8 Ppagrly Taxes                                           150,807              9.1
       -\4iqgsllane-ousE qurpment                                29,289              1.8 Cqlp-orate,G&A                                           63.644              3.8 Total tsl                                              1.660.404           100.0 1.054.131
            +14gel"Me$ese*ry-elj" Site Restoration                                         91,735t             5.5 tu Includes engineeringcosts t21 Excludesprogram managementcosts(staffing) but includes costsfor spent fuel loading/transfer costs/spentfuel pool O&M and EP fees l3l Columns may not add due to rounding TLG Seruices. Inc.

Perry Nuclear Power Plant Docurnent F07-1699-001, Reu. 0 D ecommissioning Cost An alysis Section 7, Page 1 of 3

7. REFERENCES

1. "Decommissioning Cost Analysis for the Perry Nuclear Power Plant," TLG ServicesDocumentNo. F07-1619-003,Rev. 1, December2014

2. IJ.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, L988

3. U.S. Nuclear Regulatory Commission,RegulatoryGuide 1.159,"Assuring the Availability of Funds for DecommissioningNuclear Reactors," Rev. 2, October 20TL

4. U.S. Code of Federal Regulations, Title 10, Part 20, Subpart E, "Radiological Criteria for LicenseTermination" 5 . U.S. Code of Federal Regulations, Title 10, Parts 20 and 50, "Entombment Options for Power Reactors,"Advanced Notice of ProposedRulemaking, 66 Fed.

Reg.52551,October16,2001

6. 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

7. U.S. Code of Federal Regulations,Title 10, Parts 20, 30, 40, 50, 70, and 72, "Decommissioning Planning," Nuclear Regulatory Commission, Federal RegisterVolume 76, (p 35512et seq.),June 17,20LL 8 . "Nuclear Waste Policy Act of 1982," 42 U.S. Code 10101, et seq.

http :/lpbadunws.nrc.eov/docsfMll327lML132744489.pdf#paee=4 19.

9. United States Court of Appeals for the District Of Columbia Circuit, In Re:

Aiken County, Et Al., August 20L3, http://www.cadc.uscourts.gov/internet/opinions.nsflBAE0CF34F762EBD9B5257 BC6004DEB18/$filei11-1271-1451347.pdf

10. Charter of the Blue Ribbon Commission on America's Nuclear Future.

     "Objectivesand Scopeof Activities,"

http ://www.brc.gov/index.php?q=paee/charter 1 1 . "Blue Ribbon Commissionon America's Nuclear Future, Report to the Secretary of Energy," http:/lwww.brc.gov/,p. 32, January 2012 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommissioning Cost Analysis Section 7, Page 2 of 3

7. REFERENCES (continued)

12. "Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level RadioactiveWaste,"U.S. DOE, January 11, 2013 1 3 ."AcceptancePriority Ranking & Annual Capacity Report," DOE/RW-0567,2004 L4. U.S. Code of Federal Regulations,Title 10, Part 50, "Domestic Licensing of Production and Utilization Facilities," Subpart 54 (bb), "Conditions of Licenses" 1 5 . U.S. Code of Federal Regulations,Title 10, Part 72.40 Subpart K, "General Licensefor Storageof Spent Fuel at Power Reactor Sites" 1 6 . "Low Level RadioactiveWaste Policy Act," Public Law 96-573,1980 r7. "Low-Level RadioactiveWaste Policv Amendments Act of 1985."Public Law 99-240. 1986 1 8 . U.S. Codeof Federal Regulations,Title 10, Part 61.55 "Waste Classification" 1 9 . U.S. Code of Federal Regulations, Title 10, Part 20, Subpart E, "Final RuIe, Radiological Criteria for License Termination," 62 Fed. Reg. 39058, July 21, 1997

20. "Establishment of Cleanup Levels for CERCIA Sites with Radioactive Contamination,"EPA MemorandumOSWERNo. 9200.4-18,August22, L997 2r.U.S. Code of Federal Regulations, Title 40, Part 141.16, "Maximum contaminant levels for beta particle and photon radioactivity from man-made radionuclidesin community water systems"

22. "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,October9, 2002

23. "Multi-Agency Radiation Survey and Site Investigation Manual O4ARSSIM),"

NUREG/CR-1575,Rev. 1, EPA 402-R-97-016, Rev. 1, August 2000

24. T.S. LaGuardia et al., "Guidelines for Producing Commercial Nuclear Power Plant DecommissioningCost Estimates,"AIF/NESP-036,May 1986 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecom.missioning Cost An aly si s Section 7, Page 3 of 3

7. REFERENCES (continued)

25. W.J. Manion and T.S. LaGuardia, "Decommissioning Handbook," U.S.

Departmentof Energy, DOE/EV/10128-1, November1980

26. "Building Construction Cost Data 2014," Robert Snow Means Company, Inc.,

Kingston, Massachusetts

27. Project and Cost Engineers' Handbook, Second Edition, p. 239, American Associationof Cost Engineers,Marcel Dekker, Inc., New York, New York, 1984

28. U.S. Department of Transportation, Title 49 of the Codeof Federal Regulations, "Transportation,"Parts 173 through 178

29. Tri-State Motor Transit Company, published tariffs, Interstate Commerce Commission (ICC), Docket No. MC-4277L9 Rules Tariff, March 2004, RadioactiveMaterials Tariff, August 2011

30. J.C. Evans et al., "Long-Lived Activation Products in Reactor Materials" NUREG/CR-3474, Pacific Northwest Laboratory for the Nuclear Regulatory Commission,August 1984 3 1 . 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-0130and addenda. Pacific Northwest Laboratorv for the Nuclear Regulatory Commission,June 1978

32. H.D. Oak, et al., "Technolory, Safety and Costs of Decommissioninga Reference Boiling Water Reactor Power Station," NUREG/CR-0672and addenda, Pacific Northwest Laboratory for the Nuclear Regulatory Commission,June 1980

33. SECY-00-0145, "Integrated Rulemaking Plan for Nuclear Power Plant Decommissioning,"June 200O."MicrosoftProject Professional 2010," Microsoft Corporation, Redmond,WA

34. "Microsoft Project Professional2013," Microsoft Corporation,Redmond,WA

35. "Atomic Energy Act of L954,"(68 Stat. 919)

TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07- 1699-001, Reu. 0 D ecommissioning Cost Analysis AppendixA,Page 1of4 APPENDD(A UNIT COSTFACTOR DEVELOPMENT TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommissio n ing Cost An aly si s Append.ix A, Page 2 of 4 APPENDD(A UNIT COSTFACTOR DEVELOPMENT Example: Unit Factorfor Removalof Contaminated HeatExchanger< 3,000lbs.

1. SCOPE Heat exchangersweighing < 3,000 lbs. will be removedin one piece using a crane or small hoist. They will be disconnectedfrom the inlet and outlet piping. The heat exchangerwill be sent to the waste processingarea.

2. CALCULATIONS Activity Critical Act Activity Duration Duration ID Description (minutes) (minutes)*

a Removeinsulation 60 (b) b Mount pipe cutters 60 60 c Install contamination controls 20 (b) d Disconnectinlet and outlet lines 60 60 e Cap openings 20 (d) f Rig for removal 30 30 o b Unbolt from mounts 30 30 h Removecontamination controls 15 15 i Remove,wrap, sendto waste processingarea 60 60 Totals (Activity/Critical) 355 255 Duration adjustment(s):

 + Respiratory protection adjustment (50%of critical duration)                              L28
 + Radiatior/AIARA. adjustment (37.Io/oof critical duration)                                  95 Adjusted work duration                                                                       478

Protective clothing adjustment (30o/o of adjusted duration) r43 Productive work duration 62r

 + Work break adjustment (8.33% of productiveduration)                                        52 Total work duration (minutes)                                                                673
                            *# Total duration = lL.2I7 hr #*

alpha designators indicate activities that can be performed in parallel TLG Sentices, Inc.

Perry Nuclear Power Plant Document F07-1699-001, Reu. 0 D ecomrnissioning Cost Analysis Appendix A, Page 3 of 4 APPENDD(A (continued)

3. LABOR REQUIRED Duration Rate Crew Number (hours) ($/hr) Cost Laborers 3.00 II.217 $48.07 $1,617.60 Craftsmen 2.00 IL.2I7 $57.94 $1,299.83 Foreman 1.00 rr.2t7 $62.1e $697.59 GeneralForeman 0.25 II.2I7 $65.66 $184.13 Fire Watch 0.05 lt.217 $48.07 $26.96 Health Physics Technician 1.00 rt.2r7 $48.36 $542.45 Total Labor Cost $4,368.56

4. EQUTPMENT & CONSUTVTABLES COSTS Equipment Costs none Consumables/lVlaterialsCosts

-universal sorbent 50 @$0'52 sq' ft' tt)                                   $26.00
-Tarpaulins (7.5mils, oil resistant, fire retardant) 50 @$0.39/sq.ft.l2l   $19.50
-Gastorch consumables1@ $9.57lhr.x t hr. {s}                                 $9.57 Subtotal cost of equipment and materials                                     $55.07 Overhead& profit on equipment and materials @ 17.00%                          $9.36 Total costs,equipment & material                                             $64.43 TOTAL COST:

Removal of contaminated heat exchanger <3000 pounds: $4,432.99 Total labor cost: $4,368.56 Total equipment/materialcosts: $64.43 Total craft labor man-hoursrequired per unit: 81.88 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001, Reu. 0 D ecommis sioning Cost Analy si s Appendix A, Page 4 of 4 A.PPENDXA (continued)

5. NOTESAND REFERENCES Work difficulty factors were developed in conjunction with the Atomic Industrial Forum's (now NEI) program to standardizenuclear decommissioning cost estimatesand are delineatedin Volume 1, Chapter 5 of the "Guidelinesfor ProducingCommercialNuclear PowerPlant DecommissioningCost Estimates,"

AIF/NESP-036,May 1986. Referencesfor equipment & consumablescosts:

1. www.mcmaster.comonline catalog,McMaster Carr Spill Control (71e3T88)

2. R.S.Means (201a)Division 01 56, Section13.60-0600,page23

3. R.S.Means (201a)Division 01 54 33, Section40-6360,page698 Material and consumable costs were adjusted using the regional indices for Cleveland.Ohio.

TLG Seruices,Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommissioning Cost Analysis Append,ix B, Page 1 of 7 APPENDX B UNIT COSTFACTOR LISTING (DECON:Power Block Structures Only) TLG Services, Inc.

Perry Nuclear Power Plant Document F07-1699-001, Reu. 0 D ecom.missioning Cost An aly si s Appendix B, Page 2 of 7 APPENDD( B UNIT COSTFACTOR LISTING (Power Block Structures Only) Unit Cost Factor Cost/Unit($) Removalof clean instrument and sampling tubing, $/linear foot 0.52 Removalof cleanpipe 0.25 to 2 inchesdiameter, g/linear foot 5.56 Removalof cleanpipe >2 to 4 inchesdiameter,$/linear foot 7.87 Removalof cleanpipe >4 to 8 inchesdiameter,g/linear foot 15.09 Removalof cleanpipe >8 to 14 inchesdiameter, $/linear foot 29.35 Removalof cleanpipe >14 to 20 inchesdiameter, $Ainearfoot 38.08 Removalof cleanpipe >20 to 36 inchesdiameter, $Ainearfoot 56.05 Removalof clean pipe >36 inches diameter, $llinear foot 66.63 Removalof cleanvalve >2to 4 inches 101.00 Removalof cleanvalve >4to 8 inches 150.92 Removalof clean valve >8 to 14 inches 293.54 Removalof cleanvalve >I4to 20 inches 380.79 Removalof clean valve >20 to 36 inches 560.46 Removalof clean valve >36 inches 666.29 Removalof clean pipe hanger for small bore piping 33.16 Removalof cleanpipe hanger for large bore piping r 21. 77 Removalof cleanpump, <300 pound 252.74 Removalof cleanpump, 300-1000pound 696.84 Removalof cleanpump, 1000-10,000pound 2,775.67 Removalof cleanpump, >10,000pound 5,361.78 Removalof cleanpump motor, 300-1000pound 293.30 Removalof cleanpump motor, 1000-10,000 pound 1,L56.23 Removalof cleanpump motor, >10,000pound 2,601.53 Removalof cleanheat exchanger<3000pound 1,489.18 Removalof cleanheat exchanger>3000pound 3,739.91 Removalof cleanfeedwaterheater/deaerator 10,551.92 Removalof clean moisture separator/reheater 2r,705.99 Removalof cleantank, <300 gallons 325.31 Removalof cleantank, 300-3000gallon 1,029.29 Removalof cleantank, >3000 gallons,$/squarefoot surfacearea 8. 52 TLG Seruices, Inc.

Perry Nuclear Pouter Plant Document F07-1699-001,Reu. 0 D ecommissioning Cost Analysis Appendix B, Page 3 of 7 APPENDD( B UNIT COSTFACTOR LISTING (Power Block Structures Only) Unit Cost Factor Cost/Unit($) Removalof cleanelectricalequipment,<300 pound 138.65 Removalof clean electricalequipment,300-1000pound 477.51 Removalof clean electricalequipment,1000-10,000pound 955.02 Removalof cleanelectricalequipment,>10,000pound 2,266.87 Removalof cleanelectricaltransformer < 30 tons r,574.31 Removalof clean electrical transformer > 30 tons 4,533.74 Removalof clean standby dieselgenerator,<100 kW 1,608.02 Removalof clean standbydieselgenerator,100kW to 1MW 3,589.23 Removalof clean standby dieselgenerator,>1 MW 7,430.40 Removalof clean electrical cabletray, $/linear foot L2.9L Removalof clean electrical conduit. Sllinear foot 5.63 Removalof clean mechanicalequipment,<300 pound 138.65 Removalof clean mechanicalequipment,300-1000pound 477.51 Removalof cleanmechanicalequipment,1000-10,000pound 955.02 Removalof cleanmechanicalequipment,>10,000pound 2,266.87 Removalof clean HVAC equipment, <300 pound 167.66 Removalof cleanHVAC equipment,300-1000pound 573.77 Removalof cleanHVAC equipment,1000-10,000pound 1,143 .51 Removalof cleanHVAC equipment,>10,000pound 2,266.87 Removalof clean HVAC ductwork, g/pound 0.55 Removalof contaminated instrument and sampling tubing, $/linear foot 1.58 Removalof contaminatedpipe 0.25 to 2 inchesdiameter,gllinear foot 22.45 Removalof contaminated pipe >2 to 4 inches diameter, $/linear foot 38.32 Removalof contaminatedpipe >4 to 8 inchesdiameter,$/Iinearfoot 59.84 Removalof contaminatedpipe >8 to 14 inchesdiameter,$llinear foot 117.90 Removalof contaminatedpipe >14 to 20 inchesdiameter,$llinear foot r4L.46 Removalof contaminatedpipe >20 to 36 inchesdiameter,$Ainearfoot 195.61 Removalof contaminatedpipe >36 inches diameter, $/linear foot 231.15 Removalof contaminated valve >2 to 4 inches 455.65 Removalof contaminatedvalve >4to 8 inches 544.24 TLG Seruices.Inc.

Perry Nuclear Power Plant Document F07-1699-001,Reu. 0 D ecommi ssioning Cost An aly sis Appendix B, Page 4 of 7 APPENDX B UNIT COSTFACTOR LISTING (Power Block Structures Only) Unit Cost Factor Cost/Unit($) Removalof contaminatedvalve >8 to 14 inches L,125.73 Removalof contaminatedvalve >I4to 20 inches r,429.46 Removal of contaminatedvalve >20 to 36 inches 1,902.90 Removalof contaminatedvalve >36 inches 2,258.24 Removalof contaminatedpipe hanger for small bore piping L48.45 Removalof contaminated pipe hanger for large bore piping 499.70 Removalof contaminatedpump, <300 pound 969.30 Removalof contaminatedpump, 300-1000pound 2,233.66 Removalof contaminatedpump, 1000-10,000pound 7,335.16 Removalof contaminatedpump, >10,000pound 17,862.27 Removalof contaminatedpump motor, 300-1000pound 955.46 Removalof contaminatedpump motor, 1000-10,000pound 2,990.91 Removalof contaminatedpump motor, >10,000pound 6,7t4.98 Removal of contaminated heat exchanger<3000 pound 4,432.99 Removal of contaminated heat exchanger>3000 pound L2,852.96 Removalof contaminated feedwater heater/deaerator 31,528.11 Removalof contaminated moisture separator/reheater 68,947.82 Removalof contaminated tank, <300 gallons 1,613.55 Removalof contaminated tank, >300 gallons, $/squarefoot 3r.24 Removalof contaminated electrical equipment, <300 pound 752.83 Removalof contaminatedelectricalequipment,300-1000pound 1,823.66 Removalof contaminatedelectricalequipment, 1000-10,000 pound 3,512.74 Removalof contaminatedelectricalequipment,>10,000pound 6,894.97 Removalof contaminated electrical cable tray, $/linear foot 36.29 Removalof contaminated electrical conduit. $/linear foot 17.83 Removalof contaminatedmechanicalequipment,<300 pound 837.45 Removalof contaminatedmechanicalequipment,300-1000pound 2,013.64 Removalof contaminatedmechanicalequipment, 1000-10,000pound 3,872.36 Removalof contaminatedmechanicalequipment,>10,000pound 6,894.97 Removalof contaminatedHVAC equipment,<300pound 837.45 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-001, Reu. 0 D ecomrni ssioning Cost An aly si s AppendixB, Page 5 of 7 APPENDX B UNIT COSTFACTORLISTING (Power Block Structures Only) Unit Cost Factor Cost/Unit($) Removalof contaminatedHVAC equipment,300-1000pound 2,013.64 Removalof contaminatedHVAC equipment,1000-10,000 pound 3,872.36 Removalof contaminatedHVAC equipment,>10,000pound 6,894.97 Removal of contaminatedI{VAC ductwork, $/pound 2.L8 RemovaUplasmaarc cut of contaminated thin metal components,$Ainearin. 4.02 Additional decontaminationof surface by washing, g/squarefoot 8.49 Additional decontaminationof surfacesby hydrolasing, $/squarefoot 34.96 Decontamination rig hook up and flush, $/ 250 foot length 7,054.77 Chemical flush of components/systems,$/gallon 15.88 Removal of clean standard reinforced concrete,$/cubicyard L42.84 Removal of grade slab concrete,$/cubicyard 191 .31 Removal of clean concretefloors, $/cubicyard 37L.46 Removal of sectionsof clean concretefloors, $/cubicyard 1,098.13 Removal of clean heavily rein concretewl#9 rebar, $/cubicyard 245.84 Removal of contaminated heavily rein concretewl#9 rebar, $/cubicyard 2,178.79 Removal of clean heavily rein concretew#18 rebar, $/cubicyard 310.84 Removal of contaminated heavily rein concretewA#18rebar, $/cubicyard 2,881.56 Removal heavily rein concretewl#18 rebar & steel embedments,$/cubicyard 469.63 Removal of below-gradesuspendedfloors, $/cubicyard 37L.46 Removal of clean monolithic concretestructures. $/cubicyard 927.92 Removal of contaminated monolithic concretestructures, $/cubicyard 2,169.02 Removal of clean foundation concrete,$/cubicyard 728.03 Removal of contaminated foundation concrete,$/cubicyard 2,020.67 Explosive demolition of bulk concrete,g/cubicyard 3r.26 Removal of clean hollow masonry block wall, $/cubicyard 107.03 Removal of contaminated hollow masonry block wall, $/cubicyard 344.79 Removal of clean solid masonry block wall, $/cubicyard 107.03 Removal of contaminated solid masonry block waII, $/cubicyard 344.79 Backfill of below-gradevoids, g/cubicyard 23.O4 Removalof subterraneantunnels/voids.$/linearfoot 120.23 TLG Seruices. Inc.

Perry Nuclear Power Plant Document F07-1699-001,Rev. 0 Decommissioning Cost Analysis Appendix B, Page 6 of 7 APPENDX B UNIT COSTFACTORLISTING (Power Block Structures Only) Unit Cost Factor Cost/Unit($) Placement of concretefor below-gradevoids, $/cubicyard I24.20 Excavation of clean material, $/cubicyard 3.07 Excavation of contaminated material, $/cubicyard 42.3r Removal of clean concreterubble (tipping fee included), g/cubicyard 23.82 Removal of contaminated concreterubble, $/cubicyard 27.r2 Removal of building by volume, g/cubicfoot 0.32 Removal of clean building metal siding, g/squarefoot 7.23 Removal of contaminatedbuilding metal siding, g/squarefoot 4.L7 Removal of standard asphalt roofing, $/squarefoot 2.43 Removal of transite panels, $/squarefoot 2.24 Scarifiting contaminated concretesurfaces(drill & spall), $/squarefoot L2.92 Scabblingcontaminated concretefloors, $/squarefoot 8.13 Scabblingcontaminated concretewalls, $/squarefoot 2r.60 Scabblingcontaminated ceilings, $/squarefoot 74.23 Scabblingstructural steel, $/squarefoot 6.44 Removal of clean overheadcrane/monorail< 10 ton capacity 660.57 Removal of contaminated overheadcrane/monorail< 10 ton capacity 1,836.76 Removal of clean overheadcrane/monorail>10-50ton capacity 1,585.37 Removal of contaminated overheadcrane/monorail>10-50 ton capacity 4,407.49 Removal of polar crane > 50 ton capacity 6,62r.75 Removal of gantry crane > 50 ton capacity 28,335.93 Removalof structural steel,$/pound 0.2r Removal of clean steel floor grating, $/squarefoot 4.58 Removal of contaminated steel floor grating, $/squarefoot 13.19 Removal of clean free standing steel liner, $/squarefoot r2.78 Removal of contaminated free standing steel liner, $/squarefoot 36.57 Removalof cleanconcrete-anchored steelliner, $/squarefoot 6.39 Removalof contaminatedconcrete-anchored steelliner, $/squarefoot 42.59 Placementof scaffoldingin clean areas,g/squarefoot 16.99 Placementof scaffoldingin contaminatedareas,$/squarefoot 27.52 TLG Seruices, Inc.

Perry Nuclear Power Plant Document F07-1699-A0\ Reu. 0 D ecommissio ning Cost An aly si s Appendix B, Page 7 of 7 APPENDD( B UNIT COSTFACTOR LISTING (Power Block Structures Only) Unit Cost Faetor Cost/Unit($) Landscapingwith topsoil, g/acre 25,510.L2 Costof CPCB-88 LSA box & preparationfor use 2,050.26 Costof CPCB-25 LSA box & preparationfor use r,878.29 Costof CPCB-12V 12 gaugeLSA box & preparationfor use L,529.63 Costof CPC8-144 LSA box & preparationfor use 8,924.2r Cost of LSA drum & preparation for use 198.48 Costof caskliner for CNSI 8 120,4.cask (resins) 7,296.67 Cost of cask liner for CNSI S 1204.cask (frlters) 7,979.85 Decontaminationof surfaceswith vacuuming, $/squarefoot 0.80 TLG Services, Inc.

Perry Nuclear Power Plant Document F07-1699007,Reu. 0 D ecommissioning Cost Analysis Appendix C, Pa,ge I of 12 APPENDX C DETAILED COST ANALYSF DECON TLG Serviceq Inc.

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L-15-101, Submittal of the Decommissioning Funding Status Reports for Beaver Valley, Units 1 and 2, Davis-Besse and Perry, Unit 1

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L-15-101, Submittal of the Decommissioning Funding Status Reports for Beaver Valley, Units 1 and 2, Davis-Besse and Perry, Unit 1

Text

SUBJECT:

Enclosures:

References:

References:

SUMMARY

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SUMMARY

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