Text

Decommissioning Study, Revision 0
	ML18341A134
Person / Time
Site:	Cook, 07200072
Issue date:	01/21/2016
From:	; Knight Cost Engineering Services
To:	; Indiana Michigan Power Co, Office of Nuclear Material Safety and Safeguards, Office of Nuclear Reactor Regulation
References
	AEP-NRC-2018-71 KCES 2016-100, Rev 0
	Download: ML18341A134 (51)
	v • d • e

ENCLOSURE 2 TO AEP-NRC-2018-71 Decommissioning Study of the D.C. Cook Nuclear Power Plant conducted by Knight Cost Engineering Services, LLC, dated January 21, 2016, Revision 0

Decommissioning Study of the D. C. Cook Nuclear Power Plant Prepared for Indiana Michigan Power Company Knight Cost Engineering Services, LLC January 21, 2016 Revision 0

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 TABLE OF CONTENTS

1.0 INTRODUCTION

3 1.1 DONALD C. COOK UNITS 1 AND 2 PLANT SITE 3

1.2 OVERVIEW OF THE SCENARIO 3

2.0

SUMMARY

5 2.1 DECOMMISSIONING ALTERNATIVES 5

3.0 DECOMMISSIONING COST ESTIMATING METHODOLOGIES 7

3.1 DECON 7

3.2 SPENT FUEL ACTIVITIES 8

3.3 DECOMMISSIONING MANAGEMENT 9

3.4 COLD&DARK 9

3:5 DECONTAMINATION PROCEDURES 10 3.6 CONTINGENCY 11 4.0 ASSUMPTIONS 14 5.0 SCENARIO DESCRIPTION 17 5.1 DECON WITH INDEFINITE ON-SITE DRY STORAGE 17 6.0 SCHEDULES 19 6.1 DECON WITH ON-SITE DRY STORAGE AND NO SPENT FUEL SHIPPING 19 7.0 PROJECT MANAGEMENT 22 7.1 UTILITY STAFF 22 7.2 DECOMMISSIONING GENERAL CONTRACTOR 23 7.3 SECURITY 23 7.4 DECON WITH INDEFINITE DRY STORAGE 23 8.0 WASTE DISPOSAL 25 8.1 LOW LEVEL WASTE DISPOSAL BACKGROUND 25 8.2 CLASS A WASTE DISPOSAL 25 8.3 CLASS B & C WASTE DISPOSAL 26 8.4 DISPOSAL OF WASTES GREATER THAN CLASS C 27 8.5 RADIOACTIVE WASTE VOLUMES PER 10 CFR61 CLASSIFICATIONS 27 8.6 PROJECTION OF NON-RADIOACTIVE WASTE QUANTITIES 28 9.0 COST SUMMARIES 29 9.1.

ESTIMATING APPROACH 29 9.2 DECON WITH INDEFINITE ON-SITE DRY STORAGE 30

10.0 REFERENCES

32 Page 2 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0

1.0 INTRODUCTION

1.1 DONALD C. COOK UNITS 1 AND 2 PLANT SITE The Donald C. Cook Nuclear Power Plant (D.C. Cook Plant) is a nuclear-powered electrical generating facility located in Bridgman, Michigan. D.C. Cook Plant consists of two pressurized water reactors (PWR). Its electrical rating is 1084 MWe for reactor Unit 1 and 1107 MWe for reactor Unit 2.

D.C. Cook Plant has been granted a twenty-year license extension by the Nuclear Regulatory Commission (NRC).

Based on the terms of this extension, Unit 1 is scheduled for shutdown on October 25, 2034; Unit 2 is scheduled for shutdown on December 23, 203 7. Units 1 & 2 are planned to be decommissioned in series following shut down.

This study is an update of the 2012 site-specific Decommissioning Cost Estimate of the D.C.

Cook Nuclear Power Plant, Units 1 & 2, prepared for the Indiana Michigan Power Company (the Company). As such, it reflects site-specific plant information and cost factors. The most current decommissioning experience and logic have been incorporated into this estimate, including spent fuel acceptance

rates, spent fuel storage

issues, decommissioning methodologies, decommissioning management and waste disposal.

1.2 OVERVIEW OF THE SCENARIO This study consists of one decommissioning scenario. This scenario includes the cost for the immediate decommissioning of the site (DECON), on-site storage of spent fuel, and clean removal. In addition, it includes the cost for the removal of the Independent Spent Fuel Storage Installation (ISFSI).

The cost estimate contained herein was developed based on a May 2015 configuration. It utilizes site-specific plant systems and building inventory recently generated based on current site.

configuration, drawings and component database. Costs have been determined for removal, packaging, transportation and disposal.

The decommissioning activities contained herein were previously developed and have been modified as required, with costs determined for each activity. The critical path schedule was previously developed and has been modified based on new spent fuel discharge assumptions and new and modified task durations. Period-dependent costs include utility staff, decommissioning general contractor staff, security, insurance, energy and others. Cost levels were determined based on specific periods or groups of activities per the schedule. Total period dependent costs were determined by the scenario-specific durations. Activity and period dependent costs were totaled to determine overall costs for each scenario.

The purpose of this study is to provide one cost estimate based the actual spent fuel storage conditions. The costs presented are for financial planning. All costs are in summer, 2015 dollars.

All costs are based on the aforementioned spent fuel shipping and storage assumptions.

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Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 Utilizing the above.estimating methodology, the cost for this scenario is $1,634,038,400. In addition there will be an annual cost of $4,912,700 per year of post decommissioning spent fuel storage and $56,952,300 for the eventual decommissioning of the ISFSI.

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Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 2.0

SUMMARY

Decommissioning is the safe removal of a facility or site from service and the reduction of radioactivity to a level that permits either the release of the property for unrestricted use and NRC license termination; or a restricted release of the property and NRC license termination.

2.1 DECO:M:MISSIONING ALTERNATIVES The NRC allows three types of scenarios in estimating the decommissioning of a nuclear site, DECON, SAFSTOR and ENTOMB.

The first, DECON, occurs soon after shutdown.

It assumes that all systems, structures and contaminated site areas will be removed or decontaminated and that the facility's license will be terminated.

For the second alternative, SAFSTOR, preparations occur soon after shutdown. It assumes limited site decontamination and dismantlement; that all liquid will be drained from systems; that the facility will be placed in a safe and stable condition; that all spent fuel will be held in storage or shipped from the site; and that the site will be decontaminated and its license terminated within sixty years. This study does not consider the SAFSTOR scenario.

In the third alternative, ENTOMB, preparations occur soon after shutdown. It assumes limited site decontamination and dismantlement; that all liquid will be drained from systems; that the remaining radioactive systems and structures will be encased inside an entombment structure; that the facility will be continuously monitored; that spent fuel will be held in storage or shipped from the site; that the site will be decontaminated and license terminated within 60 years; and that most reactors will have radionuclides in concentrations exceeding the limits for unrestricted release after 100 years. This study does not consider the ENTOMB scenario.

Per NRC regulations, there are specific reporting requirements for decommissioning and spent fuel storage. Regulation 10 CPR 50. 75, Reporting and Recordkeeping for Decommissioning Planning, requires a decommissioning report certifying that financial assurance will be available for decommissioning. The amount funded must be adjusted annually. A report on the status of funding must be submitted every two years. Costs not associated with decommissioning, such as spent fuel storage and clean removal costs, are specifically excluded.

Five years before license expiration or within 2 years after permanent shutdown, whichever occurs first, NRC regulation 10 CPR 50.54(bb) requires the licensee have a program to manage and provide funding for the management of spent fuel following permanent cessation until title to and possession of all of its spent fuel is transferred to the Department of Energy (DOE) for ultimate disposal in a repository. The licensee must demonstrate the actions will be consistent with NRC requirements and will be implemented on a timely basis according to these requirements.

On June 17, 2011, the NRC published a final rule amending its regulations to improve decommissioning planning. The rule became effective on December 1 7, 2012 and required Page 5 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 compliance by March 31, 2013. This rule requires licensees to report additional details in their decommissioning cost estimate. To assist in the implementation of the new rule, the NRC revised NUREG-1757, "Consolidated Decommissioning Guidance, Financial Assurance, Recordkeeping and Timeliness," specifically volume 3. This volume applies to the timeliness and recordkeeping requirements for licensees under Title 10 of the Code of Federal Regulations (10 CFR) Parts 30, 40, 70, and 72. It also applies to financial assurance requirements for licensees under 10 CFR Parts 30, 40, 70, and 72. This volume does not apply to licensees under 10 CFR Part 50, "Domestic Licensing of Production and Utilization Facilities." Regulatory Guide 1.159, Revision 1, "Assuring the Availability of Funds for Decommissioning Nuclear Reactors," issued October 2003, provides guidance on financial assurance for these licensees.

While the final rule applies to reactor licensees, like Cook, the guidance of NUREG-1757 is not directly applicable but does provide additional information useful in the development of this cost estimate.

While none of the above NRC regulations require Greenfield or clean system and structure removal costs, these costs may be required by local authorities to minimize liability. Removal of clean systems and structures may also be required to access contaminated components and structures. Therefore, Greenfield costs have been included in this study.

Table 2-1 provides a summary of the costs for this scenario. Costs are separated into the three cost categories based on the aforementioned spent fuel shipping and storage assumptions and have been determined based on the described estimating methodology.

TABLE2-1

SUMMARY

OF COSTS DECON, Indefinite On-Site Drv Stora2e and Modified Spent Fuel Pool Systems Decommissioning Fuel Storage and Dormancy Delayed Total Program Cost Alternative Decommissioning Period Cost Dismantling Cost Cost 10 CPR 50.75(c)

$909,101,862 NIA NIA

$909,101,862 10 CPR 50.54(bb)

$529,465,643 NIA NIA

$529,465,643 Greenfield

$195,470,882 NIA NIA

$195,470,882 total:

$1,634,038,387 Annual ISPSI

$4,912,735 per year

$4,912,735 per vear ISPSI

$56,952,278

$56,952,278 Decommissioning Page 6 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 3.0 DECOMMISSIONING COST ESTIMATING METHODOLOGIES 3.1 DECON There are typically six periods associated with the DECON methodology of decommissioning cost estimating. Period one consists of decommissioning planning prior to shutdown. Period two involves post-shutdown preparations, including isolation of spent fuel; decontamination of the primary system; flushing and draining of all systems; implementation of cold and dark; and characterization surveys. Period three consists of removal of reactor internals and removal of the reactor vessel. The critical path task for period three is the removal, packaging, shipping and disposal of the reactor internals and the reactor vessel.

Also in period three, the steam generators, pressurizers, contaminated systems and structures are removed, packaged, shipped and disposed of.

Additionally, clean structures and systems are removed as they become unnecessary. In period four, the buildings undergo decontamination. Building decontamination includes decontamination of the reactor building(s), removal, packaging, shipping and disposition of spent fuel racks after spent fuel has been removed from the spent fuel pool, decontamination of the spent fuel pool and the balance of the auxiliary building(s), a formal site survey of any remaining buildings, and termination of 10 CFR Part 50 license. Period five consists of demolition of clean buildings. In this period, all remaining clean structures are removed with the exception of any required to support spent fuel storage. Period six consists of site restoration. In this period, the site is graded and landscaped to conform to the natural surroundings. Depending on the spent fuel storage assumptions, these periods may be separated by a wet spent fuel storage period, a dry spent fuel storage period, and/or a combination of both.

The estimate in this study utilizes the DECON methodology.

There are advantages to utilizing the DECON methodology.

DECON provides sooner termination of the NRC license compared to SAFSTOR. Knowledgeable employees who are familiar with the site will still be available.

There is no need for long-term security and surveillance. The DECON method provides a greater certainty of regulatory requirements due to the inherent uncertainty in trying to assess future regulatory requirements. Finally, the total cost will be lower as it is incurred in current dollars and there is no extended dormancy period.

DECON offers similar advantages over ENTOMB, primarily avoiding the uncertainty and long-term surveillance costs likely associated with restricted release of the site. In addition, DECON allows more flexible site reuse compared to ENTOMB.

Disadvantages of the DECON methodology compared to SAFSTOR or ENTOMB include the following: the short time period that elapses following shut-down means less radioactive decay and therefore a higher worker dose. The initial cash outlay will be larger. There is time for funds to accrue, which means a larger present value; and work will have to be performed in proximity to the on-site storage of spent fuel.

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Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 3.2 SPENT FUEL ACTIVITIES There are many uncertainties associated with the Department of Energy's (DOE) acceptance of spent fuel. The Department of Energy (DOE) originally contracted to begin accepting spent fuel from nuclear power plants no later than January 31, 1998. To date, no commercial spent fuel has been taken by the DOE under the contract. Many utilities have brought legal proceedings against the DOE for their breach of contract with the majority winning court ordered compensation.

Recently, all activity at Yucca Mountain has been shutdown and, at least in the near term, has been removed as a potential spent fuel repository. It appears unlikely that that spent fuel shipments to a Federal repository will occur anytime in the foreseeable future. In light of this fact, all nuclear utilities should be prepared to store spent fuel on-site for a long period of time.

This scenario assumes indefinite storage.

In October, 2011 the DOE reached a settlement agreement with Indiana Michigan Power Company in regards to their failure to commence acceptance of spent nuclear fuel and high level waste. The agreement allowed Indiana Michigan to recover costs incurred due to the DOE's failure through December 31, 2013. An Addendum to this settlement agreement was issued in January of 2014. The Addendum extended the termination date of the settlement to December 31, 2016. Allowable reimbursements are based on costs incurred above and beyond those that would have been incurred had the DOE performed according to the contract. But for DOE's failure to perform, Indiana Michigan's spent fuel allocations, those spent fuel assemblies that would have been taken by DOE, are identified in attachment 1 of the Addendum.

This scenario assumes all spent fuel will be transferred to an on-site ISFSI after shutdown. Dry storage will be required during operations to maintain full core discharge capabilities, including expanding the ISFSI, if needed. The ISFSI must be expanded, after shutdown, sufficiently to accommodate the long term storage of all spent fuel from both units. The storage system is anticipated to be licensed for both storage and transportation facilitating the eventual transfer to the DOE site.

It is assumed that spent fuel cannot be transferred to dry storage until it has cooled a minimum of seven years in the spent fuel pool. In order to minimize post-shutdown spent fuel storage costs the spent fuel island concept will be implemented. Modifications to the site will provide self-contained fuel pool cooling, cleanup, monitoring, control and electrical power systems. This will isolate the spent fuel pool from the remainder of the site and will allow decommissioning to continue safely on the balance of site. This option will provide the low cost option for the long term on-site storage of spent fuel.

Per ISFSI Licensing requirements, a 10 CFR part 72 license will be required in order to terminate the 10 CFR Part 50 license. Systems approved for use under the provisions of 10 CFR part 72 Subpart K, a Certificate of Compliance, may be used on a site with a 10 CFR part 50 license without a 10 CFR Part 72 Subpart C license. The process to obtain a 10 CFR Part 72 Page 8 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 license will be simplified by utilizing a storage system with a Certificate of Compliance. For this reason, this study assumes the dry storage system utilized will have a Certificate of Compliance.

A site re-evaluation is not required to obtain the Part 72 subpart C ISFSI license if it is shown that original site findings have not changed. A re-evaluation would only be required if new infonnation is available that alters the original findings. It is assumed that the system utilized for dry storage will meet or could be modified to meet the original site design conditions.

3.3 DECOMMISSIONING MANAGEMENT The utility staff will retain certain of their ongoing functions during decommissioning, including the following:

Shipment of low-level waste remaining from plant operations Radiological health and safety Security Quality assurance Health physics monitoring Defueling of the reactor Draining and de-energizing of all systems Continued safe on-site storage of spent fuel Management of the decommissioning general contractor.

The number of staff during each period depends on the major work planned for each period.

Details are provided in section seven of this report.

While not directly applicable, consistent with the reasons stated in the NRC guidance of NUREG-1757, Vol. III, App. A, Section A.3.1, this study assumes that the utility will hire an experienced decommissioning general contractor (DGC) who will be responsible for performing the decommissioning activities. The DGC in turn will hire and be responsible for subcontractors hired to perform activities, such as primary system decontamination flush and large component removal. The number of staff during each period depends on the major work planned for each period. Details are provided in section seven of this report.

3.4 COLD & DARK To simplify the removal of systems and structures, a "cold & dark" status will be implemented.

The cold & dark status will allow component removal without individually verifying that each component has been de-energized. To implement cold & dark, all systems will be drained and electrical power to components will be removed as appropriate.

After the spent fuel pool isolation has been completed, a new minimized control room will be constructed. Construction power will be supplied to the site for decommissioning and to operate essential loads with color coded wire. This process ensures that all energy sources are removed prior to the beginning of Page 9 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 decommissioning activities, simplifying the removal process and greatly increasing safety during the decommissioning process.

3.5 DECONTAMINATION PROCEDURES To facilitate the removal of contaminated large components, contamination control envelopes (CCE's) will be set up inside the reactor building. CCEs will have integral ventilation systems for contamination control and to maintain negative pressure. Cutting stations, including for underwater cutting, will be set up within the reactor building.

The reactor vessel internals will be removed from the vessel and transferred to the fuel transfer canal. Once in the transfer canal, they will be segmented and loaded underwater into shipping liners. The liner outer surfaces will be washed and loaded into shipping casks for transport to the disposal facility.

The reactor vessel will be cut into ring segments with each segment transferred to the fuel transfer canal. Here, each segment will be further segmented and loaded into shipping cask liners. The outer surfaces of the liners will be washed and then loaded into shipping casks for transport to the disposal facility.

With the exception of the upper shell, the steam generator will be removed intact. A steam generator transfer system and support equipment will be installed to remove the steam generator from the reactor building. A CCE and ventilation system, scaffolding, temporary lighting and shielding will also be installed. The insulation will be removed from the steam generators, followed by cutting of the main steam, feedwater and miscellaneous piping. Next the upper shell and components will be cut and removed. These will be surveyed, decontaminated and released if possible.

A steel plate will be welded to the top of the lower shell. The lower shell will be removed, transferred from the building, prepared for transport and transported to the disposal facility.

The pressurizer will be removed in a similar fashion, excluding segmentation.

The following process will be used for removal and disposal of contaminated systems, previously drained by the utility staff: Contaminated pipe and components will be cut free and segmented as necessary. The components will be transferred to a packaging area where a crew will package them, survey the containers and prepare the containers for shipment.

Clean pipe and components will be cut free and segmented when necessary. The components will be transferred to a packaging area where a crew will package the material into containers and prepare for them for shipment. It is assumed that clean waste will be disposed of at a local landfill.

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Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 With the exception of the reactor building interior, contaminated concrete surfaces will be decontaminated by partial surface removal. In some cases entire walls and/or floors. will be removed. The remaining structures will be surveyed for conformance to release limits.

Depending on the results of the survey, more decontamination may be required. Bulk removal of the reactor building interior floors and walls will be performed with all of the material being sent out for off-site processing. This leads to a large disposal volume; however, at a lower rate for bulk processing than for direct burial. In addition, there will be far less characterization and iterative decontamination.

Clean structures will be demolished using explosives and/or mechanical means and disposed of at a local landfill.

3.6 CONTINGENCY Contingencies are applied to cost estimates primarily to account for unknown or unplanned events that experience tells us are likely to occur. These events include increased radioactive waste materials in volumes exceeding the amount anticipated; equipment breakdowns; weather delays; labor strikes, etc. Estimates are based on assumed values of cost, which in reality are subject to variability. The actual costs may be higher or lower than the estimated value; however, they usually go higher. The amount of contingency to be added is directly related to the level of detail and uncertainty contained in the estimate.

The U.S. Department of Energy (DOE) Cost Estimating Guide, DOE G 430.1-1, 3-28-97; defines contingency as follows:

"Covers costs that may result from incomplete design, unforeseen and unpredictable conditions, or uncertainties within the defined project scope. The amount of contingency will depend on the status of design, procurement, and construction; and the complexity and uncertainties of the component parts of the project. Contingency is not to be used to avoid making an accurate assessment of expected costs."

DOE G 430.1-1 provides a recommended range of contingencies as a function of program design:

Time of Estimate Planning Phase Budget Title I Title II Contingency Range as a% of Total Estimate 20-30 15-25 10-20 5-15 The AACE International Certification Study Guide, Second Edition - Revised, 2003, defines contingency. as follows: "Contingency is a cost element of an estimate to cover a statistical probability of the occurrence of unforeseeable elements of cost within the defi°:ed project scope Page 11 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 due to a combination of uncertainties, intangibles and unforeseen, highly-unlikely occurrences of future events based on management decisions to assume certain risks."

AIFINESP-0036 "Guidelines for Producing Nuclear Plant Decommissioning Cost Estimates" (AIF) is another source for published contingency values.

This document identifies contingencies for activities specific to nuclear power plant decommissioning. Except for system decontamination, reactor vessel removal and disposal and reactor internals removal and disposal, the contingencies presented in AIF are consistent with the values presented in DOE G 430.1-1 for a Budget/Title I estimate. The contingencies identified in AIF for system decontamination and reactor vessel and reactor internals removal and disposal are higher than the rnnges identified in DOE G 430.1-1. This is in part due to the lack of actual decommissioning work performed during the time period the AIF document was published.

While not directly applicable to a Part 50 reactor license, the NRC guidance of NUREG-1757, Vol. III, App. A, Section A.3.1, states that a contingency factor of 25% is normally appropriate.

"Because of the uncertainty in contamination levels, waste disposal costs, and other costs associated with decommissioning, the cost estimate is required to apply an 'adequate' contingency factor. In general a contingency of 25 percent applied to the sum of all estimated decommissioning costs should be adequate, but in some cases, a higher contingency may be appropriate." The guidance goes on to recognize that "Proposals to apply the contingency only to selected components of the cost estimate, or to apply a contingency lower than 25 percent, should be approved only in circumstances when a case-specific review has determined that there is an extremely low likelihood of unforeseen increases in the decommissioning costs." For the reasons developed below, this study is an example of circumstances where a case-specific review has determined that applying a contingency lower than 25 percent to some elements of the cost estimate is appropriate.

An estimate of the nature developed for D. C. Cook would be considered somewhere between a Budget estimate (based on conceptual design) and a Title I (based on more detailed site specific design). As such, an overall contingency in the 15% to 25% range would be appropriate. Knight Cost Engineering Services, LLC (KCES) has detennined contingency values specific to DC Cook utilizing the information presented in AIF and consistent with DOE G 430.1-1. There are a number of large scale decommissioning projects in progress or nearing completion. The DC Cook decommissioning cost estimate incorporates the lessons learned from these projects. As such, costs can be estimated with a greater degree of confidence than was true at the time AIF was published. This increased level of confidence allows for a downward adjustment to the recommended contingency where applicable. Other cost elements, particularly with regard to the reactor vessel segmentation, are less well known and contingency up to 50 percent is appropriate.

The following table provides a summary of the contingency values that were applied to each activity for each cost category.

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Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 TABLE3.l Equip Contam-Staff Craft Trans-Clean inated Labor Labor Mtls Pkging

12ortation Dis:12osal Dis:12osal Energy Other Engineering and Project Management 15%

Contaminated removal 25%

10%

15%

25%

Reactor Vessel and Internals 50%

25%

50%

Clean removal 15%

10%

25%

10%

Supplies and consumables 25%

Other 15%

15%

There is some variation associated with the contingency analysis for on-site spent fuel storage.

The activity costs associated with spent fuel storage, such as the purchase and construction of the ISFSI, the modification of the spent fuel pool and the transfer of spent fuel pool to the ISFSI are subject to many of the unknown or unplanned occurrences for which contingency is based. As such, the above methodology will be applied. During periods of spent fuel storage only, either wet or dry, the operating costs of the spent fuel storage facility include only" a ten percent contingency because of the higher degree of knowledge and confidence in the factors comprising the operation of the wet or dry storage facility. Any variability in the duration of the fuel storage period due to failed DOE schedules is excluded from the contingency.

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Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 4.0 ASSUMPTIONS Following is a list of assumptions developed by KCES in completing this study.

These assumptions are based on the most current decommissioning methodologies and site-specific considerations.

1. Component quantities with the exception of pipe, conduit, cable tray and duct lengths, were developed from directly from the plan EDB system. Pipe, conduit, cable tray and duct lengths were used as is from the previous estimate.

2. Structure inventory quantities were developed for this estimate from general arrangement drawings and the site walkdown.

3. The utility staff is assumed to be the same size at the time of Unit 2 shutdown as it was in July, 2015.

4. Utility staff positions and costs were supplied by the Company and represent July, 2015 salary and benefit data

5. Subcontractor base labor rates and fringe benefits were supplied by AEP for most crafts. These rates were current as of June, 2015. The overhead and profit structure for these rates was developed by KCES.

6. Craft labor rates for positions not supplied by the Company were determined by KCES.

7. Activity labor costs do not include any allowance for delays between activities, nor is there any cost allowance for craft labor retained on-site while waiting for work to become available.

8. All skilled laborers will be supplied by the local umon hall and hired by the Decommissioning General Contractor (DGC).

9. The professional personnel used for the planning and preparation activities will be paid per diem at the rate of $142.00/day. Since the skilled laborers are being supplied by local union hall they will not be paid per diem.

10. The cost for Utility personnel assisting the DGC to develop decommissioning activity specifications is included in the Utility Staff costs. *

11. Health Physics technicians used during vessel and internal removal will be supplied by the Utility Staff.

12. The DGC staff salaries, including overhead and profit, were determined by KCES.

13. Transportation costs are based on actual mileage from D. C. Cook to each disposal or processing facility utilized in the estimate.

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Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0

14. Class B & C radioactive waste base disposal costs are based on actual out of compact disposal rates and fees incurred at the WCS facility in Andrews, TX. In addition, the disposal costs of the Greater Than Class C waste, e.g., the core baffle and lower core grid plate, include present day curie surcharges as imposed at the WCS facility to more accurately reflect handling costs for highly radioactive material.

15. Class A waste will be disposed of at the EnergySolutions facility in Utah, EnergySolutions metal melt facility in Tennessee or the Studsvik processing facility in Tennessee, which EnergySolutions acquired in 2014. Waste is assumed to be transported to the lowest cost facility for which it qualifies. Further details on these processes are presented in Section 8.1.

16. Clean waste is assumed to be disposed of at a local landfill at a cost of $90.00 per ton.

1 7. It is assumed that all radioactive waste generated during operations and stored on-site will be disposed of prior to shutdown. The cost of disposal of this material is considered an operating expense and is assumed not to be a decommissioning cost.

18. Greater than Class C waste will be removed from the reactor vessel, segmented and packaged in containers of similar size and shape to the spent fuel assemblies,. The containers will be stored in the spent fuel pool or transferred to the ISFSI. The additional containers are assumed to be shipped offsite with the spent fuel and are included in the spent fuel shipping analysis. Eighty-four containers will be filled per unit for both scenarios.

19. All costs used in these calculations were current on July, 2015.

20. The costs of all required safety analyses and safety measures for the protection of the general public, the environment, and decommissioning workers are included in the cost estimates.

21. All post shutdown costs necessitated by the presence of stored spent fuel are presented separately.

22. It is assumed that Unit 1 will shut down in October, 2034 and that Unit 2 will remain operational until December 2037.

23. On-site dry storage will utilize the Holtec Vertical Concrete Casks (VCC) and Multi-Purpose Canister (MPC) system. Each MPC is designed to store and transport 32 spent fuel assemblies. Separate overpacks will be used for transportation and disposal.

24. It is assumed that spent fuel will cool seven years in the spent fuel pool prior to being transferred to the ISFSI or shipped off site.

25. Only the costs for the expanded storage pad, canister and overpacks projected to be purchased after Unit 1 shutdown are included in this study as a spent fuel storage Page 15 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 expense. All canisters and overpacks required during operations, in order to maintain full core discharge capabilities, are assumed to be an operations expense.

The cost per canister and storage overpack is estimated to be $2,000,000, including closure services.

26. The Unit 1 and Unit 2 reactor vessel and internals will be removed sequentially.

27. The Unit 1 and Unit 2 reactor vessel and internals are considered identical.

28. Vessel and internals curie estimates were derived from the values for the Reference PWR vessel and internals in NUREG/CR-0130. These values were adjusted for MWT rating, weight and decay period.

29. While there will in all likelihood be some level of property tax after shutdown, this study does not attempt to estimate the amount. It has been assumed for purpose of this study that property taxes for the D,C. Cook Plant will be zero after shutdown. This issue will be addressed as more information becomes available.

30. No PCBs will be on-site at shutdown.

31. It is assumed that all asbestos insulation will have been removed during the operating life of the plant.

32. Clean building walls and foundations more than three feet below grade may be left in place if there are no voids.

33. KCES has assumed that a site specific 10 CFR Part 72 license will be required for the balance of the dry storage period prior to terminating the 10 CFR Part 50 operating license.

34. The decommissioning will be performed under the current regulations. These regulations require a Post-Shutdown Decommissioning Activities Report (PSDAR) to be submitted prior to or within two years of after shutdown. In addition, certificates for permanent cessation of operations and permanent removal of fuel from the vessel must be submitted to the NRC 90 days after the PSDAR submittal. Major decommissioning activities that meet the criteria of 10 CFR Part 50.59, may be performed provided NRC agrees with the PSDAR.

35. The VCCs and storage pad may have some level of activation, as such the material will be removed and transported to one of the EnergySolutions processing facilities in Tennessee.

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Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 5.0 SCENARIO DESCRIPTION Utilizing the above described estimating methodology cost for this scenario is $1,634,038,400.

In addition there will be an annual cost of $4,912,700 per year of post decommissioning spent fuel storage and $56,952,300 for the eventual decommissioning of the ISFSI. The assumptions pertinent to this scenario are described below.

5.1 DECON WITH INDEFINITE ON-SITE DRY STORAGE This scenario includes Unit 1 shutdown on Oct 25, 2034 and Unit 2 on Dec 23, 2037. The transfer of spent fuel remaining in the spent fuel pool to the dry storage facility will begin in 2039. The existing ISFSI will be expanded to accommodate all spent fuel remaining on-site.

With the exception of the last core load of fuel assemblies, transfer of all remaining fuel to the ISFSI will be completed seven years after shutdown. The transfer of the last core load of 193 assemblies and a few remaining assemblies will occur immediately after the required seven year cooling period. The site will remain as an Independent Spent Fuel Storage Installation indefinitely.

The spent fuel pool will be modified immediately after Unit 2 shutdown to isolate it from the remainder of the facility. The capital cost of the skid mounted pool support systems package is included in this estimate. This will allow decommissioning to proceed exclusive of the spent fuel pool. Once all spent fuel has been removed from the spent fuel pool, the spent fuel pool island will be decommissioned. As soon as all spent fuel is transferred to dry storage, the balance of the D.C. Cook Plant will be decommissioned. All spent fuel will be stored on-site in Holtec's VCC and MPC system.

The six sequential periods in this scenario and the major activities occurring in each are as follows:

Period Description Period Duration, Months 1

BETWEEN SHUTDOWN OF UNIT 1 AND SHUTDOWN OF UNIT 2 38 Planning for spent fuel pool modifications.

Planning for cold and dark Planning for primary systems flush SelectDGC Planning for decommissioning 2

POST-SHUTDOWN ACTIVITIES 12 Transfer spent fuel from pool to the ISFSI Modification of spent fuel pool systems Primary system decontamination flush Page 17 of 32

Knight Cost Engineering Services, LLC 3

4 5

6 Flush and drain non-essential systems

. Perform characterization survey Implement cold and dark Vessel and Internals removal preparations REMOVAL OF MAJOR COMPONENTS Transfer spent fuel from pool to the ISFSI Removal of Unit 1 and Unit 2 reactor vessels and internals Removal of Unit 1 and Unit 2 steam generators Removal of Unit 1 contaminated systems Remove Unit 1 clean systems Decontaminate Unit I Reactor Building Begin Unit 1 and Unit 2 structures decontamination DECON BALANCE OF SITE

Removal of Unit 2 contaminated systems

Remove Unit 2 clean systems

Decontaminate Unit 2 Reactor Building

Remove spent fuel racks

Decontaminate spent fuel storage building

Completion of Unit 1 and Unit 2 structures decontamination

Final site survey of reactor plant confirming satisfactory removal CLEAN STRUCTURES DEMOLITION

Demolition of decontaminated Unit l and Unit 2 structures RESTORATION OF PLANT SITE Backfill, grading and landscaping of Unit 1 and Unit 2 sites KCES 2016-100, Rev. 0 42 38 18 2

In this scenario, decommissioning and site restoration will be complete approximately 112 months or 9.3 years after Unit 2 shutdown. Spent fuel will remain on-site indefinitely. The cost for the eventual decontamination and removal of the ISFSI is included in the estimate.

Page 18 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 6.0 SCHEDULES A scenario-specific schedule has been developed for this study. The schedule is based on some combination of the following assumptions:

DECON Spent fuel shipping start date Spent fuel shipping rate Construction and maintenance of on-site dry storage facility The first step in determining each schedule is assessment of the spent fuel disposition. The spent fuel disposition schedule will have a major influence on the overall schedule critical path. The spent fuel disposition analysis will then.be combined with the decommissioning activities to determine the overall project schedule.

Activity durations are determined based on the unit cost factor approach. Once the plant material inventory has been determined specific unit rates for cost, man hours and schedule hours for a specific activity, such as surface decontamination, are applied to the inventory.

From this calculation the removal or decontamination cost, total man hours and total schedule hours are determined for an activity. The schedule hours are then entered into the schedule to determine project duration. The schedule will be divided into multiple periods depending on the activities occurring during that time period. The separation into multiple periods allows for better control in determining the period dependent costs such as staffing, insurance and security.

The spent fuel disposition analysis for Unit 1 and Unit 2 are presented in Table 6.1. This scenario assumes an indefinite on-site storage period. A detailed decommissioning schedule, based upon this spent fuel transfer schedule and a critical path analysis of the decommissioning activities, is presented in Appendix A.

6.1 DECON WITH ON-SITE DRY STORAGE AND NO SPENT FUEL SHIPPING Spent fuel is assumed to remain on-site in dry storage indefinitely. The schedule of spent fuel movements is reflected in Table 6.1. The detailed project schedule is present in Appendix A.

The decommissioning schedule has been optimized within the limitations imposed by the spent fuel storage requirements. Program periods and durations for this scenario are as follows:

Period 1

2 3

Description Ul & U2 Decommissioning Planning Cost:

Post-Shutdown Activities Costs:

Vessel and Internals Removal Costs:

Page 19 of 32 Duration, months 38 12 42

Knight Cost Engineering Services, LLC 4

5 6

7 8

Decontaminate Balance of Site Costs:

Clean Structure Demolition Costs:

Restore Site Costs:

Dry Storage (Indefinitely)

Eventual decontamination and removal of ISFSI KCES 2016-100, Rev. 0 38 18 2

21 Decommissioning of the site will be complete in 2047, which is 112 months after the shutdown of Unit 2. Spent fuel will remain on site in dry storage indefinitely.

Page 20 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 TABLE6.1 SPENT FUEL SHIPPING SCHEDULE Total Total Unit 1 Unit2 Assemblies Assemblies Assemblies Pool Fuel Fuel Assemblies

& other items to in Dry Locations Year Discharged Discharged ToDOE on Site Dry Storage Storage Occupied 2015 84note l 3684 512 896 2788 2016 89 89 3862 0

896 2966 2017 89 0

3951 0

896 3055 2018 0

89 4040 512 1408 2632 2019 89 89 4218 0

1408 2810 2020 89 0

4307 0

1408 2899 2021 0

89 4396 512 1920 2476 2022 89 89 4574 0

1920 2654 2023 89 0

4663 0

1920 2743 2024 0

89 4752 384 2304 2448 2025 89 89 4930 0

2304 2626 2026 89 0

onote3 5019 0

2304 2715 2027 0

89 0

5108 384 2688 2420 2028 89 89 0

5286 0

2688 2598 2029 89 0

0 5375 0

2688 2687 2030 0

89 0

5464 320 3008 2456 2031 89 89 0

5642 0

3008 2634 2032 89 0

0 5731 0

3008 2723 2033 0

89 0

5820 0

3008 2812 2034 193 89 0

6102 0

3008 3094 2035 0

0 6102 0

3008 3094 2036 89 0

6191 0

3008 3183 2037 193 0

6384 0

3008 3376 2038 0

6384 0

3008 3376 2039 42 note~

0 6426 320 3328 3098 2040 84 0

6510 384 3712 2798 2041 42 0

6552 512 4224 2328 2042 0

6552 512 4736 1816 2043 0

6552 704 5440 1112 2044 0

6552 704 6144 408 2045 0

6552 408 6552 0

2046 0

6552 6552 0

NOTES:

1. Discharge supplied by AEP 5/5/15.

2. 84 spent fuel baskets loaded with GTCC will be discharged into the spent fuel pool, from each unit, during internals removal.

3. Spent fuel will remain on-site indefinitely.

4. Assemblies to dry storage determined by AEP through, 2033. Assemblies to dry storage after Unit 1 shutdown determined by KCES

5. Max number of casks required:

205

6. Casks purchased after shutdown 111 Page 21 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 7.0 PROJECT MANAGEMENT There are three components to project management during decommissioning, Utility Staff (staff),

Decommissioning General Contractor Staff (DGC) and Security. Each of these is further broken down into that required for decommissioning and that required for spent fuel storage. The person levels for each are specific to each decommissioning period.

7.1 UTILITY STAFF The staff size at Unit 1 shutdown is assumed to be the same size and composition as it was in the spring of 2015. Immediately after Unit 1 shutdown, the staff is reduced approximately 33%,

severance payments for the severed personnel are included in period one of this study. The majority of the remaining staff is attributed to the operation of Unit 2. Upon shutdown of Unit 2 this staff is reduced to the level required for decommissioning operations and spent fuel storage, the severance payments for the severed personnel are included in period two of this study.

Severance payments are tracked through the decommissioning and all costs are included in this study. All severed employees will receive a severance package based on the existing severance policy.

There are two components to the staff, decommissioning and spent fuel storage. The majority of the staff during the early part of the decommissioning process will be attributed to decommissioning. A staff level of 11.5 full time employees (FTE) will be required during period 1, between Unit 1 and Unit 2 shutdown. Upon shutdown of Unit 2, period 2, approximately 145 FTEs will be required to prepare the site for decommissioning, including the spent fuel pool, security and control room modifications. Once these modifications have been made the staff will be reduced to 96 FTEs to support the reactor internals and reactor vessel removal, period 3. The staff will be further reduced to 78 FTEs, 7 FTEs and 3 FTEs for period 4 site decontamination, period 5 structures removal and period 6 site restorations, respectively.

During the decommissioning process there is a need to manage the safe operations of the spent fuel storage facilities, whether spent fuel is in wet storage or dry storage. The Utility staff will maintain responsibility for these actions. Spent fuel will remain in the spent fuel pool for a minimum of seven years. Also, there is an existing ISFSI, required during operations to maintain full core off load capabilities. As such, there are two on-site spent fuel storage scenarios, wet and dry storage in operations at the same time and dry storage only. During the wet and dry storage periods the Utility staff will be 33 FTEs and 14.25 during dry storage only. There will be some fluctuation in these staffs due to sharing of upper management personnel with the decommissioning staff.

Page 22 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 7.2 DECOMMISSIONING GENERAL CONTRACTOR The DGC is assumed to have no role in the post shutdown management of the spent fuel storage facility. Upon selection of a DGC contractor, the contractor will begin to mobilize on site. A DGC staff of 27 FTEs is assumed to be on site during the last 12 months of period 1, between Unit 1 and Unit 2 shutdown.

A DGC staff of 76 FTEs will be on site to prepare for decommissioning during period 2 site preparations. The DGC staff will be increased to 89 FTEs to support the reactor internals and reactor vessel removal, period 3. The DGC staff will be reduced to 76 FTEs, 34 FTEs and 15 FTEs for period 4 site decontamination, period 5 structures removal and period 6 site restorations, respectively.

7.3 SECURITY There are two components to the security staff, decommissioning and spent fuel storage. The majority of the security staff during the early part of the decommissioning process will be attributed to decommissioning. An apportionment of the full security staff is allocated to Unit 1 during period 1, between Unit 1 and Unit 2 shutdown, estimated to be 5 full time employees (FTE). Upon shutdown of Unit 2, period 2, approximately 72 FTEs will be required during preparations for decommissioning. Once modifications have been made to the spent fuel pool, security and control room the security staff will be reduced to 32 FTEs to support the reactor internals and reactor vessel removal, period 3 and site decontamination, period 4. The staff will be further reduced to 7 FTEs and 2 FTEs for period 5 structures removal and period 6 site restorations, respectively.

During the decommissioning process there will be a need to manage the safe operations of the spent fuel storage facilities, whether spent fuel is in wet storage or dry storage. A dedicated security staff will be assigned to both the wet and dry storage facility. Spent fuel will remain in the spent fuel pool for a minimum of seven years. There is an existing ISFSI, required during operations to maintain full core off load capabilities. As such, there are two on-site spent fuel storage scenarios, wet and dry storage in operations at the same time and dry storage only.

During the wet and dry storage periods the security staff will be 20 FTEs and during dry storage only the security staff will consist of 13 FTEs. A security staff of 13 FTEs is attributed to spent fuel storage during the ISFSI removal.

The following Table 7-1 is a summary of the utility staff, DGC and security staff levels required.

7.4 DECON WITH INDEFINITE DRY STORAGE Table 7.1 summarizes the staff level for Decommissioning and Table 7.2 summarizes the staff levels for spent fuel storage as defined above, by period.

Page 23 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 TABLE 7-1 DECOMMISSIONING STAFF

SUMMARY

Position:

l 2

l 4

i Q

1 Health Physics 2.25 29 24 24 0

0 0

Engineering 1.25 20 11 10 2

1 0

Maintenance Se1vices 2.75 19 5

5 3

0 0

Operations 0.75 38 14 5

0 0

0 Projects 3.25 13 29 22 0

0 0

Administration 1.25 26 u

12 2

2 Q

11.5 145 96 78 7

3 0

DGC 27 76 89 76 34 15 Security Guards 5

72 32 32 7

2 TABLE 7-2 SPENT FUEL STORAGE STAFF

SUMMARY

Position:

l 2

l

+/-

i Q

1

~

Health Physics 0

5 5

5 1.25 1.25 1.25 4

Engineering 0

1 1

1 0

0 0

0 Maintenance Services 0

5 5

5 2

2 2

2 Operations 0

13 13 13 5

5 5

6 Projects 0

0 0

0 2

2 2

1 Administration Q

2 2

2

+/-

4

+/-

0 33 33 33 14.25 14.25 14.25 17 DGC 0

0 0

14 Security Guards 0

24 20 20 13 13 13 13 Page 24 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 8.0 WASTE DISPOSAL 8.1 LOW LEVEL WASTE DISPOSAL BACKGROUND The Low-Level Waste Policy Act (LLWPA), passed by Congress in 1980 and the Low-Level Waste Policy Amendments Act of 1985 encouraged states to form compacts for the disposal of low-level radioactive waste. The Acts made each state responsible for disposing of their own radioactive waste. The formation of compacts allowed states to limit their disposal facility to compact members thereby limiting the amount of waste accepted. On the other hand, the Acts also required that states not participating in the process would be required to take title to waste generated within that state. This provision was overturned by the U. S. Supreme Court in 1992 thus eliminating the need for states to develop their own disposal facility, including those already in a compact. The compact process has not resulted in the expected regionalization of low level radioactive waste disposal; to date there has been just one new disposal facility licensed to accept all low level radioactive waste, including Class A, B & C.

There are currently three facilities licensed to accept all low level radioactive waste:

the Barnwell, South Carolina facility operated by EnergySolutions, LLC; the Waste Control Specialists, LLC (WCS) facility in Andrews, TX and the Hanford, Washington facility operated by U. S. Ecology.

There is one other site in Clive, Utah owned and operated by EnergySolutions, LLC; however, this facility is currently licensed to accept only Class A radioactive waste. As of July 1, 2008 the Barnwell facility will only accept waste from the Atlantic Compact states.

The Atlantic Compact member states include South Carolina, Connecticut and New Jersey. The Hanford facility only accepts waste from the Northwest Compact and the Rocky Mountain Compact; this has been the case since 1993. The Northwest Compact and Rocky Mountain Compact member states include Alaska, Colorado, Hawaii, Idaho, Montana, Nevada, New Mexico, Oregon, Utah, Washington and Wyoming. While the WCS facility is the compact disposal facility for Texas and Vermont it will accept waste from out of compact. WCS is licensed to accept Class A, B and C radioactive waste, as such this estimate assumes that Class B & C waste will be disposed of at this facility with the costs based on the current rate structure for out of compact waste.

8.2 CLASS A WASTE DISPOSAL There are currently multiple options for the disposition of Class A waste. These include metal melt, direct burial and waste processing. Table 8-1 provides a summary of waste disposition options for Class A waste and their unit rates considered in this estimate. KCES assumes that each waste stream will be transported to the least cost option for which it qualifies. Packaging and transportation costs have been calculated based on these specific locations.

Page 25 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 Table 8-1 Class A Waste Disposal Options Description ENERGY SOLUTIONS disposal WCS disposal BSFR processing Disposal Cost. $/cu. ft.

$171.84 per cubic foot

$208. 79 per cubic foot

. $0.25 per pound KCES assumed that the reactor building internal floors and walls will be removed in bulk and sent for processing to a BSFR facility. This approach will produce a large volume of waste compared to the traditional decontamination, survey and release methodology but at a lower rate.

In addition, the approach will reduce the amount of characterization and iterative decontamination. Other contaminated structures will follow the decontamination, survey and release approach due to the smaller areas of potentially contaminated surfaces.

The steel in the vertical concrete casks and the storage pad for the ISFSI are assumed to be potentially activated. The entire volume of the VCCs and pad will be sent to the BSFR facility in Tennessee for processing. Sending the entire volume of this material for processing will eliminate the time consuming processing of separating, surveying and repeating as necessary.

The remainder of the material associated with the ISFSI will be.removed as clean material.

8.3 CLASS B & C WASTE DISPOSAL As discussed above, the WCS facility is licensed to accept Class B and C waste. This study assumes that all Class B & C waste will be disposed of at WCS. There is currently only a published fee and surcharge structure for in compact generators. Based on guidance from WCS personnel, increasing the published fees and surcharges by 20% would be representative of the rates that would be charged to out of compact generators. The base disposal rate for Class B & C waste is currently $2,680/cubic foot. This rate was provided by AEP.

Additionally, there is a dose rate surcharge and a millicurie charge that must be added. The basic millicurie charge is $0.55 per millicurie up to $220,000 per shipment. There is also a weight surcharge, up to $20,000 per shipment; a dose rate surcharge, up to $400 per cu. ft.; an irradiated hardware there is an additional surcharge of $75,000 per shipment and a cask handling surcharge of $2,500 per cask. Finally there are State and County fees of 5% each. These rates appear to be unchanged from 2012. This estimate includes all applicable surcharges and fees.

Page 26 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 8.4 DISPOSAL OF WASTES GREATER THAN CLASS C While waste identified as Class A, Band C, according to 10 CPR 61, may be disposed of at a near-surface disposal facility, certain components may exceed the radionuclide concentration limitations for 10 CFR 61 Class C waste.

These components cannot be disposed in a near-surface radioactive -waste disposal facility based on 10 CPR 61 definitions. They will have to be transferred to a geologic repository or a similar site approved by the NRC.

The KCES site-specific classification of radioactive wastes for the D.C. Cook Plant identified that the Spent Fuel Assemblies and two components within each reactor vessel (the Core Baffle and the Lower Core Grid Plate) will exceed Class C limitations. Like the spent fuel assemblies, the reactor vessel components will be stored with the spent fuel either in wet or dry storage.

Here they will wait for transportation to a DOE geologic disposal facility for disposal. The costs for disposing of these components was estimated based upon the maximum curie surcharges currently in effect at the WCS disposal facility. Prior to placing in storage with the spent fuel, these components will be segmented and the pieces placed into spent fuel sized containers, it is estimated that 168 containers will be generated from the two units.

8.5 RADIOACTIVE WASTE VOLUMES PER 10 CPR 61 CLASSIFICATIONS KCES has determined the classifications of radioactive wastes resulting from decommissioning the D.C. Cook Plant. The radioactive waste associated with each decommissioning activity is based upon the site-specific decommissioning calculations prepared for this cost estimate. The total volumes of 10 CPR 61 wastes for Units 1 and 2 are presented in Table 8.2. These volumes represent waste volumes generated at the site, for both units, excluding the waste generated by removing the ISFSI.

Table 8-2 10 CFR 61 Radioactive Waste Volumes (cubic feet)

Class A Class B Class C Greater Than Class C Total:

3,622,768 5,480 2,344 1,512 3,632,104 Waste associated with the removal of the ISFSI, is identified in Table 8-3 below.

Page 27 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 Table 8-3 10 CFR 61 Radioactive Waste Volumes (cubic feet)

ISFSI 534,981 8.6 PROJECTION OF NON-RADIOACTIVE WASTE QUANTITIES KCES has included the cost for disposal of all non-contaminated waste at a local landfill. As seen in the Maine Y an.kee decommissioning, on-site use of concrete rubble to fill below grade voids can be problematic. Maine Yankee originally intended to utilize remediated concrete to fill below grade voids. Many felt that this would essentially be considered on-site disposal of radioactive material since the concrete, although below the limits specified in the Licen~e Termination Plan (LTP), might still be slightly radioactive. Maine Yankee decided to eliminate potential legacy waste by transporting and disposing of this material in a licensed landfill. For this reason KCES has assumed that all non-contaminated waste, including pipe and components will be disposed of in a licensed landfill at a rate of $0.045 per pound. Table 8-4 presents the total volumes of non-contaminated waste resulting from the decommissioning program.

Table 8-4 Non-Contaminated Waste (pounds)

Structures Systems 1,006,158,339 45,885,045 Page 28 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 9.0 COST SUMMARIES 9.1.

ESTIMATING APPROACH The estimating methodology utilized in the development of the cost estimate in this study is consistent with that presented in both Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates, AIF/NESP-036, May 198b and Revised Analysis of Decommissioning for the Reference Pressurized Water Reactor Power Station, NUREG/CR-5884, PNL-8742, November 1995. Specifically the estimating methodology used by KCES herein is based on the Unit Cost Factor (UCF) approach. In addition, current experience from recently completed decommissioning projects has been considered in developing the estimating methodology.

KCES has developed a database of unit cost factors specific to the work activities associated with decommissioning a nuclear power reactor such as the cutting of a section of six inch contaminated pipe. These UCFs define the duration of an activity on a unit basis, including for the example above, contamination control set-up, cutting, capping pipe ends, removal from area, removal of contamination control and productivity adjustment factors. From the durations, local labor rates and equipment and material costs, removal costs are determined, including associated consumable costs. Material waste volumes, man-hours, disposal costs, packaging costs and transportation costs are also determined, again on a unit basis for each UCF. Each UCF is adjusted based on site specific factors such as labor rates, transportation costs and disposal rates.

The first step in developing the site specific activity removal and disposal cost is to develop a site specific plant inventory. KCES developed the.structure inventory for this estimate from current site specific drawings supported by a site walkdown. The systems inventory was developed from the site component database supported by referencing flow diagrams and the USAR. The plant system inventory list was separated into contaminated and non-contaminated components and unique unit cost factors were developed for each radiological condition. The site specific material quantities are then multiplied by the appropriate UCF to determine the total activity cost and removal man-hours.

The decommissioning activities are inserted into a project schedule and sequenced based on order of performance. The schedule hours, as determined by the UCFs for each activity are then incorporated in the project schedule to determine the critical path of the project. The schedule is then divided into several periods. Each period is defined by an activity or group of activities requiring a specific amount of oversight or support. For instance, during the vessel internals and reactor vessel removal activities the Utility staff, DGC staff and security staff are required to be maintained at a certain level. Once these activities are complete the levels may change based on the controlling activities.

Page 29 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0 Period dependent costs are those costs that are not specific to the decommissioning activities but are required as support. Costs such as those for the Utility staff, DGC staff, security staff, insurance, health physics supplies and energy are calculated on a monthly basis based on the major activities defining a given period. These monthly costs are then multiplied by the duration of the respective period to determine period dependent costs. The activity and period dependent costs are then summed to determine total decommissioning costs.

These activity and period dependent costs are either spent fuel storage related ( 10 CFR 50.54(bb)), decommissioning related (10 CFR 50.75(c)), greenfield (g) or a combination of the three. KCES has separated costs in each of these categories during the estimating process.

A detailed decommissioning cost table is presented in Appendix B and is summarized below.

All costs are presented in 2015 dollars. The summarized costs include contingency.

9.2 DECON WITH INDEFINITE ON-SITE DRY STORAGE The total cost for this scenario is $1,634.0 million fixed and $4.9 million annual, as shown in Table 9.1. A total of $529.5 million fixed is attributed to the preparation and transfer of spent fuel to the ISFSI. An annual cost of $4.9 million will be incurred for the continuing maintenance and surveillance of the ISFSI. A total of $909.1 million is attributed to the decommissioning, and

$195.5 million for greenfield. For this scenario, there is a large fixed cost required for the design, license, cask procurement, and construction and installation of the dry storage facility.

There are also annual surveillance costs, NRC license fees and NRC inspection fees. The cost attributed to the operation and maintenance of the spent fuel pool has been optimized by minimizing the spent fuel support systems. There is an additional cost of $57.0 million for the eventual decontamination and removal of the ISFSI.

An ISFSI will have been constructed during operations in order to maintain full core offload capabilities in the spent fuel pool. The existing facility will be expanded shortly after Unit 1 shutdown to accommodate the long term storage of spent fuel. The transfer of the spent fuel assemblies remaining in the spent fuel pool at shutdown, to the ISFSI, will begin just after Unit 2 shutdown. This transfer will proceed at a rate sufficient to allow the spent fuel pool to be empty approximately 7.5 years after Unit 2 shutdown. The maximum number of spent fuel assemblies stored at the ISFSI at any time will be approximately 6,552 requiring 205 storage casks, 111 of which will have been purchased to maintain full core offload capability and are an operations expense. In addition to the spent fuel, 168 spent fuel size containers loaded with GTCC will be stored at the ISFSI, requiring an additional six casks.

The existing ISFSI and infrastructure will have to be expanded to accommodate the post shutdown transfer of spent fuel. The additional pad and infrastructure will cost approximately Page 30 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0

$135 million, before contingency. It is assumed that the Holtec vertical storage system will be utilized in the ISFSI at a cost of $2,000,000 per 32 assembly PWR canister and overpack, including welding services.

All casks purchased during operations to maintain full core offload capability would be expended prior to Unit 1 shutdown, so would not be an expense of the decommissioning trust. A total of 111 casks will be purchased after Unit 2 shutdown at a cost of

$222.0 million, before contingency. All costs associated with the operation of the ISFSI such as staff oversight, maintenance costs, insurance costs, etc. are included in the 10 CFR 50.54(bb) costs.

TABLE9.1 50.75(c) 50.54(bb)

Greenfield Total PERIOD DESCRIPTION Cost Cost Cost Cost U1 & U2 DECOMMISSIONING PLANNING COST:

$50,041,436

$173,086,201

$223,127,637 2

POST-SHUTDOWN ACTIVITIES COSTS:

$126,358,434

$153,329,659

$279,688,093 3

VESSEL AND INTERNALS REMOVAL COSTS:

$487,208,650

$169,529,044

$27,958,874

$684,696,569 4

DECONTAMINATE BALANCE OF SITE COSTS:

$245,493,342

$27,478,897

$20,813,681

$293,785,921 5

CLEAN STRUCTURE DEMOLITION COSTS:

$5,493,075

$144,693,529

$150,186,604 6

RESTORE SITE COSTS:

$548,766

$2,004,798

$2,553,564 TOTAL COSTS:

$909,101,862

$529,465,643

$195,470,882

$1,634,038,387 7

ANNUAL DRY STORAGE

$4,912,735

$4,912,735 8

ISFSI DECONTAMINATION AND REMOVAL

$56,952,278

$56,952,278 Page 31 of 32

Knight Cost Engineering Services, LLC KCES 2016-100, Rev. 0

10.0 REFERENCES

1. Radiation Safety and Control Services, Inc.

2. Smith, R. I., et. al., Revised Analysis of Decommissioning for the Reference Pressurizer Water Reactor Power Station, NUREGICR-5884, PNL-8742, Volumes 1 & 2, November 1995

3. Laquardia, Thomas S., et. al., Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates, AIFINESP-036, Volumes 1 & 2, May 1986

4. Taboas, Anibal L., et. al., The Decommissioning Handbook, ASME, 2004

5. New Horizon Scientific, LLC, Maine Yankee Decommissioning Experience Report, Detailed Experiences 1997 - 2004, 2005

6. R.S. Means, Inc, Building Construction Cost Data, Kingston, Massachusetts, 2015.

7. NRC Rules and Regulations, JO CFR 50, 61, 71, 72, 170, 171

8. Cost Estimating Guide, DOE G 430.1-1, March 1997

9. McMaster-Carr Supply Co., Internet catalog 2015

10. DOE/RW-0567 Acceptance Priority Ranking & Annual Capacity Report, July 2004

11. U.S.NRC, Office of Public Affairs, Decommissioning Nuclear Power Plants Fact Sheet, 2008

12. American Nuclear Society, Disposal of Low Level Radioactive Waste, Background Information, revised February 2009

13. South Carolina Department of Health and Environmental Control Bureau of Land and Waste Management, Status of the Barnwell Low-Level Radioactive Waste Disposal Facility, February 2007

14. Gregory B. Jaczko, The Need for Alternatives in Low-Level Radioactive Waste Disposal, June 26, 2007

15. U.S. Dept. of Energy Office of Civilian Radioactive Waste Management, Total System Life Cycle Cost Report, July 2008

16. U.S. Department of Energy Office of Civilian Radioactive Waste Management, Report to Congress on the Demonstration of the Interim Storage of Spent Nuclear Fuel from Decommissioned Nuclear Power Reactor Sites, December 2008 Page 32 of 32

Knight Cost Engineering Services, LLC APPENDIXA SCHEDUL;E KCES 2orn~100, Rev. 0

ID.

Task.Name.

1

j Dry spent fuel storage

2==I Posi:shutdowfl wet siorage

~I:if tr;;;;;;;;~.*.**

- - . r~*.*1**.***..

r:ieiine systems modification

8.

Design *systems modii\\cation*a~i:i ~quipmeni specificatons.

-g ---

Prepare Installation procedures......

1 o.

Prepare iest pr66ed ures

11 -

Prepare iiialhtenahce prc>cedures:

. 12** 1 Control room'reiocatlon

-1 ~ --1 *............ Define control room equiprhe~t 14.---1.

... Design coiitrcifioom:rriodificat\\on iind. equipment siiei61tii:iati:ins*.....

"-Js-:-1..

P.repaie instaHaiioii prqce*dures ******..

16 *-I *...... Prepare test. procie#ures uJ Tii I

. Prepare maintenance procedures *..

Deslg'n spenf ftiel storage security mociifl~atlons

.** 19.l

. 'DesiRn inociificati6ii and equipmenfspediicaions Define mbi:lificaiion

.. Prepare* insta1iation procedures..

Prepare tesf procedure~..

-~n

~~;:~1** *.

Pr1m::7;:t:

1~:::~~j:{~::1~~s 75*-

beline scope..

26 Evaluate pfocesses

" 27 *1 **

..... Prepare bid specifications and RFP.

. 2~j... auauiy coniradors.

29

J

.... Evah.lat.e Proposals..

30

. *31.

~-

-33

.,.-'fl;!

35-

3s Select'Decomnilssion ing' Gsneral C11ntractor

'oefine scope*

Prepare b,ld speciticaiici'ns: and RFP Ciuaffty coilfradors Evaluate Proposa)s'..

U1 &,U2 cold and dark site repowerlng

... r:ieiine scope 2015D. c. co.ck

,Scenario 1

Duration.

1926.Wki! j

.,. *s~: :::l Wed 12125144 *

() days ** 'v;.ied f0/25/34

... sis days i Wed :1012sfa4 *. tue 1*2,2213fi.

~::*~t:l ::: ~~;::i:::.. ~;i~6;~:;:t4; 1ea*clays' MoiishB/35!

'.Wed 2/6i36. 7*

so aays, Thu 2/7/36

We,d 5/28/36 i a....

aiiday~. thu s12eia(.... wedilhiiss':e so days!

Thu 9tfs1ss !

wed 1ftisi 16 624 ~11ys i Wed 10125134 \\

Mon 3116137 168 days! Wed f0/25/34; Fri 6/15135'!'4

. foi.iiays Mon eiis1:§'s i ' Mein -ii1'4i:ie i.13 aO days°l Tye 4h 5/36

11/1011 8/4/36 i j.f 80days!

Tue.. B/.5/3fi Mpn:11J24i~5 :15

,ai:i days : Jue.1112sf3e f... Moii ai1ei31 ; 1 e.

so.,1 days :

Weci1oi2sfa4 i Wed 1 Oi2p/34 !

Mon 9i29/3B '.

Fri'2l.2a/3s !4 *

- - ifo days:

176 days:

Moii.212ii1as;... Mon10129i:is'\\fa eodaysj. Tue 1Q/30/35<

Mon2/1a1:fo;20

~ci days :..

Tue.2119is6 Mon 6/9/36 i 21 so days:*

foe's/1 oi:fo;.

Mon si2ei:fo 1.22

... s20 days l* Wed 101~5/34 t fue 1012113s 80 days Wed f 0/26/34. :

fao days. Wed 2i141ss l Tue 2/13/35 '4*

Tiie 7131135.2s

160 day$

Wed 8/1/35' * ** Tue 3i1fi36 i.26 ao days i 'Wed 3t12i3!l l.... Tue ii11aa12t aodays 1

-~~~~1~136L tua10,21i:is*'2e*

&Mi days,, Wed 1_,Q/25134, Tue 4ij13i.:

2,00 days ! Wed 1012i.ii34 :. Tue '!/31i3s'Tf

240 days

Wed8/1/35 j

. Tu{tif13eTa1 120 day:;;:

Wed7i2i36 i' Tue 12/1$13i( ~2 *;**

so days i' Wed 1°2117/36 Tile 417/37 '. 33

. 680 days i Wed 1 Oi25/34 i... Tue 612/37,.

160 days \\ '-W~d {oi.25~34 !

'Tue 6i5/35 j 4

=~~=-*---~~i~~~~~~~~~alib~ and e~-~~~ehtspecmca_t~~~---*

- - .. *--..... ~~-~~**:..*.. Wed ~--*:T~~-~7-~~1}3~i :fo.

Page 1.

i I

.fa1s:o.,c.6ook Scenario*f ID (TaskName _____ ---~-* **-*-*--*----***--*-----.

--~--1.

l?repare Installation procedures Duration*

._.*.. §tart _____ ~nish. -* Predecessors _ _Jf3j3J3j.~3.3 3J.3J~J3JAJ:4.414 4 4 4 4J4

**, * *,240'days

Wed 3/12/36:

Tue 2/10/37, 37

'

I ac,*days.

vyed 2hiia7,

.. 'rue 61~1~j\\s *******.. :... *... *.*. *_.*ji

/' 1 : : : :. '.

_ : i ; ;

2sneiay's wiia,1012s134l Tue 11'12oi3s,.. *.....

. 80 days\\ Wed 10/25/34... Tue 2i13/:is :.,j 3 9 Prepare test procedures

~--

l\\'fodify U1 &.U2 pontalnment access

~ 1 J

Select new accessJocatfon

'42-

43

~--**

45

,, 46--.

47'"

--,fa*

49

,-5()-

. besign access aml eciuipment speciticatpns th & Li2 SlteCharaeterization.,..

berine scope Prepare bicfspeclficallons ah~ RFP

...... duality c,oniraciors '

.. Evaluaie Prdposalsi Prepare* pmc~d\\lre~

. ADMiNISTRATIV't!:.ikii1vit11:s,,

bave1o'p sta#Yrarisltion plan 1 -

Devefrip sa~er~h,ce iuid retentipQ poi(cy,..

s2 Prepare proJect admlnistraii've proceduiiJs..

5a -* 1:.

Develop areh 'based dei::orrfrnls~/bnirig :cosi estlm~ie

54.

Deveiap prdje<::t budgetarid scheduie CC>htrols

-"ss *j Assemble plari!tiraivirigs 66 * ********

. Define end ptoducl

-~

Develop te~~,iical approach and pe~aiie£project plaris' sa:-*1 uceNslNGiPERIVJITTING bocuMENTAi'10N

'"ji{f-:1, ' insurallce exampti6ii" '

, 60 I,, Prep'a(e Post~S&utdoyin Detonimissiqnirigfl;ctlvities Report 61 J.

i>rep~r~,certliicaiii,ri oi permaherii cessaHon'oioperations.

6:~~-~-..

Prepa're~rtification 6tpermarien\\reacto~ d~Fuellng....

_... *Prepare post;shui10Wr1'te6ftiiloa1 spedfi'ca.i1oii *modi!icaiioris.

,,,, µpdaiEl FsAR,.

65 D~velop certiftedduei ha!Jcller pr~g~m,,

.. 'sit ~L ', i=frepare pc,s(-stiuidoWri efl1erg~ncy pJan

-~..

Prepara:post-shutdown QAplari

~a, *.. p'repare post-stiuidown secor1t(p1an.

- e!i-1., Prepare*posi-shutdoiv~:r,rii:iroiedio;i plari.

l,.

'200,day_s,., We9 2(14i3S:i, tueT1'iioi3:s: 41

, 590 dayi i Wed f'i./27/34,,

Tue 3/31/37f.

120 days ' wed 12121 i:iJ'

. Yue s11213fi'ssi=~i1s days

.. 120Jays Weci 6/J 3/35,

Tut;1 fli2ii:i$'! 44 120days Wed9l1Sifsi, Tue 3i4/36]4si=s,s6ilays 80 daysi Wed 3/5/36 Tue'st24i36 ;4e 206 da,ys\\. We8 6/25/~6 \\

Jue atM /37 \\ 47 a2ifdays i Wed {Q12s134 :

foe 12122i:i1 i 120 days i wect 1 oi2s1§4 Tue,i11013s : 4

.,,, 120 days; Wec!.4/11/35..

T\\.ie'e/25/35 50 8Qtjaysi Vved,.9/26/3f[

Tue 1iisia6 s*1 326 days, Wed2/2013ai i:;ue ~/1213f ~7F$~1e:,wks:

1 sDdays' V)/e,d 5113(~7, 1\\ie fai2273't! ~3 12q cia;i' Wad 1012s,~

.* Tiie 411013s 1 4

120 days Wed 10/25134,;

Tue4/10i35T4"',,

320 days vve(f4f1"1Jas i... Ttiiftt1!3'il\\ se

.. 1ocio days i Wed 1oi.2s1s,i*r

-'rue ai2413a i

.. 120.daysi wed 1012sia4'*

rue 4/fdi3~'j4**

24() day~ : ** wed 1012s134<

Tue 912s/3s 1 4 '"'

)fdays wed 10,2siM, Mon 11/21134 :.'-i' 24.daiis! vved1012sfa4_'

Man f1mi?414 440:days '. Wed 10/25i34 :.

Tue'?h/36 '. ;(.

4PQ days': Wed 10125134

Tue s,a,aa,i :.i 12{) day~ ;, 'wed 10/25/34

.,100 aays':

wed toi2s,~

i20 days \\' Wed 1012si34 aiodaYs: Wed'1012s/34 i

. 's2o'days] Wed 1bi25134 a20 days ' vvad 10,2s134 ;

Tue 411 o/a's' 4.

. Tue siai3o ; 4 Tue 11151aa 14.*.

~

*.~;~:~;:./*:

tiie 1115/36 : 4 *****

7~_j ' '..r~pare pos(*ShLj!~O~t1 'radiation prot~°"ti~n manual.

71 1*. Prepare and.submit slate anq,localpeririits 320,ciays, Wed 10/25/34 i*.. *Tµ,e,1l1$/36i'4

'1*r**...,,,,, 'Respond to NRC qu,estion~.on PSDAR 24 days.j. Wed 9/2S~as i Mein foji9i35'i 60

---rs*,

Prepa're defalied'res6ui:ce' ioaded projefo(schedule 480 days ; W~d 10125/34 Tue 8/26/36 H ' ;

- 74 -:.. Perform 50:59'unreviewei:l salatfquestioris' 246da*ys!. Wecf1oi2isi:f,i',.

Tue~i25/3514

*.... ¥..,. A~*********-*-**.. -* * '*-***"*."..... '..

-**<<**n<-*-*.-n...........,...,z*--~~"~'

", ---*-*-.. ~;....;, *****-~.,----*-*------

- - "*- **~-~

Pa9e2 r*

,.,,.~,¥ I I I

I

... I

-.-~-:---*

2015 o. c. cook Scenado"1 *

.. JQ.

.TasK. Name....... -.. -,----.............

75

P,repate,activity speclffcatiohs h,

_a... ' \\.* ~- D~~ci~~a;s : ' w~J%~25/34L.. :T~~i~~4/~;

4redecessors *...

""76 Prepa'ie a~tauaci work proc~ci~res*

. n.

s'elec!sllipping c~sks'and" obtain 'par{llits' 78 rCENSE TERMINATION Pl.AN

- 79 General information. '

---ga---

Site Characterizaticin

s1 -

Identification of remaining site dismantlement activities'

. 82-*]

- Retnediation.Plans:

~, -*

~\\na_l Radiatiqn Survey Pian

~..

compliance with. tiiera 0dlologicalcritefia forlfc~nse formlnail~n 85 "lJpdaie decomrrilssioi-iing costestimate.

s.t-'

supplemeni foihe eriv)roiimental report.

~

.... Resiiorid*to.NRC'questJons

"'"'s8 UpiiaieT.rr Unif2 Down

r>ilrli>d 2 Post-shiitdbwti Activities.

~-***

_92-:-.

93'-'

-"94

.. 95 96..

9!1

""98~1 I

.. 99~.

1DO *1.,

101;*

.. -.......... J.

102 I

1D3

- 105*-

~i

-107:

Mod1ry'spen!Fuel CoqHrig System

. fv1ociify controfroom Modify security systeiii

Primary SystJrilbe~n*

Flush &'brain 'Systems

. 'Implement coid & dark,..

.. Modlry:u1 Cont~inmenfAccess..

. :Modify iJ2toniainrrien\\'.Access Historical s*He A;sess'irient Vesse(and. int~foais activatlQri an~lysis. *.**..

.. characterization survey..

Testspe6iafe9GTp~eht ahdtraining.

End Pert6d 2 ***

. Remove'unit fieaot6tveli~el intern~ls andreaciorvesse!

. rr'aAsiet Eqilif.im~htto uriii 2. *.

Remove linit 2 ri:iactor vessefinlernals and reactof.v~s~'ei

1:ooJfd~ys * ** Weci1012si34;"

rue a/24fas *

4 240 days * *wed 1 ii12s1a;t " *. 'rue 9125/35 4 11Mci~ys'." iJed1Q/25/34i M.o.il 311.4139; 16 days wad* f 67:isi:i-4'*

Wed 11115134 4 60 dtiys i, Thu 11116/3,4 Wed,3!7/35. 79 BOd,~Y~ j Thu. 318135 '

Wed 6/27/~5 BQ

'40 dafsi **. l'liu s12ala~J Wed a122ias i a1

'rhu8i23/35 J Wed 6i24/37iB{

480 days*

Thu. 11127 f:il(

Wed 2h7j:ia. 83FSc1 so days

i'iiu 11ifo134 **. We'rJ3171as '. 'fa Wect6/9/3S

84 I I ! !

80 day_s BO.days**

1*

80 days ;. Thu 6/1 a,a*s Wed 9/29f3s 86 1

11

~ ::~:. --~::~ :;::~:; * -,~~:\\ !~::~::.. ~~.1;'.23,29,34,~:. l

2iiodays I Wiici12123J~Yi 'ruii12i211ja * *

I

173 days; Wed12123/37T..... 'i=ri's12oi3a ! ae 1

1fadayf:

M9ri3111i3sl w.ea.101271sa)~1s'.12,saavs

I 1!~ day5j

w**-**eMa*. o 1n 2a 1

2 1

3 11 1

i 3

}

7

.

We(f?/~7/36 /~1 F.M25 days 40 days,:

Tue 2116/38.(89 60 da~s

\\/Ved 1217,.3131 Tue 3'16:'3sf a~

I

. 240 days,) Wed 12123/37; Tue 11/23/38/*BS

. j 160 days,: We'rJ'12/23j3f.

Tua s/21sil ::a9

15oi:f~y{!

wecf5h2ha

'rue'f2i.21J3ef9if'.s.ao,di,1ys

. 240 days !' Vl/ed.1. 212,J/3?

Tue 11123i3a I os

21s:d8yS *wed 12123/37 "TliE(1o/19/3a*l*BEi.

2so.days Wed 1212ai_37j.

tu~ 12i'j1asi~il 215 qays, Wed 1212ai2i. foe foif gisa 'leg I

o clays, l'ue12i2113a.: 'rue'12i2113s [ s4;9~;ii6;09,ioo.)i

~29 days VVecH2/2V38 i Tuii'1/1l4(..

'4s6'days wed 12'122ise' fue"sh11i+(1oa..

4 wks i Wed 9112/40 *

. Tue 10/9140 ;, 105 450 qayi*! 'Wed1oi1D/40;*. 'Tue i1Ji42 hoe *..

. *1

-*10s ***

.*.* R~move tJnit 1 steam ge~erators

¢§\\vks Wed]/12146 : Tue 12ifol4 ( -165

........... *1:

"'"'10s"

-***rnr-11c

. Reri16ve Unit 2 steam ge6ei.r.;tois..

',, 65 Wks : Wed 12/22/38 Tue 3/20/40 j 103 Remove Unli1.corifaminaled. sytitemS:.

105 ci.~Y~ j V\\led 9/1?140[.

Tue '2/5i4i (165.

..... *I

. ~rimove_uriu**~cie~-~~!~~-s ____ ---- -. *.*---.. ----* *' -*--*--*---

3~3:~~y-~s~~w~*e.~d-'s/@4oy '.. FrT2i1~~:~~ 1~:.. ********** *.*.

- . ' J... ' -'-.',_. -.*.. *. *-' *-.

' --~~ '

Pages I I I

I I

I 2015 D, C: Cook Scenario,1 ID.. Task Name... ***-.---******..

112

Decol) Unit 1 reactor building 113

-rr4

.. Remoye misceilaneious sfructures End Period 3

__......... **...... L... Duration Start ___, __ finish __.!.Predecessors........ 3 3 3 3 3 *.3 13 3. 3 I l'll,1 i 4 l 4.l.416 J 4 4 4, 56 days Wed 2/6/41 Wed 4/24/41 '110,111 I

8 days Wed 12/22/3~

Fri 12/31/38 103

/ ;

-~~8.Y~iJ Tue7/1./42J

.~~~]/114_2;.108,109;112,113,7 1

1

-*115--, Periocf4 i3uiiding clecontaminaHoii 11a.

Remove Speiii fuel storage *raci<s.

117 Remove uiiff 2 contaminalect ~yste'ms.

1.18...

... 'Remove Unit 2 cleansysteiiis

~..

ReirioveTuibina Building.

120 -*

.. Decon Steam Ge~erat~r Storage BijJiding 121 oecon lin1!2 Reacfor~uiieitiig 122..

Decori Auxliiary Bu1fding 123-:-1 End Period*4 124-Period 5 Clean Removal

~= '. *

- *"*::::::**.:::: ~:~::~;;~:~::v at ai1* st;:u~fores *:

--w:-*.

bbtain f'lRC approval' '

--:fza**. Remove Unit,,. react6!'buiiding 12"lf'*.

' Remove uiiii 2 r~ac(orb'uilding 130

. RemoveAuxiilary Building

'13.f-....... Remove steain Generator storage su'nding 132.

Remove Admfnistratiori ti.uildlng..

13,3.. *... 1*

Rernove Low,Level Raciwasie building

~

End Periods

. ~:;=lPeri;de:t::~l~t~tie:.*

1. 37 * ! Period 7 Dry Storage

--.. -~..,,....

138 I Dry Stci(ilge "w-*j Pei-lod 8 isFS.1 Removal

. 146]_ b~c-~~-8..~~r~~~ve'i_~!.~!: ____ *.....---

~-

822 ~ays i Wed 7/2/42' Thu 8/24/45' 1

8 W\\<S.

Wed 3/29/45; tue's}23j451{4,3,.

...*. I

1a,!days, Thu 9/22/44'. Tue 6120/45'.116FS-174days 11io'i:la\\is"(

Wed i1211i2 rue3/24/.43 114 188 days Wed 3/25/*i:31 Fri 12111/43 :* He...

35 days * *wed 'm/42J Tue i@\\142 114 55' qays

.. Thu 9;22i44 Thu 12/8/44 r 'l17SS,f1e.

.,ffdayS!. Vve{GJ2fi45'*... thu,ei24/45 i 117 o days 'i Thu 8/24145 l Th~ 8/24/45 \\ 122 39fiiaya

... Fri. 8/25/45 '

Mon 2125/47 ;

ils wks 1 **

Fri 012sMs. :,

ThU 5/3146 ! 123 36 wks'

- - 'Fri isi4t4e" ** Thu 1ho14f<,*2s

.*.. Odays*:

..... 80daysf Thu*1ft0/.47

°Thtj'.1i16/4ty'12a;12s

Fri 5/4/4fl..

Thu ii/23/46 [ fas 80 day:(

Fri 5/4'46l. Thu 8/23/46 \\ fas 1'32cJays I Fri 8/24/46

, Mo,n2/2Si47: 129,-126' 40 days Fri B/25/45' "rhu'10t.19/45 \\ 123

31 days i... Frisi25/45!.

Fri 10/6/45: 123.

eij days :

Fri ei25/45 '*

Fri1112414i;" 123 6 days'

'Mon2125/47.*. Mon 2/25i4i: 12'9, 131;fa:i;fa3,1, 40 d<1:ysr Tue 2/26/47 :

Mon 4/22/47 ;'134 Bwksi 'iue2/26/47' Mon4/22f4ii134 iilodays.

me 4123147,.. Mon,i12cii4a::

s2wlis1

- ri.ie<1i2314t *. Mon 4i20/4R !136...

84days' 16,8.wks i Page4 Tu~*4i211.;s '*

Fii,ah4i4a :

Tue 4121/48

Fri iiii4i,iif (faii

-*"*---. --**......,..,-~-~~~** **.*'

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

I

, I 21

~*

,, I 1

Knight.Cost Engineering*services~ LLC

.APPENDIX J3 COSTTABLE

~CE.S 2016-lDOr.Rev. O

. _'rn,..

h

- h PEIUOD 1

Ul 8 U% DE:COMMJSSION!NG PLANNIHG COST:

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'22,178 f56.7711

$1.1m'.,711

$9~7fl

$1,958",1<1&

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1

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$4'M,all4

51,600.c~~:

$760,002~

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$,435,709

$1s.81s*

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$~,119

1321,sioo 11wo*_

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$114,00CI*

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$~JI~*

'S6H,600

$557,000

.U8.&'ll-0,IU5B 110,4!2,COO

-$3,871:1,010 tl.794.. 123

.$1,211,63~

"$44,030

~69.~

$1,Pe4,1W

- - s900,i1ro sci..i"'9,018

.1:1::n,.000::

31_00,82£1.

4651,900:

!581,000

$161,700

-s11.200

~.-~~:

S11lil~OO-

~?~,IJOO 11&'.),000 1l!t1.:i90_'

.s1~.100*

$116.ooci."

.. $10.000*

tf5.1B7,1.:i'O.

'2..Ht,'"1)(1 i.c4,1~s.s1s..

S-ttBt"G,3oo**

with

'tAA_fina~J'ISi..i*,

$549,766

$:Z,004/111 1s-1n,1Bo 11.930.Jm

S:~i.(002

$:?20.000

,1:~2,M&

479,io9

S1B,57!1 S2-U7B

$6-4,678

.14,sta,he

no.40Q,Bti9-

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-s'11s,,r23**

S1.393,330' t55.&30:

S665.43-1.

$1, ~00.011.

,1,133,HG

&1,000.319, f:f.$13.300

$115..920,

..$m/,65£1 i:5:i,e,2 S1f.u1~-i:zo S!11.M2,:mi Stair 12,807 54,8:!IJ

Tol:ll _.1oerR*~.75(e)i c:Or,irruiri Subl~al ~~1'!h1r_d (gj.

Oo_lllm~ SubtO!al SO:~~ {btil

-"5_RIODC'EPEMr;>:ENT.

Cii111mon Toul:1ocFR 6o.76(bj:..

~om"mon Sublotei a11onfl11ld (Qf Colf!in.i;m Stbl<it.1.40.54 '(tlb)

Vtit\\Ul\\1'iu-c-cmn1011 Totii 100FAS0,7B{e)~

Toti:iG1l!lenfleid{(I):

Toto1Eo.54(bb} *

"rorAl..AClMrt<'.lOSTtJ:

UN1r1 umr1*

G11B.T0tAL UN'lr.1 10 OFR !tl,7G(C) OOSTS FOR ~En1¢DS t ~,..

.*sl1Bl01AL"UNIT 11Q CFR 5M4CbbJ COSTS FOA "rnruOos 1.e

SuelOTAL utrnr 1 C!Rml_F!ELoCosrs FOR ~~s:,t ~ tf

.stJ9TOTAL I.WIT 2 10Crf\\ GO,r&{CJ COSTS PO!\\ P£Rl0D5 t ~t CtmtoTAL UNIT 2 10 CFA 60.~-l{lruJ COSTG POA PERICOS 1 "ti sU8.JOT.Gl:. U_N'! ~ '?,RE~HF)~Lt~CO~TS Fo.:t Pl!'~9.1'*G.

COtJMO!f ' =~:i::~~~~!~~ ::~=::=!{ti::s'7~:=\\!~

sue.TOT'~L i::Or.f¥.oN liRE£NF~.E!Lt).c0aTS Po.rt PER1oos 1 !*o TOTAI.PSRIOO DEPEN0ENT.C0STB,

.;~atorAL wit _1 1~ cm ~.7&!CJ cO!irs fOR Pb~oD!*.1, s.

&uttfOTAL.Vltrr 1*10 tFR GO;B.tlbb)Cbsnir0RrERJOOS_1. 11 siJ~orAi. umT 1 GREEN~1EU)eo5rs FOR Fa\\lODS:;.:-t suetoT~L umi 2 *1r. ~n\\60.?&(crcOs:rs _FORP~Oos,

e sue1orAl UN112,o c,R Ul,S.Slbb)cosn FOR PGAIOos 1 -11 euetotAL UNrr 2 oREENflE!Lo COS,s ftO~ P-tiRIOM 1

a

.COMMON suarot'AL COMMON 10*cFRso161cJ cos1sFcn PERlOO!l 1-.A SUBTorAL CO"MMON*10 CFR w.~fbb) cos rs FOR PERIOD& t :. *

!Uf:ITOfAL COMMON QRfBNfl!LD eo5T;5 fOR.P°eRld0$ ~ *(I:..

AHNllAL sPeir FUEL srORAG&

wm-1, uNrr 2 a eoMMOrl 0AAH010TAL AOTJVJTY cosrs f'oA PEA.t'oos*,..e ORA~O m~ r6~~ OEPEt~(f.l,:,cosTs Fei!\\ PB~IOOS 1-6;

~N?!\\L,S~enr ~~et. Bl~~~~

CRA.'IDTOfAL

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~::::~:.: :~: :~;~ ;:::~:-~N~~~:~.: ~~-~: ::t:~}:

S~BTO!AL ~Nii 1 ~eo~.P~~RAM flllANCIAL ~lAflMINCi COST F:Of\\ tJRt!NNP18..D fgj:

tumor AL uN1T ~ ~CON PROGRAM FIMAildAL PlANMN'o coSnOA 10 CFR r.o.?~cJ:

SUBTi;tiAL IJNlt' 2 oicON PROGRAM JllNAHCIAl. PLAM'J1NG cosrr:o,t10 Cl'R Gtl.S((bb)!

s~m:~,~L.UNr1:- ~ D£eotJ P1t09RA.M f'.WAr-JCIALPt.AriN100 cosr r-On QR6f~Plr.1::b (g):

~tiBTOTAt.C~rt1MON OEcon PA00~;11'fll.N~!AL f't..Af1N1NCJ COST1'0Fl 10 CFR 60,f~c):.

suer'oTAL Cor11.10N De.CoN PRooAAM PiNANCTAL PU\\Jn1rNG cosTl'Of\\ io CFRSU4(bb)i slleTOf>,L COMMON 0£COPI.PROGR6.MFINAN<l1At. PI.A~!N(J <::~S1:°-.F~i,~~~tffll'reLD.1?)!

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TotN. uN~r ~* & :i OEcON PROGRAM FtNANC!At. rLANNINo*~T-,-OR 10 Cp_1(Pio:.S-1{tb):

tOTAL UIJIT t ti 1 DEiCotl PROG~ FINANCIAi.. rLAP-Mtf.io cdsr F.Ori <ml!NN~l!LD ~g}:

oAAr.o toTAL

su,r,1,nO' 1183,760 1222,4s.a;.u1.

930,112,93'7:

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'l1H,6B11.11J.

- sflSG,_6~0 110),Tle.o.2t t1ss.a8tl.e11 t63,aouor'.

t-'°3_.E2:2,1Uc Hi,31~.545 0,ff5,2-31

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= S1n,B1;r-,9311.

s-1J;.11G0,800

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=t;.qo,249,34,

'?~502,83.0

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Knight CQst EngineerihifSeivices, LLC APPENDIXC

'CASH FLOW TABLE KCES 2016-100, Rev; 0

ZO,,S o. C Coot

~cenalio 1 Ora~,.

OECQN and_ Permanent.On-Site D~ Storage Scenario 1 -Yearly costs:

UNIT1 Packaging,

. Ccintlngericy far Total fcir 10 CFR 10 CFR 50,54(bb)

Maierial&

T ranspoi:tatlon 8, 10 CFR 50.7!i(c}

50;7S(c)'and costs with.

Year Labar

&iuieirient Dls~I EnelJ!r

Other an<l Greenfield Greenfield..

ConUn9enct 2034.

$1,598,700

. $42,60{)

$0

$202,200

$186,900

$308,800.

$2,339,200 2035

~;715,300

$232,400

$0

$1;102, 100

$1,018;800

$1,683,600

$12.752,200 2036

$8,715,300.

$232,400

$0

$1;102,100.

$1,016.!!00

$1,683,600

$1.2;752,200 2037

$8,§?2,30()

$257,100

$111,900

$1 ;075,BOO:

'$994,500

$1,720,500

$12,782,100 2038

$5,011,000

$1°;272,500

$5,262,900 so*

SQ

$3,485,700 s15;os2,100 2039

$11,865,200 S1/156,000

$26,572,600

$0

$12;597,400

$52,491,200 2040 S1t865;2oO S1;456,D00

$26,572,600

$0 so

$12,597,400

$52,491;200 2041

$11,865,200

$1,456,000

$26,572,600

$0

$12,597,400

$52:491,200 2042

$5,890.300

. $722;800

$13,191,700

.*~

.0

$6,25.3,900

$26,058., 700 2043

jiO:

$0

$0 so

. so 2044 so

$0

.$0 2045

$1,955,700

$967,500

$3;611,100

$0

$0 s*1.12s,foo

$7,660,400 2046

$5,467,600*

$2,705;000

$10,095,900

$0

$3; 148,3fl0.

$21;416,800.

2q47

. $795,200.

$393;400

$1,458.~0 so*

$0

$457;900

$3;ft4,800 2046

$0

$0 so 2049

$0

$0 so so

$0

$0 2050 so

$0

$82,367,000

$11,193,700

$113,4 79,60()

$3,482,200.

$3,219,000

$57,6!,0,600

$271,402,100 Rounding Allowance:

$52

$271,402,152 UNIT2

Packaging,

<;ontingencyfor 'Total for10 CFR

10 CFR S0.1;4(bb).

Material &

.Transportation &

10 CFR 51L75(cj 50.75(c) and

costs with Year Labor Eijwpinent Disposal. $0 Energy

Other

'and GieenfiCid Gre<:nlleld

Contingency 2034 so so

$0

$0 2035

$()

$0'

$0

~

$0

$0 2036

. $0

$0

so

$0

$0 2037

$115,000

$30,300

_s111;eoo

$0

$77,100

$334;300 2038'

$4,772,100.

$1,249,900

$5,140,100

$0

$3,375,400

$14,537,500 2039

$3;106,600

$626,300

,$21,337,500

$0

$8,554,000

$33,624.400 2040*

$3,106,600

$626,300

$21,337,500

$0,

$0 ss.s54;ooo *

$33,624,400 2041

$:3:106,600

$626,300

$21;337,500

$0 so

$8,554,000

$33,624,400 2042

$6,44.1,400

$769,800

$13,471,900

$0, so

$6;486,800

$27, 169,900 2043

$9,729,000

.$911,200'

$5,717,500

$0

'so

.$4,448,800

$20,806,500 2044

$9,729,000

$911'.200,

$5,717.500

$0

$4,448,BQO

$20;BQ6;S00 2045 ss:204.BOO

$,1 ;ss2.soo

$7;283,600 SD

$0

$3,983,600

$21,024,800 2046 ss,461;soo

$2,705;000

$10,095,900

$0

$o

$3;148;300

$21,416,800.

2047-

$795,200

$393,400

$1,468,390

$0

$457.900

$3,114,800 2048

$0

.. $0

$0

$0.

$0

. $0 2049

$0

$0 so

$0

$9 2050

$0

,so

$0

$54,573,900

$1Di402,500

$113,019,200

$0

$52;088, 700

'$230,084,300 RouhdingAllowarice:

$121

$230,084,421 Common P~cka~lng, contingency tor Tota1Jor10 CFR 10 _CFR 50.S4(i:,bj Material.&

TransJ)_ortaHon* & *

'-10.CFR;SD.7_S{c)

so.75{c) and costs witti' Year Labor Egulement Dl!!eosal*

Emirl!l".

Olhar and Greenfield Greenfield Contingency 2034

$492,200 sa:

$0

$73,900

$556,100

$_10;049,200 2035'

$2,663:100

$0

.so

$0

$402,700

$3,085,800

$54,781,600 2036

$2,6~.100

. ',' $0

$0

$0 S402,70Cl

$3,oB5;aoo

$54,781,600 2037

$4,085,400

$371;300

$22.7:

$100,700

$76,900

$736,2_00.

. $5,3?0,500

$57,146,900 2038

$60,563,500

$15,'197,600

$4,1%,200

.$3.217,300

$14;231,200*

$97,728,700

$150,968,500 2039

$29,983,900

$13,489,700:

$83?'400

$3,485,800

$3,019;000

$9,272,900

$60,084,700

$48,110,900 2040

$29,983;900

. $13;489;?00

$833,400

$3,485,800

$3;019,000

$9,272;900

$60,084,700

~:;~g:~~

204.1

$29,983;900

,$13,489,700

$833;400

$3,485,800.

$3,019,000'

$9,272;900

$60,084,700 2042

$30,757,000

. $11',867 ;600 *

$3,080,300

$3,395;200

$2,843,300

$10,035,400

$91,,978,800

$28,282,800 2043

$31,5.19,000

$10,268,500

$5,295,500

$3,:;105,900

$2,670;100

$10,787.100

$63;846, 1 OD

,$8,7'.34,900 2044

$31',519,!)00.

$.10;268,500

$5,295,500

$3,305,900

$2,670'.100

$10,787;100

$63,846,100' ss;134,soo 2045

$27,160,700'

$10,396,300

$8,476,800

$2,222,000

$1,991,800

$9,872,300.

$60,119,900 S6,917,700 2046

$19,334,100

$10,625,800

$14.:189,700

$275,600

s173;aoo

$8,229;500

$53,428,500

$3,654,400 2047

$<!,048,500

$1.852,800

$2,063,700

$62,500

$22fl,100

$1,518,800

$9,775,400

$1,080,300

,2048

$0,

$0

. $0 2049

$0

.0

$0

$0 so,:

$0 2050

$0 so

$0

.$0

$0

$304.797,3@

$111;617,70,0

$40,924,400

$27,321,400

$23,529,400

$94,895,600

$503,085,800

$529,465,500

Rouryding Allowance:

$371 143

$60~,086, 171 ji529,465;643

$136,940,900

$21,596,200

$226,498,800

$3,482,200

$3;_219,000

$1(i9,749;3Dti

$1,10.f;S72,745

$529,465,643

.$1,634,,036,387 Ail_nual storage cost

$4;912,700 ISFSI deoomtnissioning'Year 1

$33.123,000 ISFSI decommissioning Year 2.

$23,829.300

$56,952,300

ML18341A134

Contents

Text

1.0 INTRODUCTION

SUMMARY

10.0 REFERENCES

1.0 INTRODUCTION

SUMMARY

SUMMARY

SUMMARY

SUMMARY

10.0 REFERENCES

Navigation menu

ML18341A134

Text

1.0 INTRODUCTION

SUMMARY

10.0 REFERENCES

1.0 INTRODUCTION

SUMMARY

SUMMARY

SUMMARY

SUMMARY

10.0 REFERENCES

Navigation menu

Search