NLS2008098, Decommissioning Cost Analysis

Decommissioning Cost Analysis

ML083580119
Person / Time
Site:	Cooper
Issue date:	12/15/2008
From:	Vanderkamp D Nebraska Public Power District (NPPD)
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
NLS2008098
Download: ML083580119 (212)

Text

N Nebraska Public Power District "Always there when you need us" NLS2008098 December 15, 2008 U.S. Nuclear Regulatory Commission Attention: Document Control Desk Washington, D.C. 20555-0001

Subject:

Decommissioning Cost Analysis Cooper Nuclear Station, Docket'No. 50-298, DPR-46

Reference:

Letter from Stewart B. Minahan (Nebraska Public Power District) to the U.S.

Nuclear Regulatory Commission dated September 24, 2008, "License Renewal Application" (NLS2008071)

Dear Sir or Madam:

The purpose of this correspondence is to transmit the Nebraska Public Power District's (NPPD)

Decommissioning Cost Analysis pursuant to the requirements of 10 CFR 50.75(f)(3), "Reporting and Recordkeeping for Decommissioning Planning."

NPPD submitted a License Renewal Application for Cooper Nuclear Station (CNS) (Reference).

Although NPPD is seeking license renewal, the Preliminary Decommissioning Cost Estimate is submitted based on the current operating license expiration date of January 18, 2014. When the license for CNS is renewed, this 2008 Decommissioning Cost Estimate for the 2014 plant shutdown scenario would no longer be applicable.

Should you have any questions concerning this matter, please contact me at (402) 825-2904.

Sincerely, David W. Van Der Kamp Licensing Manager

/Jo Enclosure COOPER NUCLEAR STATION kg P.O. Box 98 / Brownville, NE 68327-0098 Telephone: (402) 825-3871 / Fax: (402) 825-5211 www.nppd corn

NLS2008098 Page 2 of 2 cc: Regional Administrator w/enclosure USNRC - Region IV Cooper Project Manager w/enclosure USNRC - NRR Project Directorate IV-1 Senior Resident Inspector w/enclosure USNRC - CNS NPG Distribution w/o enclosure CNS Records w/enclosure

ATTACHMENT 3 LIST OF REGULATORY COMMITMENTS@

ATTACHMENT 3 LIST OF REGULATORY COMMITMENTS© Correspondence Number: NLS2008098 The following table identifies those actions committed to by Nebraska Public Power District (NPPD) in this document. Any other actions discussed in the submittal represent intended or planned actions by NPPD. They are described for information only and are not regulatory commitments. Please notify the Licensing Manager at Cooper Nuclear Station of any questions regarding this document or any associated regulatory commitments.

COMMITMENT COMMITTED DATE COMMITMENT NUMBER OR OUTAGE None

+ 4

+ 4

+ 4 I PROCEDURE 0.42 REVISION 22 PAGE 18 OF 25 1

Document N01-1590-002, Rev. 1 DECOMMISSIONING COST ANALYSIS for the COOPER NUCLEAR STATION preparedfor the NEBRASKA PUBLIC POWER DISTRICT prepared by TLG Services, Inc.

Bridgewater, Connecticut December 2008

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Page ii of xvii APPROVALS Project Manager William A. Cloutier, JP-/ Date Project Engineer William J. Dietz Date Technical Manager 1A S Francis W. Sey uoe Dte" DAte' Quality Assurance Manager J eph JJer d&-

'ýH TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Pageiii of xvii TABLE OF CONTENTS SECTION - PAGE EXECUTIVE

SUMMARY

.................................................................................. vii-xvii

1. INTRODUCTION ..................................................................................................... 1-1 1.1 Objectives of Study ........................................................................................... 1-1 1.2 Site Description ................................................................................................. 1-1 1.3 Regulatory Guidance ................................................................................... 1-2 1.3.1 Nuclear W aste Policy Act ...................................................................... 1-4 1.3.2 Low-Level Radioactive W aste Act ........................................................ 1-6 1.3.3 Radiological Criteria for License Termination .................................... 1-7

2. DECOMMISSIONING ALTERNATIVES .............................................................. 2-1 2.1 D E C ON .............................................................................................................. 2-2 2.1.1 Period 1 - Preparations ......................................................................... 2-2 2.1.2 Period 2 - Decommissioning Operations .............................................. 2-4 2.1.3 Period 3 - Site Restoration .................................................................... 2-7 2.1.4 ISFSI Operations and Decommissioning ............................................ 2-8 2.2 SAFSTOR and Delayed Decommissioning ..................................................... 2-9 2.2.1 Period 1 - Preparations ....................................................................... 2-10 2.2.2 Period 2 - Dormancy ............................................................................ 2-11 2.2.3 Periods 3 and 4 - Deferred Decommissioning ................. 2-12 2.2.4 Period 5 - Site Restoration .................................................................. 2-13

3. COST ESTIMATES ................................................................................................... 3-1 3.1 Basis of Estimates ............................................................................................ 3-1 3.2 Methodology ...................................................................................................... 3-1 3.3 Financial Components of the Cost Model ....................................................... 3-3 3.3.1 Contingency ........................................................................................... 3-4 3.3.2 Financial Risk ........................................................................................ 3-5 3.4 Site-Specific Considerations ............................................................................. 3-6 3.4.1 Spent Fuel Management ....................................................................... 3-6 3.4.2 Reactor Vessel and Internal Components ........................................... 3-9 3.4.3 Primary System Components ............................................................. 3-10 3.4.4 Main Turbine and Condenser ............................................................. 3-11 3.4.5 Transportation Methods ..................................................................... 3-11 3.4.6 Low-Level Radioactive W aste Conditioning and Disposal ............... 3-12 3.4.7 Site Conditions Following Decommissioning .................................... 3-13 TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Page iv of xvii TABLE OF CONTENTS (continued)

SECTION - PAGE 3.5 A ssumptions .................................................................................................... 3-14 3.5.1 Estim ating Basis ............................................................................ 3-14 3.5.2 L abor C osts .......................................................................................... 3-14 3.5.3 D esign Conditions ................................................................................ 3-15 3.5.4 G eneral ................................................................................................. 3-16 3.6 Cost Estim ate Sum m ary ............................................................................... 3-18

4. S C H E D UL E ............................................................................................................... 4-1 4.1 Schedule Estim ate Assum ptions ..................................................................... 4-1 4.2 Project Schedule ................................................................................................ 4-2

5. RADIOA CTIVE WASTES ........................................................................................ 5-1

6. R E S ULT S ................................................................................................................. 6-1

7. R E F E R E NC E S .. *....................................................................................................... 7-1 TABLES Cost Summary, 2014 Cessation of Operations ............................................... xvi Cost Summary, 2034 Cessation of Operations .............................................. xvii 3.1 2014 DECON, Schedule of Total Annual Expenditures ............................... 3-19 3.2 2014 Delayed DECON, Schedule of Total Annual Expenditures ................ 3-21 3.3 2014 SAFSTOR, Schedule of Total Annual Expenditures ........................... 3-23 3.4 2034 DECON, Schedule of Total Annual Expenditures ............................... 3-25 3.5 2034 Delayed DECON, Schedule of Total Annual Expenditures ................ 3-26 3.6 2034 SAFSTOR, Schedule of Total Annual Expenditures ........................... 3-28 5.1 Decommissioning Waste Summary ................................................................. 5-3 5.2 2014 DECON, Decommissioning Waste Summary ........................................ 5-4 5.3 2014 Delayed DECON, Decommissioning Waste Summary .......................... 5-5 5.4 2014 SAFSTOR, Decommissioning Waste Summary ..................................... 5-6 5.5 2034 DECON, Decommissioning Waste Summary ........................................ 5-7 5.6 2034 Delayed DECON, Decommissioning Waste Summary .......................... 5-8 5.7 2034 SAFSTOR, Decommissioning Waste Summary ..................................... 5-9 TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Page v of xvii TABLE OF CONTENTS (continued)

SECTION - PAGE TABLES (continued) 6.1 Cost Summary, 2014 Cessation of Operations ............................................... 6-4 6.2 Cost Summary, 2034 Cessation of Operations ............................................... 6-5 FIGURES 4.1 2014 DECON Activity Schedule....................................................................... 4-3 4.2 2014 Delayed DECON Activity Schedule ........................................................ 4-6 4.3 2014 SAFSTOR Activity Schedule ................................................................... 4-9 4.4 2034 DECON Activity Schedule ..................................................................... 4-12 4.5 2034 Delayed DECON Activity Schedule ...................................................... 4-15 4.6 2034 SAFSTOR Activity Schedule ................................................................. 4-18 4.7 D E C O N Tim elines ......................................................................................... 4-21 4.8 Delayed DECON and SAFSTOR Timelines .................................................. 4-22 APPENDICES A. Unit Cost Factor Development ....................................................................... A-1 B. Unit Cost Factor Listing ................................................................................ B-1 C. Detailed Cost Analyses, 2014 Cessation of Operations ................................. C-1 T able C -1, D E C ON ................................................................................................ C -2 Table C-2, Delayed DECON ........................................................................... C-13 Table C-3, SAFSTOR ...................................... C-24 D. Detailed Cost Analyses, 2034 Cessation of Operations ................................. D-1 T able D -1, D E C O N ................................................................................................ D -2 Table D -2, Delayed D ECON ............................................................................... D -13 Table D -3, SAFSTO R .......................................................................................... D -24 E. Work Difficulty Adjustment Factors ................................................................ E-1 F. Area M aps .......................................................................................................... F -1 TLG Services, Inc.

Cooper NuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Page vi of xvii REVISION LOG No'R~. ~ 1 t R d R f - 'Revso 0 10-08-08 Original Issue Pages xvii-xviii Tables 3.1 through 3.6 1T73-0804 12-08-08 Tables 6.1 and 6.2 Corporate Overhead Costs Revised Tables C-1, C-2, C-3 Tables D-1, D-2, D-3 TLG Services, Inc.

CooperNuclearStation Document N01-1590-002,Rev. 1 DecommissioningCost Analysis Page vii ofxvii EXECUTIVE

SUMMARY

This report presents estimates of the cost to decommission the Cooper Nuclear Station (Cooper) for the selected decommissioning scenarios following a scheduled cessation of plant operations. The estimates are designed to provide Nebraska Public Power District (NPPD) with the information needed to assess its financial obligations as they pertain to the eventual decommissioning of the nuclear station. This report is also designed to meet the requirements of 10 CFR 50.75(f)(3) in that it includes an assessment of the major factors that could affect the cost to decommission.

The primary goal of the decommissioning is the removal and disposal of the contaminated systems and structures so that the plant's operating license can be terminated. The cost analysis recognizes that spent fuel will be stored at the site in the plant's storage pool and/or in an independent spent fuel storage installation (ISFSI) until such time that it can be transferred to the U.S. Department of Energy (DOE).

Consequently, the estimates also include those costs to manage and subsequently decommission these interim storage facilities.

The estimates are based on numerous fundamental assumptions, including regulatory requirements, project contingencies, low-level radioactive waste disposal practices, high-level radioactive waste management options, and site restoration requirements.

The estimates incorporate a minimum cooling period for the spent fuel that resides in the storage pool when operations cease. Any residual fuel remaining in the pool after the cooling period is transferred directly to the DOE or relocated to the ISFSI for interim storage. The estimates also include the dismantling of site structures and non-essential facilities and the limited restoration of the site.

Alternatives and Regulations The Nuclear Regulatory Commission (NRC) provided general decommissioning guidance in a rule adopted on June 27, 1988.[1] In this rule, the NRC set forth technical and financial criteria for decommissioning licensed nuclear facilities. The regulations addressed planning needs, timing, funding methods, and environmental review requirements for decommissioning. The rule also defmed three decommissioning alternatives as being acceptable to the NRC: DECON, SAFSTOR, and ENTOMB.

DECON is defined as "the alternative in which the equipment, structures, and portions of a facility and site containing radioactive contaminants are removed or decontaminated to a level that permits the 1 U.S. Code of Federal Regulations, Title 10, Parts 30, 40, 50, 51, 70 and 72 "General Requirements for Decommissioning Nuclear Facilities," Nuclear Regulatory Commission, Federal Register Volume 53, Number 123 (p 24018 et seq.), June 27, 1988 TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Page viii of xvii property to be released for unrestricted use shortly after cessation of 2

operations."[ ]

SAFSTOR is defined as "the alternative in which the nuclear facility is placed and maintained in a condition that allows the nuclear facility to be safely stored and subsequently decontaminated (deferred decontamination) to levels that permit release for unrestricted use."[3]

Decommissioning is required to be completed within 60 years, although longer time periods will be considered when necessary to protect public health and safety. The safe-storage periods in the Delayed DECON analyses are selected to coincide with the removal of spent fuel from the site.

ENTOMB is defined as "the alternative in which radioactive contaminants are encased in a structurally long-lived material, such as concrete; the entombed structure is appropriately maintained and continued surveillance is carried out until the radioactive material decays to a level permitting unrestricted release of the property."[4] As with the SAFSTOR alternative, decommissioning is currently required to be completed within 60 years, although longer time periods will also be considered when necessary to protect public health and safety.

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

In 1996, the NRC published revisions to its general requirements for decommissioning nuclear power plants to clarify ambiguities and codify procedures and terminology as a means of enhancing efficiency and uniformity in the decommissioning process.[5 ] The amendments allow for greater public participation and better defme the transition process from operations to decommissioning. Regulatory Guide 1.184, issued in July 2000, further described the methods and procedures that are acceptable to the NRC 2 Ibid. Page FR24022, Column 3 3 Ibid.

4 Ibid. Page FR24023, Column 2 5 U.S. Code of Federal Regulations, Title 10, Parts 2, 50, and 51, "Decommissioning of Nuclear Power Reactors," Nuclear Regulatory Commission, Federal Register Volume 61, (p 39278 et seq.), July 29, 1996 TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Page ix of xvii staff for implementing the requirements of the 1996 revised rule that relate to the initial activities and the major phases of the decommissioning process. The costs and schedules presented in this analysis follow the general guidance and sequence in the amended regulations.

Decommissioning Scenarios The following alternatives were evaluated and are representative of the alternatives available to the owner:

1. DECON: The plant is decommissioned shortly after the permanent cessation of plant operations. Spent fuel, that is not transferred directly to the DOE, is relocated to the ISFSI for interim storage. Spent fuel storage operations continue at the site until the transfer of the fuel to the DOE is completed.

2. Delayed DECON: In the second scenario, the unit is prepared for an abbreviated period of storage. As in the first scenario, spent fuel storage operations continue at the site until the transfer of the fuel to the DOE is completed. Once completed, decommissioning operations are initiated.

3. SAFSTOR: The third scenario is similar to the second scenario in that the unit is placed in safe-storage with concurrent spent fuel storage operations. However, in this scenario, decommissioning is deferred beyond the fuel storage period to the maximum extent possible; termination of the license would conclude within the maximum required 60-year period.

Six scenarios were identified for evaluation. As shown below, the six scenarios evaluate a combination of shutdown dates (scheduled and anticipated) and decommissioning alternative (prompt or deferred).

Shutdown Spent Fuel Operating Scenario Date Option Transfer License Completed Terminated 1 2014 DECON 2046 2020 2 2014 Delayed DECON 2046 2053 3 2014 SAFSTOR 2046 2074 4 2034 DECON 2061 2040 5 2034 Delayed DECON 2061 2068 6 2034 SAFSTOR 2061 2094

_ _ _ I __ _ I _ _ _ _ _ I _ _ _ _ I _ _

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002,Rev. 1 Decommissioning Cost Analysis Pagex of xvii Methodology The methodology used to develop the estimates described within this document follows the basic approach originally presented in the cost estimating guidelines[6] developed by the Atomic Industrial Forum (now Nuclear Energy Institute). This reference describes a unit cost factor method for estimating decommissioning activity costs. The unit cost factors used in this analysis incorporate site-specific costs and the latest available information about worker productivity in decommissioning.

The estimates are area-based estimates, i.e., the plant inventory has been correlated with site-specific area working conditions, and the plant work activities organized into discrete areas to better reflect the manner in which the decommissioning will be conducted. The areas were determined on the basis of "common" conditions or attributes. Each area was evaluated for work difficulty, including affects of radiation, external surface contamination, and access. This evaluation was used to adjust the work difficulty factors for removing equipment in a given area. A data base was constructed and identified the installed equipment in each area. This data base contains a list of components that have a unique identifier, such as valves, tanks, electrical equipment, and heat exchangers. It also contains bulk commodities such as piping, ventilation ductwork, cable tray, electrical conduit, and supports.

The inventory was organized according to its proposed disposition. There were three primary waste streams identified for the Cooper inventory: (1) clean material (expected to meet the release criteria without any decontamination), (2) contaminated material with recovery potential or requiring additional processing for disposal (expected to be sent to an off-site waste processor), and (3) contaminated material designated for direct disposal at a controlled low-level radioactive waste disposal site (i.e., material expected to exceed waste processor acceptance criteria or uneconomical to process).

An activity duration critical path was used to determine the total decommissioning program schedule. This was required for estimating the project costs, including program management, administration, field engineering, equipment rental, quality assurance, and security.

This analysis reflects lessons learned from TLG's involvement in the Shippingport Station decommissioning, completed in 1989, as well as the decommissioning of the Cintichem reactor, hot cells, and associated facilities, completed in 1997. In addition, the planning and engineering for the Pathfinder, Shoreham, Rancho Seco, Trojan, Yankee Rowe, Big Rock Point, Maine Yankee, Humboldt Bay-3, Connecticut Yankee, 6 T.S. LaGuardia et al., "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates," AIF/NESP-036, May 1986 TLG Services, Inc.

CooperNuclearStation Document N01-1590-002,Rev. 1 Decommissioning Cost Analysis Pagexi of xvii and San Onofre-1 nuclear units have provided additional insight into the process, the regulatory aspects, and the technical challenges of decommissioning commercial nuclear units.

Contingency Consistent with standard cost estimating practice, contingencies are applied to the decontamination and dismantling costs developed as "specific provision for unforeseeable elements of cost within the defined project scope, particularly important where previous experience relating estimates and actual costs has shown that unforeseeable events which will increase costs are likely to occur."[7 ] The cost elements in the estimates are based on ideal conditions; therefore, the types of unforeseeable events that are almost certain to occur in decommissioning, based on industry experience, are addressed through a percentage contingency applied on a line-item basis. This contingency factor is a nearly universal element in all large-scale construction and demolition projects. It should be noted that contingency, as used in this analysis, does not account for price escalation and inflation in the cost of decommissioning over the remaining operating life of the station.

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

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

Until recently, there were two facilities available to NPPD for the disposal of low-level radioactive waste generated by Cooper. As of July 1, 2008, however, the facility in Barnwell, South Carolina was closed to generators outside the Atlantic Compact (comprised of the states of Connecticut, New Jersey and South Carolina). This leaves the facility in Clive, Utah, operated by EnergySolutions, as the only available destination for low-level radioactive waste requiring controlled disposal.

7 Project and Cost Engineers' Handbook, Second Edition, American Association of Cost Engineers, Marcel Dekker, Inc., New York, New York, p. 239 8 "Low-Level Radioactive Waste Policy Amendments Act of 1985," Public Law 99-240, 1/15/86 TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 Decommissioning CostAnalysis Pagexii of xvii For the purpose of this analysis, the EnergySolutions' facility is used as the basis for estimating the disposal cost for the majority of the radioactive waste (Class A [91).

EnergySolutions does not have a license to dispose of the more highly radioactive waste (Classes B and C), for example, generated in the dismantling of the reactor vessel. As a proxy, the disposal cost for this material is based upon the last published rate schedule for non-compact waste for the Barnwell facility.

The dismantling of the components residing closest to the reactor core generates radioactive waste considered unsuitable for shallow-land disposal (i.e., low-level radioactive waste with concentrations of radionuclides that exceed the limits established by the NRC for Class C radioactive waste (GTCC)). The Low-Level Radioactive Waste Policy Amendments Act of 1985 assigned the federal government the responsibility for the disposal of this material. The Act also stated that the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste. However, to date, the federal government has not identified a cost for disposing of GTCC or a schedule for acceptance. As such, the GTCC radioactive waste has been packaged and disposed of as high-level waste, at a cost equivalent to that envisioned for the spent fuel.

A significant portion of the waste material generated during decommissioning may only be potentially contaminated by radioactive materials. This waste can be analyzed on site or shipped off site to licensed facilities for further analysis, for processing and/or for conditioning/recovery. Reduction in the volume of low-level radioactive waste requiring disposal in a licensed low-level radioactive waste disposal facility can be accomplished through a variety of methods, including analyses and surveys or decontamination to eliminate the portion of waste that does not require disposal as radioactive waste, compaction, incineration or metal melt. The estimates for Cooper reflect the savings from waste recovery/volume reduction.

High-Level Radioactive Waste Management Congress passed the "Nuclear Waste Policy Act"[' 01 (NWPA) in 1982, assigning the federal government's long-standing responsibility for disposal of the spent nuclear fuel created by the commercial nuclear generating plants to the DOE. The NWPA provided that DOE would enter into contracts with utilities in which DOE would promise to take the utilities' spent fuel and high-level radioactive waste and utilities would pay the cost of the disposition services for that material. NWPA, along with the individual contracts with the utilities, specified that the DOE was to begin accepting spent fuel by January 31, 1998.

9 U.S. Code of Federal Regulations, Title 10, Part 61, "Licensing Requirements for Land Disposal of Radioactive Waste" 10 "Nuclear Waste Policy Act of 1982 and Amendments," DOE's Office of Civilian Radioactive Management, 1982 TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Pagexiii of xvii Since the original legislation, the DOE has announced several delays in the program schedule. By January 1998, the DOE had failed to accept any spent fuel or high level waste, as required by the NWPA and utility contracts. Delays continue and, as a result, generators have initiated legal action against the DOE in an attempt to obtain compensation for DOE's breach of contract.

Operation of DOE's yet-to-be constructed repository is contingent upon the review and approval of the facility's license application by the NRC and the successful resolution of pending litigation. The DOE submitted its license application to the NRC on June 3, 2008, seeking authorization to construct the repository at Yucca Mountain, Nevada.

Assuming a timely review, and adequate funding, the DOE expects that receipt of fuel could begin by 2020.[111 It is generally necessary that spent fuel be actively cooled and stored for a minimum period at the generating site prior to transfer. As such, the NRC requires that licensees establish a program to manage and provide funding for the management of all irradiated fuel at the reactor site until title of the fuel is transferred to the Secretary of Energy, pursuant to 10 CFR Part 50.54(bb).[121 This funding requirement is fulfilled through inclusion of certain cost elements in the decommissioning estimates, for example, associated with the isolation and continued operation of the spent fuel pool and ISFSI.

At shutdown, the spent fuel pool is expected to contain freshly discharged assemblies (from the most recent refueling cycles) as well as the final reactor core. Over the following 51/2 years the assemblies are packaged into multipurpose canisters for transfer to the DOE or to the ISFSI. It is assumed that this period provides the necessary cooling for the final core to meet the storage system requirements and/or transport system requirements for decay heat.

DOE's contracts with utilities generally order the acceptance of spent fuel from utilities based upon the oldest fuel receiving the highest priority. For purposes of this analysis, acceptance of commercial spent fuel by the DOE is expected to begin in 2020.

NPPD has 1,054 spent fuel assemblies from Cooper in storage at General Electric's wet-pool ISFSI in Morris, Illinois. This analysis assumes that this inventory is preferentially transferred to the DOE, starting in 2022. The first assemblies removed from the Cooper site are assumed to be in 2027. With an estimated rate of transfer of 3,000 metric tons of uranium (MTU)/year, completion of the removal of fuel from the site is projected to be in the year 2046 for a 2014 shutdown and year 2061 for a 2034 11 "Testimony of Edward Sproat, Director, Office of Civilian Radioactive Waste Management, before a U.S. House of Representatives subcommittee on the status of Yucca Mountain, July 15, 2008 12 U.S. Code of Federal Regulations, Title 10, Part 50, "Domestic Licensing of Production and Utilization Facilities," Subpart 54 (bb), "Conditions of Licenses" TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 0 DecommissioningCost Analysis Pagexiv of xvii shutdown. Consequently, costs are included within the estimates for the long-term caretaking of the spent fuel at the Cooper site until the transfer is completed.

An ISFSI, which can be operated under a separate and independent license, has been constructed to support continued plant operations and future decommissioning. As such, the facility will be designed to accommodate the dry storage modules needed to off-load the wet storage pool so that dismantling activities can proceed. Once emptied, the Reactor Building can be either decontaminated and dismantled or prepared for long-term storage.

NPPD's position is that the DOE has a contractual obligation to accept Cooper's fuel earlier than the projections set out above consistent with its contract commitments. No assumption made in this study should be interpreted to be inconsistent with this claim. However, at this time, including the cost of storing spent fuel in this study is the most reasonable approach because it insures the availability of sufficient decommissioning funds at the end of the station's life if, contrary to its contractual obligation, the DOE has not performed earlier.

. Site Restoration Prompt dismantling of site structures (once the facilities are decontaminated) is clearly the most appropriate and cost-effective option. It is unreasonable to anticipate that these structures would be repaired and preserved after the radiological contamination is removed. The cost to dismantle site structures with a work force already mobilized on site is more efficient than if the process is deferred. Site facilities quickly degrade without maintenance, adding additional expense and creating potential hazards to the public and the demolition work force. Consequently, this study assumes that site structures are removed to a nominal depth of three feet below the local grade level wherever possible. The site is then to be graded and stabilized.

Summary The costs to decommission Cooper assumes the removal of all contaminated and activated plant components and structural materials such that the owner may then have unrestricted use of the site with no further requirements for an operating license.

Low-level radioactive waste, other than GTCC waste, is sent to a commercial processor for treatment/conditioning or to a controlled disposal facility.

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

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Pagexv of xvii The decommissioning scenarios are described in Section 2. The assumptions are presented in Section 3, along with schedules of annual expenditures. The major cost contributors are identified in Section 6, with detailed activity costs, waste volumes, and associated manpower requirements delineated in Appendices C and D. The major cost components are also identified in the cost summary provided at the end of this section.

The cost elements in the estimates are assigned to one of three subcategories: NRC License Termination, Spent Fuel Management, and Site Restoration. The subcategory "NRC License Termination" is used to accumulate costs that are consistent with "decommissioning" as defmed by the NRC in its financial assurance regulations (i.e.,

10 CFR Part 50.75). The cost reported for this subcategory is generally sufficient to terminate the unit's operating license, recognizing that there may be some additional cost impact from spent fuel management.

The "Spent Fuel Management" subcategory contains costs associated with the containerization and transfer of spent fuel to the ISFSI and the management of the ISFSI until such time that the transfer of all fuel from this facility to an off-site location (e.g., geologic repository) is completed.

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

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

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

As noted within this document, the estimates were developed and costs are presented in 2008 dollars. As such, the estimates do not reflect the escalation of costs (due to inflationary and market forces) over the remaining operating life of the reactor or during the decommissioning period.

TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Pagexvi of xvii COST

SUMMARY

2014 Cessation of Operations (thousands of 2008 dollars)

Delayed Cost Element DECON DECON SAFSTOR Decontamination 12,832 18,547 18,399 Removal 73,606 74,005 75,346 Packaging 13,340 9,827 9,577 Transportation 8,571 6,672 6,346 Waste Disposal 75,482 43,839 44,260 Off-site Waste Processing 35,573 42,626 42,743 Program Management [R1 360,232 426,204 490,053 Corporate A&G 15,657 10,100 10,100 Spent Fuel Management [21 77,077 69,839 69,839 Insurance and Regulatory Fees 53,616 62,853 76,914

.Energy 6,141 10,408 12,641 Characterization and Licensing Surveys 16,568 16,568 16,568 Miscellaneous Equipment 23,364 31,112 34,923 Total [31 772,0581 822,600 907,708 Cost Element License Termination 506,078 475,790 674,963 Spent Fuel Management 231,584 309,463 195,398 Site Restoration 34,396 37,347 37,347 Total [3] 772,058 822,600 907,708 I'] Includes engineering and security costs

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

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

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Pagexvii of xvii COST

SUMMARY

2034 Cessation of Operations (thousands of 2008 dollars)

Delayed Cost Element DECON DECON SAFSTOR Decontamination 12,832 18,581 18,438 Removal 74,270 74,184 76,329 Packaging 13,342 9,820 9,871 Transportation 8,571 6,704 6,578 Waste Disposal 75,618 46,649 44,999 Off-site Waste Processing 35,573 42,626 42,743 Program Management [1W 340,929 400,786 479,929 Corporate A&G 15,657 10,100 10,100 Spent Fuel Management [2] 53,484 47,535 47,535 Insurance and Regulatory Fees 46,578 54,706 72,081 Energy 6,141 9,875 12,641 Characterization and Licensing Surveys 16,568 16,568 16,568 Miscellaneous Equipment 23,408 30,280 34,989 Total [3] 722,972 768,414 872,803 Cost Element License Termination 506,207 476,185 676,510 Spent Fuel Management 182,368 254,881 158,945 Site Restoration 34,396 37,348 37,348 Total [3] 722,972 768,414 872,803

[R] Includes engineering and security costs

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

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

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 1, Page I of 8

1. INTRODUCTION This report presents estimates of the costs to decommission the Cooper Nuclear Plant (Cooper) following a scheduled cessation of plant operations. The estimates are designed to provide Nebraska Public Power District (NPPD), the plant's owner, with the information needed to assess its financial obligations, as they pertain to the eventual decommissioning of the nuclear station. It is not a detailed engineering document, but a financial analysis prepared in advance of the detailed engineering that will be required to carry out the decommissioning.

1.1 OBJECTIVES OF STUDY The objectives of this study were to prepare comprehensive estimates of the costs to decommission Cooper, to provide a sequence or schedule for the associated activities, and to develop waste stream projections from the decontamination and dismantling activities.

The construction permit for Cooper was issued in June of 1968, with commercial operation in July of 1974. For the purposes of this study, two shutdown dates were evaluated: the current license expiration date of January 18, 2014 and a projected date assuming license renewal of January 18, 2034.

These dates were used in scheduling the decommissioning activities.

1.2 SITE DESCRIPTION Cooper is a single unit facility located on the west bank of the Missouri River between the villages of Brownville and Nemaha, Nebraska. The nuclear station is owned and operated by NPPD, a public corporation and political subdivision of the state of Nebraska engaging in generation, transmission, distribution, and sale of electric energy.

The station is comprised of a single cycle, forced circulation, boiling water reactor designed by the General Electric Company, producing steam for direct use in the steam turbine: The original supporting facilities were engineered and constructed by Burns and Roe, Inc. The Multi-Purpose Facility, Office Building Addition, Warehouses, Flammable Liquid Storage Building and other on-site structures were designed and built by others.

The reactor vessel and the recirculation piping system are contained within the drywell of a pressure suppression system housed within the Reactor Building.

The pressure suppression system consists of a drywell, a pressure suppression chamber which stores a large volume of water and a connecting submerged TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 1, Page2 of 8 vent system between the drywell and water pool, isolation valves, containment cooling systems and other service equipment. The Reactor Building encloses the primary containment system thereby providing a secondary containment.

Heat produced in the reactor is converted to electrical energy by the power conversion system. A turbine-generator system converts the thermal energy of the steam produced in the reactor into mechanical shaft power and then into electrical energy. The turbine consists of one high-pressure, double-flow turbine element, and two low-pressure, double-flow turbine elements all aligned in tandem. The generator is a direct-driven, 1,800 rpm hydrogen-cooled synchronous generator. The turbine is operated in a closed feedwater cycle, which condenses the steam; the heated feedwater is returned to the reactor.

The heat rejected to the main condenser is removed by the circulating water system. Based upon the recent power uprate, Cooper's generating capacity will be approximately 836 Megawatts electric (MWe).

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

Circulating water is drawn from the Missouri River with heated cooling water returned to the river.

1.3 REGULATORY GUIDANCE The Nuclear Regulatory Commission (NRC or Commission) provided initial decommissioning requirements in its rule "General Requirements for Decommissioning Nuclear Facilities," issued in June 1988. 1

• This rule set forth financial criteria for decommissioning licensed nuclear power facilities.

The regulation addressed decommissioning planning needs, timing, funding methods, and environmental review requirements. The intent of the rule was to ensure that decommissioning would be accomplished in a safe and timely manner and that adequate funds would be available for this purpose.

Subsequent to the rule, the NRC issued Regulatory Guide 1.159, "Assuring the Availability of Funds for Decommissioning Nuclear Reactors,"[21 which provided additional guidance to the licensees of nuclear facilities on the financial methods acceptable to the NRC staff for complying with the requirements of the rule. The regulatory guide addressed the funding requirements and provided guidance on the content and form of the financial assurance mechanisms indicated in the rule.

• References provided in Section 7 of the document TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 1, Page 3 of 8 The rule defined three decommissioning alternatives as being acceptable to the NRC: DECON, SAFSTOR, and ENTOMB. The DECON alternative assumes that any contaminated or activated portion of the plant's systems, structures and facilities are removed or decontaminated to levels that permit the site to be released for unrestricted use shortly after the cessation of plant operations.

The rule also placed limits on the time allowed to complete the decommissioning process. For SAFSTOR, the process is restricted in overall duration to 60 years, unless it can be shown that a longer duration is necessary to protect public health and safety. The guidelines for ENTOMB are similar, providing the NRC with both sufficient leverage and flexibility to ensure that these deferred options are only used in situations where it is reasonable and consistent with the definition of decommissioning. At the conclusion of a 60-year dormancy period (or longer for ENTOMB if the NRC approves such a case), the site would still require significant remediation to meet the unrestricted release limits for license termination.

The ENTOMB alternative has not been viewed as a viable option for power reactors due to the significant time required to isolate the long-lived radionuclides for decay to permissible levels. However, with rulemaking permitting the controlled release of a site,[3] the NRC has re-evaluated this alternative. The resulting feasibility study, based upon an assessment by Pacific Northwest National Laboratory, concluded that the method did have conditional merit for some, if not most reactors. However, the staff also found that additional rulemaking would be needed before this option could be treated as a generic alternative. The NRC had considered rulemaking to alter the 60-year time for completing decommissioning and to clarify the use of engineered barriers for reactor entombments.[4] However, the NRC's staff has recommended that rulemaking be deferred, based upon several factors, e.g., no licensee has committed to pursuing the entombment option, the unresolved issues associated with the disposition of greater-than-Class C material (GTCC), and the NRC's current priorities, at least until after the additional research studies are complete. The Commission concurred with the staffs recommendation.

In 1996, the NRC published revisions to the general requirements for decommissioning nuclear power plants.[51 When the decommissioning regulations were adopted in 1988, it was assumed that the majority of licensees would decommission at the end of the facility's operating licensed life.

Since that time, several licensees permanently and prematurely ceased operations. Exemptions from certain operating requirements were required once the reactor was defueled to facilitate the decommissioning. Each case was handled individually, without clearly defined generic requirements. The NRC amended the decommissioning regulations in 1996 to clarify ambiguities and TLG Services, Inc.

CooperNuclear Station Document N01-1590-002,Rev. 1 DecommissioningCost Analysis Section 1, Page 4 of 8 codify procedures and terminology as a means of enhancing efficiency and uniformity in the decommissioning process. The amendments allow for greater public participation and better define the transition process from operations to decommissioning.

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

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

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

Since the original legislation, the DOE has announced several delays in the program schedule. By January 1998, the DOE had failed to accept any spent fuel or high level waste, as required by the NWPA and utility contracts. Delays continue and, as a result, generators have initiated legal action against the DOE in an attempt to obtain compensation for DOE's breach of contract.

Operation of DOE's yet-to-be constructed repository is contingent upon the review and approval of the facility's license application by the NRC and the successful resolution of pending litigation. The DOE submitted its license application to the NRC on June 3, 2008, seeking authorization to construct the repository at Yucca Mountain, Nevada. Assuming a TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 1, Page5 of 8 timely review, and adequate funding, the DOE expects that receipt of fuel could begin by 2020.[71 It is generally necessary that spent fuel be actively cooled and stored for a minimum period at the generating site prior to transfer. As such, the NRC requires that licensees establish a program to manage and provide funding for the management of all irradiated fuel at the reactor site until title of the fuel is transferred to the Secretary of Energy, pursuant to 10 CFR Part 50.54(bb).[8 1 This funding requirement is fulfilled through inclusion of certain cost elements in the decommissioning estimate, for example, associated with the isolation and continued operation of the spent fuel pool and ISFSI.

At shutdown, the spent fuel pool is expected to contain freshly discharged assemblies (from the most recent refueling cycles) as well as the final reactor core. Over the following 5Y years the assemblies are packaged into multipurpose canisters for transfer to the DOE or to the ISFSI. It is assumed that this period provides the necessary cooling for the final core to meet the storage system requirements and/or transport system requirements for decay heat.

DOE's contracts with utilities generally order the acceptance of spent fuel from utilities based upon the oldest fuel receiving the highest priority. For purposes of this analysis, acceptance of commercial spent fuel by the DOE is expected to begin in 2020.

NPPD has 1,054 spent fuel assemblies from Cooper in storage at General Electric's wet-pool ISFSI in Morris, Illinois. This analysis assumes that this inventory is preferentially transferred to the DOE, starting in 2022. The first assemblies removed from the Cooper site are assumed to be in 2027. With an estimated rate of transfer of 3,000 metric tons of uranium (MTU)/year from the commercial generators, completion of the removal of fuel from the Cooper site is projected to be in the year 2046 for a 2014 shutdown and year 2061 for a 2034 shutdown. Consequently, costs are included within the estimates for the long-term caretaking of the spent fuel at the Cooper site until the transfer is completed.

An ISFSI, which can be operated under a separate and independent license, is constructed to support plant operations and decommissioning.

As such, the facility will be designed to accommodate the dry storage modules needed to off-load the wet storage pool so that dismantling TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 1, Page 6 of 8 activities can proceed. Once emptied, the Reactor Building can be either decontaminated and dismantled or prepared for long-term storage.

NPPD's position is that the DOE has a contractual obligation to accept Cooper's fuel earlier than the projections set out above consistent with its contract commitments. No assumption made in this study should be interpreted to be inconsistent with this claim. However, at this time, including the cost of storing spent fuel in this study is the most reasonable approach because it insures the availability of sufficient decommissioning funds at the end of the station's life if, contrary to its contractual obligation, the DOE has not performed earlier.

1.3.2 Low-Level Radioactive Waste Acts The contaminated and activated material generated in the decontamination and dismantling of a commercial nuclear reactor is classified as low-level (radioactive) waste, although not all of the material is suitable for "shallow-land" disposal. With the passage of the "Low-Level Radioactive Waste Policy Act" in 1980,[91 and its Amendments of 1985,110] the states became ultimately responsible for the disposition of low-level radioactive waste generated within their own borders.

Until recently, there were two facilities available to NPPD for the disposal of low-level radioactive waste generated by Cooper. As of July 1, 2008, however, the facility in Barnwell, South Carolina was closed to generators outside the Atlantic Compact (comprised of the states of Connecticut, New Jersey and South Carolina). This leaves the facility in Clive, Utah, operated by EnergySolutions, as the only available destination for low-level radioactive waste requiring controlled disposal.

For the purpose of this analysis, the EnergySolutions' facility is used as the basis for estimating the disposal cost for the majority of the radioactive waste (Class A[ 1"]). EnergySolutions does not have a license to dispose of the more highly radioactive waste (Class B and C), for example, generated in the dismantling of the reactor vessel. As a proxy, the disposal costs for this material are based upon the last published rate schedule for non-compact waste for the Barnwell facility.

The dismantling of the components residing closest to the reactor core generates radioactive waste considered unsuitable for shallow land disposal (i.e., low-level radioactive waste with concentrations of radionuclides that exceed the limits established by the NRC for Class C TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 1, Page 7 of 8 radioactive waste (GTCC)). The Low-Level Radioactive Waste Policy Amendments Act of 1985 assigned the federal government the responsibility for the disposal of this material. The Act also stated that the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste.

However, to date, the federal government has not identified a cost for disposing of GTCC or a schedule for acceptance. As such, the GTCC radioactive waste has been packaged and disposed of as high-level waste, at a cost equivalent to that envisioned for the spent fuel.

A significant portion of the waste material generated during decommissioning may only be potentially contaminated by radioactive materials. This waste can be analyzed on site or shipped off site to licensed facilities for further analysis, for processing and/or for conditioning/recovery. Reduction in the volume of low-level radioactive waste requiring disposal in a licensed low-level radioactive waste disposal facility can be accomplished through a variety of methods, including analyses and surveys or decontamination to eliminate the portion of waste that does not require disposal as radioactive waste, compaction, incineration or metal melt. The estimates for Cooper reflect the savings from waste recovery/volume reduction.

1.3.3 Radiological Criteria for License Termination In 1997, the NRC published Subpart E, "Radiological Criteria for License Termination,"[121 amending 10 CFR Part 20. This subpart provides radiological criteria for releasing a facility for unrestricted use.

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

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

It should be noted that the NRC and the Environmental Protection Agency (EPA) differ on the amount of residual radioactivity considered acceptable in site remediation. The EPA has two limits that apply to radioactive materials. An EPA limit of 15 millirem per year is derived from criteria established by the Comprehensive Environmental 13 Response, Compensation, and Liability Act (CERCLA or Superfund).[ 1 An additional and separate limit of 4 millirem per year, as defined in 40 CFR §141.16, is applied to drinking water.[141 TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 1, Page8 of 8 On October 9, 2002, the NRC signed an agreement with the EPA on the radiological decommissioning and decontamination of NRC-licensed sites. The Memorandum of Understanding (MOU)[' 5] provides that EPA will defer exercise of authority under CERCLA for the majority of facilities decommissioned under NRC authority. The MOU also includes provisions for NRC and EPA consultation for certain sites when, at the time of license termination, (1) groundwater contamination exceeds EPA-permitted levels; (2) NRC contemplates restricted release of the site; and/or (3) residual radioactive soil concentrations exceed levels defined in the MOU.

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

TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 2, Page1 of 13

2. DECOMMISSIONING ALTERNATIVES Detailed cost estimates were developed to decommission the Cooper nuclear unit for the scenarios described below. Although they differ with respect to technique, process, cost, and schedule, they attain the same result: the ultimate release of the site for unrestricted use.

The following alternatives were evaluated (for both a 2014 and 2034 cessation of plant operations) and are representative of the alternatives available to the owner:

1. DECON: The plant is decommissioned shortly after the permanent cessation of plant operations. Spent fuel, that is not transferred directly to the DOE, is relocated to the ISFSI for interim storage. Spent fuel storage operations continue at the site until the transfer of the fuel to the DOE is completed.

2. Delayed DECON: In the second scenario, the unit is prepared for an abbreviated period of storage. As in the first scenario, spent fuel storage operations continue at the site until the transfer of the fuel to the DOE is completed. Once completed, decommissioning operations are initiated.

3. SAFSTOR: The third scenario is similar to the second scenario in that the unit is placed in safe-storage with concurrent spent fuel storage operations. However, decommissioning is deferred beyond the fuel storage period to the maximum extent possible; termination of the license would conclude within the maximum required 60-year period.

Six scenarios were identified for evaluation. As shown below, the six scenarios evaluate a combination of shutdown dates (scheduled and anticipated) and decommissioning alternative (prompt or deferred).

Shutdown Spent Fuel Operating Scenario Date Option Transfer License Completed Terminated 1 2014 DECON 2046 2020 2 2014 Delayed DECON 2046 2053 3 2014 SAFSTOR 2046 2074 4 2034 DECON 2061 2040 5 2034 Delayed DECON 2061 2068 6 2034 SAFSTOR 2061 2094 TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 2, Page2 of 13 The following sections describe the basic activities associated with each alternative.

Although detailed procedures for each activity identified are not provided, and the actual sequence of work may vary, the activity descriptions provide a basis not only for estimating but also for the expected scope of work, i.e., engineering and planning at the time of decommissioning.

The conceptual approach that the NRC has described in its regulations divides decommissioning into three phases. The initial phase commences with the effective date of permanent cessation of operations and involves the transition of both plant and licensee from reactor operations (i.e., power production) to facility de-activation and closure. During the first phase, notification is to be provided to the NRC certifying the permanent cessation of operations and the removal of fuel from the reactor vessel. The licensee is then prohibited from reactor operation.

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

2.1 DECON The DECON alternative, as defined by the NRC, is "the alternative in which the equipment, structures, and portions of a facility and site containing radioactive contaminants are removed or decontaminated to a level that permits the property to be released for unrestricted use shortly after cessation of operations." This study does not address the cost to dispose of the spent fuel residing at the site; such costs are funded through a surcharge on electrical generation. However, the study does estimate the costs incurred with the interim on-site storage of the fuel pending shipment by the DOE to an off-site disposal facility.

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

CooperNuclearStation Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 2, Page3 of 13 characterization of the facility and major components, and the development of the PSDAR.

Engineering and Planning The PSDAR, required within two years of the notice to cease operations, provides a description of the licensee's planned decommissioning activities, a timetable, and the associated financial requirements of the intended decommissioning program. Upon receipt of the PSDAR, the NRC will make the document available to the public for comment in a local hearing to be held in the vicinity of the reactor site. Ninety days following submittal and NRC receipt of the PSDAR, the licensee may begin to perform major decommissioning activities under a modified 10 CFR §50.59 procedure, i.e., without specific NRC approval. Major activities are defined as any activity that results in permanent removal of major radioactive components, permanently modifies the structure of the containment, or results in dismantling components (for shipment) containing GTCC, as defined by 10 CFR §61. Major components are further defined as comprising the reactor vessel and internals, large bore reactor recirculation system piping, and other large components that are radioactive. The NRC includes the following additional criteria for use of the §50.59 process in decommissioning. The proposed activity must not:

" foreclose release of the site for possible unrestricted use,

• significantly increase decommissioning costs,

• cause any significant environmental impact, or

• violate the terms of the licensee's existing license.

Existing operational technical specifications are reviewed and modified to reflect plant conditions and the safety concerns associated with permanent cessation of operations. The environmental impact associated with the planned decommissioning activities is also considered.

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

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

The decommissioning program outlined in the PSDAR will be designed to accomplish the required tasks within the ALARA guidelines (as defined in 10 CFR §20) for protection of personnel from exposure to TLG Services, Inc.

CooperNuclear Station Document N01-1590-002,Rev. 1 0 DecommissioningCost Analysis Section 2, Page4 of 13 radiation hazards. It will also address the continued protection of the health and safety of the public and the environment during the dismantling activity. Consequently, with the development of the PSDAR, activity specifications, cost-benefit and safety analyses, work packages and procedures, would be assembled to support the proposed decontamination and dismantling activities.

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

• Characterization of the site and surrounding environs. This includes radiation surveys of work areas, major components (including the reactor vessel and its internals), internal piping, and sacrificial shield cores.

• Isolation of the spent fuel storage pool and fuel handling systems, such that decommissioning operations can commence on the balance of the plant. The pool will remain operational for approximately 51/2 years following the cessation of operations before the inventory resident at shutdown can be transferred to the ISFSI.

• Specification of transport and disposal requirements for activated materials and/or hazardous materials, including shielding and waste stabilization.

" Development of procedures for occupational exposure control, control and release of liquid and gaseous effluent, processing of radwaste (including dry-active waste, resins, filter media, metallic and non-metallic components generated in decommissioning), site security and emergency programs, and industrial safety.

2.1.2 Period 2 - Decommissioning Operations This period includes the physical decommissioning activities associated with the removal and disposal of contaminated and activated components and structures, including the successful termination of the 10 CFR §50 operating license. Significant decommissioning activities in this phase include:

Construction of temporary facilities and/or modification of existing facilities to support dismantling activities. This may include a centralized processing area to facilitate equipment removal and component preparations for off-site disposal.

TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 2, Page 5 of 13 Reconfiguration and modification of site structures and facilities as needed to support decommissioning operations. This may include the upgrading of roads (on- and off-site) to facilitate hauling and transport. Modifications may be required to the containment structure to facilitate access of large/heavy equipment. Modifications may also be required to the refueling area of the Reactor Building to support the segmentation of the reactor vessel internals and component extraction.

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

o Procurement (lease or purchase) of shipping canisters, cask liners, and industrial packages for the disposition of low-level radioactive waste.

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

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

• Disconnection of the control blades from the drives on the vessel lower head. Blades are transferred to the spent fuel pool for packaging.

o Transfer of the steam separator and dryer assemblies to the dryer-separator pool for segmentation. Segmentation will maximize the loading of the shielded transport casks, i.e., by weight and activity.

The operations are conducted under water using remotely operated tooling and contamination controls.

• Disassembly, segmentation and packaging of the core shroud and in-core guide tubes. Some of the material is expected to exceed Class C disposal requirements. As such, those segments will be packaged in a modified fuel canister for geologic disposal. Interim storage can be in the pool, as space permits, or in the ISFSI.

o Removal and segmentation of the remaining internals including the jet pump assemblies, fuel support castings and core plate assembly.

• Draining and decontamination of the reactor well and permanently sealing of the spent fuel transfer gate. Install shielded platform for segmentation of reactor vessel. Cutting operations are performed in air using remotely operated equipment within a contamination control envelope, with the water level maintained just below the cut TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 Decommissioning CostAnalysis Section 2, Page 6 of 13 to minimize the working area dose rates. Sections are transferred to the dryer-separator pool for packaging and interim storage.

• Disconnection of the control rod drives and instrumentation tubes from reactor vessel lower head. The lower reactor head and vessel supporting structure will then be segmented.

• Removal of the reactor recirculation pumps. Exterior surfaces are decontaminated and openings covered. Components can serve as their own burial containers provided that all penetrations are properly sealed.

" Demolition of the sacrificial shield activated concrete by controlled demolition.

At least two years prior to the anticipated date of license termination, an LTP is required. Submitted as a supplement to the Final Safety Analysis Report (FSAR) or its equivalent, the plan must include: a site characterization, description of the remaining dismantling activities, plans for site remediation, procedures for the final radiation survey, designation of the end use of the site, an updated cost estimate to complete the decommissioning, and any associated environmental concerns. The NRC will notice the receipt of the plan, make the plan available for public comment, and schedule a local hearing. LTP approval will be subject to any conditions and limitations as deemed appropriate by the Commission. The licensee may then commence with the final remediation of site facilities and services, including:

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

• Removal of the steel liners from the drywell, disposing of the activated and contaminated sections as radioactive waste. Removal of any activated/contaminated concrete.

• Removal of the steel liners from the steam separator and dryer pool, reactor well and spent fuel storage pool.

• Surveys of the decontaminated areas of the containment structure.

" Removal of the contaminated equipment and material from the Turbine and Radwaste buildings and any other contaminated facility.

Use radiation and contamination control techniques until radiation surveys indicate that the structures can be released for unrestricted access and conventional demolition. This activity may necessitate the TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 0 DecommissioningCost Analysis Section 2, Page 7 of 13 dismantling and disposition of most of the systems and components (both clean and contaminated) located within these buildings. This activity will facilitate surface decontamination and subsequent verification surveys required prior to obtaining release for demolition.

Incorporated into the LTP is the Final Survey Plan. This plan identifies the radiological surveys to be performed once the decontamination activities are completed and is developed using the guidance provided in the "Multi-Agency Radiation Survey and Site Investigation Manual (MARSSIM)."[ I6 This document incorporates the statistical approaches to survey design and data interpretation used by the EPA. It also identifies state-of-the-art, commercially available instrumentation and procedures for conducting radiological surveys. Use of this guidance ensures that the surveys are conducted in a manner that provides a high degree of confidence that applicable NRC criteria are satisfied. Once the survey is complete, the results are provided to the NRC in a format that can be verified. The NRC then reviews and evaluates the information, performs an independent confirmation of radiological site conditions,

• and makes a determination on final termination of the license.

The NRC will terminate the operating license if it determines that site remediation has been performed in accordance with the LTP, and that the terminal radiation survey and associated documentation demonstrate that the facility is suitable for release.

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

Although performed in a controlled, safe manner, blasting, coring, drilling, scarification (surface removal), and the other decontamination activities will substantially degrade power block structures including the reactor, augmented radwaste, radwaste and turbine buildings.

Under certain circumstances, verifying that subsurface radionuclide concentrations meet NRC site release requirements will require removal of grade slabs and lower floors, potentially weakening footings and structural supports. This removal activity will be necessary for those facilities and plant areas where historical records, when available, indicate the potential for radionuclides having been present in the soil, where system failures have been recorded, or where it is required to TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 Decommissioning CostAnalysis Section 2, Page8 of 13 confirm that subsurface process and drain lines were not breached over the operating life of the station.

Prompt dismantling of site structures is clearly the most appropriate and cost-effective option. It is unreasonable to anticipate that these structures would be repaired and preserved after the radiological contamination is removed. The cost to dismantle site structures with a work force already mobilized on site is more efficient than if the process were deferred. Site facilities quickly degrade without maintenance, adding additional expense and creating potential hazards to the public as well as to future workers. Abandonment creates a breeding ground for vermin infestation as well as other biological hazards.

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

Foundations and exterior walls are removed to a nominal depth of three feet below grade. The three-foot depth allows for the placement of gravel for drainage, as well as topsoil, so that vegetation can be established for erosion control. Site areas affected by the dismantling activities are restored and the plant area graded as required to prevent ponding and inhibit the refloating of subsurface materials.

Non-contaminated concrete rubble produced by demolition activities is processed to remove reinforcing steel and miscellaneous embedments.

The processed material is then used on site to backfill foundation voids.

Excess non-contaminated materials are trucked to an off-site area for disposal as construction debris.

2.1.4 ISFSI Operations and Decommissioning The ISFSI will continue to operate under a separate and independent license (10 CFR §72) following the termination of the §50 operating license. Assuming the DOE starts accepting fuel from commercial generators in 2020, transfer of spent fuel from the ISFSI to the DOE would begin in 2027, with the transfer completed by 2046 for a 2014 shutdown and year 2061 for a 2034 shutdown.

At the conclusion of the spent fuel transfer process, the ISFSI will be decommissioned. The Commission will terminate the §72 license when it determines that the remediation of the ISFSI has been performed in accordance with an ISFSI license termination plan and that the final radiation survey and associated documentation demonstrate that the TLG Services, Inc.

CooperNuclear Station DocunentN01-1590-002,Rev. 1 DecommissioningCost Analysis Section 2, Page9 of 13 facility is suitable for release. Once the requirements are satisfied, the NRC can terminate the license for the ISFSI.

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

2.2 SAFSTOR AND DELAYED DECOMMISSIONING The NRC defines SAFSTOR as "the alternative in which the nuclear facility is placed and maintained in a condition that allows the nuclear facility to be safely stored and subsequently decontaminated (deferred decontamination) to levels that permit release for unrestricted use." The facility is left intact (during the dormancy period), with structures maintained in a sound condition. Systems not required to operate in support of the spent fuel pool or site surveillance and security are drained, de-energized, and secured.

Minimal cleaning/removal of loose contamination and/or fixation and sealing of remaining contamination is performed. Access to contaminated areas is secured to provide controlled access for inspection and maintenance.

The engineering and planning requirements are similar to those for the DECON alternative, although a shorter time period is expected for these activities due to the more limited work scope. Site preparations are also similar to those for the DECON alternative. However, with the exception of the required radiation surveys and site characterizations, the mobilization and preparation of site facilities is less extensive.

The following discussion is appropriate for both the SAFSTOR and Delayed DECON scenarios, the primary differences being in the length of the dormancy period. In the Delayed DECON scenario, decommissioning operations are assumed to begin once fuel is off site. By contrast, in the SAFSTOR scenario, the plant remains in safe-storage after the fuel is removed from site. Decommissioning operations are initiated such that the license is terminated within the required 60-year time period.

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 2, Page 10 of 13 2.2.1 Period 1 - Preparations Preparations for long-term storage include the planning for permanent defueling of the reactor, revision of technical specifications appropriate to the operating conditions and requirements, a characterization of the facility and major components, and the development of the PSDAR.

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

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

• Relocation of the spent fuel from the spent fuel storage pool to the ISFSI.

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

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

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

• Draining and de-energizing non-essential, contaminated systems with decontamination as required for future maintenance and inspection.

• Preparing lighting and alarm systems whose continued use is required; de-energizing portions of fire protection, electric power, and HVAC systems whose continued use is not required.

• Cleaning of the loose surface contamination from building access pathways.

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

• Erecting physical barriers and/or securing all access to radioactive or contaminated areas, except as required for inspection and maintenance.

TLG Services, Inc.

CooperNuclearStation Document N01-1590.002,Rev. 1 DecommissioningCost Analysis Section 2, Page 11 of 13 Installing security and surveillance monitoring equipment and relocating security fence around secured structures, as required.

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

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

An environmental surveillance program is carried out during the dormancy period to ensure that releases of radioactive material to the environment are prevented and/or detected and controlled.

Appropriate emergency procedures are established and initiated for potential releases that exceed prescribed limits. The environmental surveillance program constitutes an abbreviated version of the program in effect during normal plant operations.

Security during the dormancy period is conducted primarily to prevent unauthorized entry and to protect the public from the consequences of its own actions. The security fence, sensors, alarms, and other surveillance equipment provide security. Fire and radiation alarms are also monitored and maintained. While remote surveillance is an option, it does not offer the immediate response time of a physical presence.

The transfer of the spent fuel to a DOE facility continues during this period until complete. After an optional period of storage (such that license terminations are accomplished within 60 years of final shutdown), it is required that the licensee submit applications to terminate the license, along with an LTP (described in Section 2.1.2),

thereby initiating the third phase.

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CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 2, Page 12 of 13 2.2.3 Periods 3 and 4 - Delayed Decommissioning Prior to the commencement of decommissioning operations, preparations are undertaken to reactivate site services and prepare for decommissioning. Preparations include engineering and planning, a detailed site characterization, and the assembly of a decommissioning management organization. Final planning for activities and the writing of activity specifications and detailed procedures are also initiated at this time.

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

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

The delay in decommissioning also yields lower working area radiation levels. As such, the estimates for the delayed scenarios incorporate reduced ALARA controls for the lower occupational exposure potential.

Although the initial radiation levels due to 6°Co will decrease during the dormancy period, the internal components of the reactor vessel will still exhibit sufficiently high radiation dose rates to require remote sectioning under water due to the presence of long-lived radionuclides such as 94Nb, 59 Ni, and 63Ni. Therefore, the dismantling procedures described for the DECON alternative would still be employed during deferred scenarios. Portions of the sacrificial shield will still be radioactive due to the presence of activated trace elements with long half-lives (152 Eu and 154Eu). Decontamination will require controlled TLG Services, Inc.

Cooper NuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 2, Page13 of 13 removal and disposal. It is assumed that radioactive corrosion products on inner surfaces of piping and components will not have decayed to levels that will permit unrestricted use or allow conventional removal.

These systems and components will be surveyed as they are removed and disposed of in accordance with the existing radioactive release criteria.

2.2.4 Period 5 - Site Restoration Following completion of decommissioning operations, site-restoration activities can begin. If the site structures are to be dismantled, dismantling as a continuation of the decommissioning process is clearly the most appropriate and cost-effective option, as described in Section 2.1.3. The basis for the dismantling cost in the deferred scenarios is consistent with that described for DECON, presuming the removal of structures and site facilities to a nominal depth of three feet I

below grade and the limited restoration of the site.

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 3, Page 1 of29

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

3.1 BASIS OF ESTIMATES The current estimates are area-based estimates, i.e., the plant inventory has been correlated with site-specific area working conditions, and the plant work activities organized into discrete areas to better reflect the manner in which the decommissioning will take place. The areas were determined on the basis of "common" conditions or attributes. Each area was evaluated for work difficulty, including affects of radiation, external surface contamination, and access. This evaluation was used to adjust the work difficulty factors for removing equipment in a given area.

3.2 METHODOLOGY The methodology used to develop the estimates follows the basic approach originally presented in the cost estimating guidelines developed by the Atomic Industrial Forum (now Nuclear Energy Institute). The "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates," (AIF/NESP-036) [17] and the DOE "Decommissioning Handbook."[' 8 ]

describe a unit cost factor method for estimating decommissioning activity costs. The unit cost factors used in this analysis were developed using these guidance documents, updated for more recent decommissioning experience and modified to incorporate site-specific costs.

The activity-dependent costs were then estimated with the item quantities (cubic yards and tons), developed from plant drawings and plant design information. A data base was constructed identifying the installed equipment in each designated work area. This data base contains a list of components that have a unique identifier, such as valves, tanks, electrical equipment, and heat exchangers. It also contains bulk commodities such as piping, ventilation ductwork, cable tray, electrical conduit, and supports. Data base categories were consistent with unit cost factors described previously.

TLG Services, Inc.

Cooper NuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 3, Page 2 of29 Removal rates and material costs for the conventional disposition of components and structures relied upon information available in the industry publication, "Building Construction Cost Data," published by R.S. Means.[1 91 The unit factor method provides a demonstrable basis for establishing reliable cost estimates. The detail provided in the unit factors, including activity duration, labor costs (by craft), and equipment and consumable costs, ensures that essential elements have not been omitted. Appendix A presents the detailed development of a typical unit factor. Appendix B provides the values contained within one set of factors developed for this analysis.

The inventory was also organized according to its proposed disposition. There were three primary waste streams identified for the Cooper inventory: (1) clean material (expected to meet the release criteria without any decontamination),

(2) contaminated material with recovery potential or requiring additional processing for disposal (expected to be sent to an off-site waste processor), and (3) contaminated material designated for direct disposal at a controlled low-level radioactive waste disposal site (i.e., material expected to exceed waste processor acceptance criteria or uneconomical to process).

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

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

Work Difficulty Factors TLG has historically applied work difficulty adjustment factors (WDFs) to account for the inefficiencies in working in a power plant environment. WDFs are assigned to each unique set of unit factors, commensurate with the working conditions. The ranges used for the WDFs are as follows:

TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 Decommissioning CostAnalysis Section 3, Page3 of 29 o Access Factor 0% to 30%

" Respiratory Protection Factor 0% to 50%

o Radiation/ALARA Factor 0% to 100%

• Protective Clothing Factor 0% to 50%

o Work Break Factor 8.33%

The factors and their associated range of values were originally developed in conjunction with the AIF/NESP-036 study. The factors (and their suggested application) are discussed in more detail in Appendix E.

Scheduling Program Durations Area activity durations are used to develop the total decommissioning program schedule. The unit cost factors, adjusted for WDFs as described above, are applied against the inventory of materials to be removed in each defined work area. The work area is then evaluated for the most efficient number of workers/crews for the identified decommissioning activities. The adjusted unit cost factors are then compared against the available manpower so that an overall duration for removal of components and piping from each work area can be calculated.

The schedule is used to assign carrying costs, which include program management, administration, field engineering, equipment rental, and support services such as quality control and security.

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

Inherent in any cost estimate that does not rely on historical data is the inability to specify the precise source of costs imposed by factors such as tool breakage, accidents, illnesses, weather delays, and labor stoppages. In the DECCER cost model, contingency fulfills this role. Contingency is added to each line item to account for costs that are difficult or impossible to develop analytically. Such costs are historically inevitable over the duration of a job of this magnitude; therefore, this cost analysis includes funds to cover these types of expenses.

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Cooper NuclearStation Document N01-1590-002, Rev. 1 DecommissioningCostAnalysis Section 3, Page 4 of 29 3.3.1 Contingency The activity- and period-dependent costs are combined to develop the total decommissioning cost. A contingency is then applied on a line-item basis, using one or more of the contingency types listed in the AIF/NESP-036 study. "Contingencies" are defined in the American Association of Cost Engineers "Project and Cost Engineers' Handbook"[201 as "specific provision for unforeseeable elements of cost within the defined project scope; particularly important where previous experience relating estimates and actual costs has shown that unforeseeable events which will increase costs are likely to occur." The cost elements in this analysis are based upon ideal conditions and maximum efficiency; therefore, consistent with industry practice, contingency is included. In the AIF/NESP-036 study, the types of unforeseeable events that are likely to occur in decommissioning are discussed and guidelines are provided for percentage contingency in each category. It should be noted that contingency, as used in this analysis, does not account for price escalation and inflation in the cost of decommissioning over the remaining operating life of the station.

Contingency funds are an integral part of the total cost to complete the decommissioning process. Exclusion of this component puts at risk a successful completion of the intended tasks and, potentially, subsequent related activities. For this study, TLG examined the major activity-related problems (decontamination, segmentation, equipment handling, packaging, transport, and waste disposal) that necessitate a contingency. Individual activity contingencies ranged from 10% to 75%,

depending on the degree of difficulty judged to be appropriate from TLG's actual decommissioning experience. The contingency values used in this study are as follows:

• Decontamination 50%

" Contaminated Component Removal 25%

" Contaminated Component Packaging 10%

" Contaminated Component Transport 15%

o Low-Level Radioactive Waste Disposal 25%

o Reactor Segmentation 75%

• NSSS Component Removal 25%

o Reactor Waste Packaging 25%

• Reactor Waste Transport 25%

o Reactor Vessel Component Disposal 50%

" GTCC Disposal 15%

TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 3, Page5 of 29 o Non-Radioactive Component Removal 15%

o Heavy Equipment and Tooling 15%

" Supplies 25%

" Engineering 15%

o Energy 15%

o Characterization and Termination Surveys 30%

o Construction 15%

o Taxes and Fees 10%

o Insurance 10%

o Staffing 15%

The contingency values are applied to the appropriate components of the estimates on a line item basis. A composite value is then reported at the end of each detailed estimate (as provided in Appendices C and D).

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

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

Consideration is sometimes necessary to generate a level of confidence in the estimate, within a range of probabilities. TLG considers these types of costs under the broad term "financial risk." Included within the category of financial risk are:

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

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

Changes in the project work scope from the baseline estimate, involving the discovery of unexpected levels of contaminants, contamination in places not previously expected, contaminated soil previously undiscovered (either radioactive or hazardous material TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 0 Decommissioning CostAnalysis Section 3, Page6 of 29 contamination), variations in plant inventory or configuration not indicated by the as-built drawings.

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

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

o Pricing changes for basic inputs such as labor, energy, materials, and disposal. Items subject to widespread price competition (such as materials) may not show significant variation; however, others such as waste disposal could exhibit large pricing uncertainties, particularly in markets where limited access to services is available.

It has been TLG's experience that the results of a risk analysis, when compared with the base case estimate for decommissioning, indicate that the chances of the base decommissioning estimate's being too high is a low probability, and the chances that the estimate is too low is a higher probability. This is mostly due to the pricing uncertainty for low-level radioactive waste burial, and to a lesser extent due to schedule increases from changes in plant conditions and to pricing variations in the cost of labor (both craft and staff). This cost study, however, does not add any additional costs to the estimate for financial risk, since there is insufficient historical data from which to project future liabilities. Consequently, the areas of uncertainty or risk are revisited periodically and addressed through repeated revisions or updates of the base estimates.

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

3.4.1 Spent Fuel Management The cost to dispose the spent fuel generated from plant operations is not reflected within the estimates to decommission Cooper. Ultimate disposition of the spent fuel is within the province of the DOE's Waste Management System, as defined by the Nuclear Waste Policy Act. As such, the disposal cost is financed by a 1 mill/kWhr surcharge paid into TLG Services, Inc.

CooperNuclear Station Document N01-1590-002,Rev. 1 DecommissioningCost Analysis Section 3, Page 7 of 29 the DOE's waste fund during operations. However, the NRC requires licensees to establish a program to manage and provide funding for the management of all irradiated fuel at the reactor site until title of the fuel is transferred to the Secretary of Energy. This funding requirement is fulfilled through inclusion of certain high-level waste cost elements within the estimates, as described below.

Completion of the decommissioning process is highly dependent upon the DOE's ability to remove spent fuel from the site. The timing for removal of spent fuel from the site is based upon the DOE's most recently published annual acceptance rates of 400 MTU/year for year 1, 3,800 MTU total for years 2 through 4 and 3,000 MTU/year for year 5 and beyond.[211 The DOE contracts provide mechanisms for altering the oldest fuel first allocation scheme, including emergency deliveries, exchanges of allocations amongst utilities and the option of providing priority acceptance from permanently shutdown nuclear reactors.

Because it is unclear how these mechanisms may operate once DOE begins accepting spent fuel from commercial reactors, this study assumes that DOE will accept spent fuel in an oldest fuel first order.

Morris Wet-Pool Storage Facility NPPD has 1,054 spent fuel assemblies from Cooper in storage at General Electric's wet-pool ISFSI in Morris, Illinois. This analysis assumes that this inventory is preferentially transferred to the DOE, starting in 2022. Completion of the transfer would be in year 2027. At that time, the transfer of spent fuel would be exclusively from the Cooper site.

ISFSI The ISFSI, constructed to support plant operations, will continue to operate throughout decommissioning, and beyond the termination of the operating license in the DECON decommissioning scenario, until such time that the transfer of spent fuel to the DOE can be completed.

Assuming that DOE commences repository operation in 2020, and Morris fuel is transferred first, spent fuel from the Cooper site is projected to be removed beginning in 2027. The process is expected to be completed by the year 2046 for a 2014 shutdown and year 2061 for a 2034 shutdown. The process is similar for the Delayed DECON and SAFSTOR scenarios; however, based upon the expected completion date for fuel transfer, the ISFSI will be emptied prior to the commencement of decommissioning operations.

TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 3, Page8 of 29 Operation and maintenance costs for the ISFSI are included within the estimate and address the cost for staffing the facility, as well as security, insurance, and licensing fees. The estimates include the costs to purchase, load, and transfer the fuel storage canisters. Costs are also provided for the final disposition of the facility once the transfer is complete.

Storage Canister Design The design and capacity of the ISFSI is based upon the NUHOMS system, with a 61 fuel assembly capacity. A unit cost of $785,000 is used for pricing the internal multi-purpose canister (MPC) and the horizontal concrete storage module.

Canister Loading and Transfer An average cost of $440,000 is used for the labor and equipment to seal each spent fuel canister once it is loaded and for the labor to transfer the spent fuel canister from the pool into a DOE transport cask or onto the ISFSI pad. For estimating purposes, 50% of this cost is used to estimate the cost to transfer the fuel from the ISFSI into a DOE transport cask.

Operations and Maintenance An annual cost (excluding labor) of approximately $746,000 and $85,000 are used for operation and maintenance of the spent fuel pool and the ISFSI, respectively. Pool operations are expected to continue approximately 51/2 years after the cessation of operations. ISFSI operating costs are based upon expectations of DOE performance, as described previously.

ISFSI Design Considerations A multi-purpose (storage and transport) dry shielded storage canister with a horizontal, reinforced concrete storage module is used as a basis for the cost analysis. The final core off load, equivalent to 8 modules, are assumed to have some level of neutron-induced activation as a result of the long-term storage of the fuel (i.e., to levels exceeding free-release limits). The steel support structure is assumed to be removed from these modules for controlled disposal. The cost of the disposition of this material, as well as the demolition of the ISFSI facility, is included in the estimates.

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 Decommissioning CostAnalysis Section 3, Page9 of 29 GTCC The dismantling of the reactor internals generates radioactive waste considered unsuitable for shallow land disposal (i.e., low-level radioactive waste with concentrations of radionuclides that exceed the limits established by the NRC for Class C radioactive waste (GTCC)).

The Low-Level Radioactive Waste Policy Amendments Act of 1985 assigned the federal government the responsibility for the disposal of this material. The Act also stated that the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste. Although there are strong arguments that GTCC waste is covered by the spent fuel contact with DOE and the fees being paid pursuant to that contract, DOE has taken the position that GTCC waste is not covered by that contract or its fees and that utilities will have to pay an additional fee for the disposal of their GTCC waste. However, to date, the federal government has not identified a cost for disposing of GTCC or a schedule for acceptance. As such, the GTCC radioactive waste has been packaged and disposed of as high-level waste, at a cost equivalent to that envisioned for the spent fuel.

For purposes of this study, GTCC is packaged in the same canisters used to store spent fuel. Disposal costs are based upon a cost equivalent to that envisioned for the spent fuel. It is not anticipated that the DOE would accept this waste prior to completing the transfer of spent fuel.

Therefore, until such time the DOE is ready to accept GTCC waste, it is reasonable to assume that this material would remain in storage with the spent fuel in the ISFSI at the Cooper site (for the DECON alternative). In the Delayed DECON and SAFSTOR scenarios, the GTCC material is shipped directly to a DOE facility as it is generated since the fuel has been removed from the site prior to the start of decommissioning and the ISFSI deactivated.

3.4.2 Reactor Vessel and Internal Components The reactor pressure vessel and internal components are segmented for disposal in shielded, reusable transportation casks. Segmentation is performed in the dryer-separator pool, where a turntable and remote cutter are installed. The vessel is segmented in place, using a mast-mounted cutter supported off the lower head and directed from a shielded work platform installed overhead in the reactor well.

Transportation cask specifications and transportation regulations dictate the segmentation and packaging methodology.

TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 3, Page 10 of 29 Intact disposal of reactor vessel shells has been successfully demonstrated at several of the sites currently being decommissioned.

Access to navigable waterways has allowed these large packages to be transported to the Barnwell disposal site with minimal overland travel.

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

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

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

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

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

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

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

With lower levels of activation, the vessel shell can be packaged more efficiently than the curie-limited internal components. This will allow the use of more conventional waste packages rather than shielded casks for transport (although some shielded casks are still required).

3.4.3 Primary System Components In the DECON scenario, the reactor recirculation system components are assumed to be decontaminated using chemical agents prior to the start of dismantling operations. This type of decontamination can be TLG Services, Inc.

CooperNuclear Station Document N01-1590-002,Rev. 1 DecommissioningCost Analysis Section 3, Page 11 of 29 expected to have a significant ALARA impact, since in this scenario the removal work is done within the first few years of shutdown. A decontamination factor (average reduction) of 10 is assumed for the process. Disposal of the decontamination solution effluent is included within the estimate as a "process liquid waste" charge. In the SAFSTOR scenario, radionuclide decay is expected to provide the same benefit and, therefore, a chemical decontamination is not included.

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

3.4.4 Main Turbine and Condenser The main turbine is dismantled using conventional maintenance procedures. The turbine rotors and shafts are removed to a laydown area. The lower turbine casings are removed from their anchors by controlled demolition. The main condensers are also disassembled and moved to a laydown area. Material is then prepared for transportation to an off-site recycling facility where it is surveyed and designated for either decontamination or volume reduction, conventional disposal, or controlled disposal. Components are packaged and readied for transport in accordance with the intended disposition.

3.4.5 Transportation Methods Contaminated piping, components, and structural material other than the highly activated reactor vessel and internal components will qualify as LSA-I, II or III or Surface Contaminated Object, SCO-I or II, as described in Title 49.[221 The contaminated material will be packaged in Industrial Packages (IP-1, IP-2, or IP-3, as defined in subpart 173.411) for transport unless demonstrated to qualify as their own shipping containers. The reactor vessel and internal components are expected to be transported in accordance with Part 71, as Type B. It is conceivable that the reactor, due to its limited specific activity, could qualify as LSA II or III. However, the high radiation levels on the outer surface would require that additional shielding be incorporated within the packaging so as to attenuate the dose to levels acceptable for transport.

TLG Services, Inc.

CooperNuclearStation Document N01.1590-002, Rev. 1 DecommissioningCostAnalysis Section 3, Page 12 of 29 Any fuel cladding failure that occurred during the lifetime of the plant is assumed to have released fission products at sufficiently low levels that the buildup of quantities of long-lived isotopes (e.g., l3 7 Cs, 9 0Sr, or transuranics) has been prevented from reaching levels exceeding those that permit the major reactor components to be shipped under current transportation regulations and disposal requirements.

Transport of the highly activated metal, produced in the segmentation of the reactor vessel and internal components, will be by shielded truck cask. Cask shipments may exceed 95,000 pounds, including vessel segment(s), supplementary shielding, cask tie-downs, and tractor-trailer. The maximum level of activity per shipment assumed permissible was based upon the license limits of the available shielded transport casks. The segmentation scheme for the vessel and internal segments is designed to meet these limits.

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

Transportation costs for material requiring controlled disposal are based upon the mileage to the EnergySolutions facility in Clive, Utah.

Transportation costs for off-site waste processing are based upon the mileage to Memphis, Tennessee. Truck transport costs are estimated using published tariffs from Tri-State Motor Transit.[2 ]

3.4.6 Low-Level Radioactive Waste Conditioning and Disposal To the greatest extent practical, metallic material generated in the decontamination and dismantling processes is processed to reduce the total cost of controlled disposal. Material meeting the regulatory and/or site release criterion, is released as scrap, requiring no further cost consideration. Conditioning (preparing the material to meet the waste acceptance criteria of the disposal site) and recovery of the waste stream is performed off site at a licensed processing center. Any material leaving the site is subject to a survey and release charge, at a minimum.

The mass of radioactive waste generated during the various decommissioning activities at the site is shown on a line-item basis in the detailed Appendices C and D, and summarized in Section 5. The quantified waste summaries shown in these tables are consistent with 10 CFR Part 61 classifications. Commercially available steel containers are presumed to be used for the disposal of piping, small components, TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 Decommissioning CostAnalysis Section 3, Page 13 of 29 and concrete. Larger components can serve as their own containers, with proper closure of all openings, access ways, and penetrations. The volumes are calculated based on the exterior package dimensions for containerized material or a specific calculation for components serving as their own waste containers.

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

Disposal fees are based upon estimated charges, with surcharges added for the highly activated components, for example, generated in the segmentation of the reactor vessel. The cost to dispose of the majority of the material generated from the decontamination and dismantling activities is based upon the current cost for disposal at EnergySolutions facility in Clive, Utah. Disposal costs for the higher activity waste (Class B and C) were based upon the last published rate schedule for non-compact waste for the Barnwell facility (as a proxy).

3.4.7 Site Conditions Following Decommissioning The NRC will terminate (or amend) the site license if it determines that site remediation has been performed in accordance with the license termination plan, and that the terminal radiation survey and associated documentation demonstrate that the facility is suitable for release. The NRC's involvement in the decommissioning process ends at this point.

Building codes and state environmental regulations dictate the next step in the decommissioning process, as well as the owner's own future plans for the site.

Structures are removed to a nominal depth of three feet below grade.

Concrete rubble generated from demolition activities is processed and made available as clean fill. The Intake Structure is assumed to be removed back to the riverbank. The riverbank and the station grounds will be regraded such that the site will have a final contour consistent with adjacent surroundings, i.e., the configuration of the Missouri River levee will be maintained. The large underground tunnels between the water intake and Turbine Building will be isolated, sealed, and abandoned in place. Site utilities and service piping are abandoned in TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 3, Page 14 of 29 place. Electrical manholes are backfilled with suitable earthen material and abandoned. Asphalt surfaces in the immediate vicinity of site buildings are broken up and removed.

The existing electrical switchyard and access roads will remain in support of the electrical transmission and distribution system. The site access road will be left intact.

The estimates do not assume the remediation of any contaminated soil.

This assumption may be affected by continued plant operations and/or future regulatory actions, such as the development of site-specific release criteria.

3.5 ASSUMPTIONS The following assumptions were made in the development of the estimates for decommissioning the Cooper unit.

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

3.5.2 Labor Costs The craft labor required to decontaminate and dismantle the nuclear unit is acquired through standard site contracting practices. The current cost of labor at the site is used as an estimating basis.

NPPD, as the licensee, will continue to provide site operations support, including decommissioning program management, licensing, radiological protection, and site security. A Decommissioning Operations Contractor (DOC) will provide the supervisory staff needed to oversee the labor subcontractors, consultants, and specialty contractors needed to perform the work required for the decontamination and dismantling effort. The DOC will also provide the engineering services needed to develop TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 3, Page 15 of 29 activity specifications, detailed procedures, detailed activation analyses, and support field activities such as structural modifications.

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

Security, while reduced from operating levels, is maintained throughout the decommissioning for access control, material control, and to safeguard the spent fuel.

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

The curie contents of the vessel and internals at final shutdown are derived from those listed in NUREG/CR-3474.[ 241 Actual estimates are derived from the curie/gram values contained therein and adjusted for the different mass of the Cooper components, projected operating life, and different periods of decay. Additional short-lived isotopes were derived from CR-0130[251 and CR-0672,[ 261 and benchmarked to the long-lived values from CR-3474.

The disposal cost for the control blades removed from the vessel with the final core load is included within the estimates. Disposition of any blades stored in the pools from operations is considered an operating expense and therefore not accounted for in the decommissioning estimates.

Activation of the Reactor Building structures is confined to the area around the sacrificial shield. More extensive activation (at very low levels) of the interior structures within containment has been detected at several reactors and the owners have elected to dispose of the affected material at a controlled facility rather than reuse the material as fill on site or sending it to a landfill. The ultimate disposition of the material removed from the Reactor Building will depend upon the site release criteria applied, as well as the designated end use for the Site.

TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 3, Page 16 of 29 3.5.4 General Transition Activities Existing warehouses are cleared of non-essential material and remain for use by NPPD and its subcontractors. The plant's operating staff performs the following activities at no additional cost or credit to the project during the transition period:

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

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

Process operating waste inventories, i.e., the estimates do not address the disposition of any legacy wastes; the disposal of operating wastes during this initial period is not considered a decommissioning expense.

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

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

It is assumed, for purposes of this analysis, that any value received from the sale of scrap generated in the dismantling process would be more than offset by the on-site processing costs. The dismantling techniques assumed in the decommissioning estimates do not include the additional cost for size reduction and preparation to meet "furnace ready" conditions. For example, the recovery of copper from electrical cabling may require the removal and disposition of any contaminated insulation, an added expense. With a volatile market, the potential profit margin in TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 3, Page 17 of 29 scrap recovery is highly speculative, regardless of the ability to free release this material. This assumption is an implicit recognition of scrap value in the disposal of clean metallic waste at no additional cost to the project.

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

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

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

Insurance Costs for continuing coverage (nuclear liability and property insurance) following cessation of plant operations and during decommissioning are included and based upon current operating premiums. Reductions in premiums, throughout the decommissioning process, are based upon the guidance and the limits for coverage defined in the NRC's proposed rulemaking "Financial Protection Requirements for Permanently Shutdown Nuclear Power Reactors."[271 The NRC's financial protection requirements are based on various reactor (and spent fuel) configurations.

Taxes The only tax payment (or fee) included in the estimates is associated with the river levee maintenance costs.

Site Modifications The perimeter fence and in-plant security barriers will be moved, as appropriate, to conform to the Site Security Plan in force during the various stages of the project.

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002,Rev. 1 Decommissioning Cost Analysis Section 3, Page 18 of 29 3.6 COST ESTIMATE

SUMMARY

Schedules of expenditures are provided in Tables 3.1 through 3.6. The tables delineate the cost contributors by year of expenditures as well as cost contributor (e.g., labor, materials, and waste disposal).

Decommissioning costs are reported in 2008 dollars. Costs are not inflated, escalated, or discounted over the period of expenditure (or projected lifetime of the plant). The schedules are based upon the detailed activity costs reported in Appendices C and D, along with the timelines presented in Section 4.

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

The "Spent Fuel Management" subcategory contains costs associated with the construction of an ISFSI, the containerization and transfer of spent fuel to the ISFSI over the five and one-half years of post-shutdown pool operations, and the management of the ISFSI until such time that the transfer of all fuel from this facility to an off-site location (e.g., geologic repository) is complete.

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

TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 3, Page19 of 29 TABLE 3.1 2014 DECON SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2008 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2014 47,079 9,874 1,016 87 7,982 66,039 2015 63,173 21,674 1,573 22,361 13,287 122,069 2016 49,998 21,848 1,004 41,033 9,480 123,362 2017 44,806 11,549 799 12,824 6,767 76,745 2018 44,806 11,549 799 12,824 6,767 76,745 2019 39,861 10,474 617 13,219 5,473 69,643 2020 25,445 3,467 181 49 2,123 31,266 2021 16,129 6,815 107 0 1,730 24,781 2022 9,078 3,166 44 0 1,764 14,052 2023 4,046 562 0 0 1,788 6,397 2024 4,057 564 0 0 1,793 6,414 2025 4,046 562 0 0 1,788 6,397 2026 4,046 562 0 0 1,788 6,397 2027 4,046 562 0 0 1,788 6,397 2028 4,057 564 0 0 1,793 6,414 2029 4,046 562 0 0 1,788 6,397 2030 4,046 562 0 0 1,788 6,397 2031 4,046 562 0 0 1,788 6,397 2032 4,057 564 0 0 1,793 6,414 2033 4,046 562 0 0 1,788 6,397 2034 4,046 562 0 0 1,788 6,397 2035 4,046 562 0 0 1,788 6,397 2036 4,057 564 0 0 1,793 6,414 2037 4,046 562 0 0 1,788 6,397 2038 4,046 562 0 0 1,788 6,397 2039 4,046 562 0 0 1,788 6,397 2040 4,057 564 0 0 1,793 6,414 2041 4,046 562 0 0 1,788 6,397 2042 4,046 562 0 0 1,788 6,397 2043 4,046 562 0 0 1,788 6,397 2044 4,057 564 0 0 1,793 6,414 2045 4,046 562 0 0 1,788 6,397 2046 4,061 1,334 0 1 10,384 15,779 TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 3, Page20 of 29 TABLE 3.1 (continued) 2014 DECON SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2008 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2047 1,819 868 0 68 1,597 4,352 439,379 115,564 6,141 102,465 108,509 772,058 TLG Services, Inc.

Cooper Nuclear Station Document N01-1590-002, Rev. 1 Decommissio~ning Cost Analysis Section 3, Page 21 of 29 TABLE 3.2 2014 Delayed DECON SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2008 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2014 38,591 9,434 1,016 87 7,982 57,111 2015 38,786 10,829 676 1,988 11,278 63,557 2016 12,446 5,991 214 62 3,851 22,564 2017 12,412 5,974 213 62 3,841 22,503 2018 12,412 5,974 213 62 3,841 22,503 2019 9,150 3,617 164 60 2,877 15,869 2020 5,297 824 107 58 1,739 8,025 2021 5,282 822 107 58 1,735 8,003 2022 5,282 822 107 58 1,735 8,003 2023 5,282 822 107 58 1,735 8,003 2024 5,297 824 107 58 1,739 8,025 2025 5,282 822 107 58 1,735 8,003 2026 5,282 822 107 58 1,735 8,003 2027 5,282 822 107 58 1,735 8,003 2028 5,297 824 107 58 1,739 8,025 2029 5,282 822 107 58 1,735 8,003 2030 5,282 822 107 58 1,735 8,003 2031 5,282 822 107 58 1,735 8,003 2032 5,297 824 107 58 1,739 8,025 2033 5,282 822 107 58 1,735 8,003 2034 5,282 822 107 58 1,735 8,003 2035 5,282 822 107 58 1,735 8,003 2036 5,297 824 107 58 1,739 8,025 2037 5,282 822 107 58 1,735 8,003 2038 5,282 822 107 58 1,735 8,003 2039 5,282 822 107 58 1,735 8,003 2040 5,297 824 107 58 1,739 8,025 2041 5,282 822 107 58 1,735 8,003 2042 5,282 822 107 58 1,735 8,003 2043 5,282 822 107 58 1,735 8,003 2044 5,297 824 107 .58 1,739 8,025 2045 1 5,282 822 1071 58 1,735 8,003 2046 1 5,360 824 1 109 158 1,732 8,082 TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 3, Page22 of 29 TABLE 3.2 (continued) 2014 Delayed DECON SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2008 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2047 33,523 1,412 1,066 77 743 36,822 2048 43,779 15,439 1,042 16,243 6,546 83,049 2049 40,386 14,058 931 25,770 8,761 89,906 2050 39,158 6,342 799 15,542 3,274 65,116 2051 39,158 6,342 799 15,542 3,274 65,116 2052 24,949 3,036 221 819 759 29,785 2053 13,322 6,769 107 0 38 20,236 2054 7,993 4,062 64 0 23 12,141 508,866 121,495 10,408 77,874 103,957 822,600 TLG Services, Inc.

Cooper Nuclear Station Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 3, Page 23 of 29 TABLE 3.3 2014 SAFSTOR SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2008 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2014 38,591 9,434 1,016 87 7,982 57,111 2015 38,786 10,829 676 1,988 11,278 63,557 2016 12,446 5,991 214 62 3,851 22,564 2017 12,412 5,974 213 62 3,841 22,503 2018 12,412 5,974 213 62 3,841 22,503 2019 9,150 3,617 164 60 2,877 15,869 2020 5,297 824 107 58 1,739 8,025 2021 5,282 822 107 58 1,735 8,003 2022 5,282 822 107 58 1,735 8,003 2023 5,282 822 107 58 1,735 8,003 2024 5,297 824 107 58 1,739 8,025 2025 5,282 822 107 58 1,735 8,003 2026 5,282 822 107 58 1,735 8,003 2027 5,282 822 107 58 1,735 8,003 2028 5,297 824 107 58 1,739 8,025 2029 5,282 822 107 58 1,735 8,003 2030 5,282 822 107 58 1,735 8,003 2031 5,282 822 107 58 1,735 8,003 2032 5,297 824 107 58 1,739 8,025 2033 5,282 822 107 58 1,735 8,003 2034 5,282 822 107 58 1,735 8,003 2035 5,282 822 107 58 1,735 8,003 2036 5,297 824 107 58 1,739 8,025 2037 5,282 822 107 58 1,735 8,003 2038 5,282 822 107 58 1,735 8,003 2039 5,282 822 107 58 1,735 8,003 2040 5,297 824 107 58 1,739 8,025 2041 5,282 822 107 58 1,735 8,003 2042 5,282 822 107 58 1,735 8,003 2043 5,282 822 107 58 1,735 8,003 2044 5,297 824 107 58 1,739 8,025 2045 5,282 822 107 58 1,735 8,003 2046 5,276 821 107 58 1,732 7,993 TLG Services, Inc.

Cooper Nuclear Station Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 3, Page 24 of 29 TABLE 3.3 (continued) 2014 SAFSTOR SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2008 dollars)

.Equipment &

Year Labor Materials Energy Burial Other Total 2047 3,063 249 107 56 671 4,146 2048 3,072 249 107 57 673 4,157 2049 3,063 249 107 56 671 4,146 2050 3,063 249 107 56 671 4,146 2051 3,063 249 107 56 671 4,146 2052 3,072 249 107 57 673 4,157 2053 3,063 249 107 56 671 4,146 2054 3,063 249 107 56 671 4,146 2055 3,063 249 107 56 671 4,146 2056 3,072 249 107 57 673 4,157 2057 3,063 249 107 56 671 4,146 2058 3,063 249 107 56 671 4,146 2059 3,063 249 107 56 671 4,146 2060 3,072 249 107 57 673 4,157 2061 3,063 249 107 56 671 4,146 2062 3,063 249 107 56 671 4,146 2063 3,063 249 107 56 671 4,146 2064 3,072 249 107 57 673 4,157 2065 3,063 249 107 56 671 4,146 2066 3,063 249 107 56 671 4,146 2067 3,063 249 .107 56 671 4,146 2068 25,078 1,070 801 72 725 27,745 2069 41,529 10,664 1,054 7,391 3,362 64,001 2070 40,733 17,502 981 30,409 11,019 100,644 2071 39,109 6,285 799 15,410 3,229 64,833 2072 39,216 6,303 802 15,453 3,238 65,011 2073 30,623 3,074 387 4,609 1,507 40,200 2074 13,962 6,534 112 3 72 20,683 2075 11,278 5,731 90 0 32 17,131

______ 572,411 126,422 12,641 78,413 117,822 907,708 TLG Services, Inc.

Cooper Nuclear Station Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 3, Page 25 of 29 TABLE 3.4 2034 DECON SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2008 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2034 44,992 3,613 1,016 87 7,982 57,690 2035 62,426 19,434 1,573 22,403 13,287 119,124 2036 49,346 19,889 1,004 41,120 9,480 120,838 2037 44,584 10,883 799 12,824 6,767 75,857 2038 44,584 10,883 799 12,824 6,767 75,857 2039 39,850 10,440 617 13,219 5,473 69,598 2040 25,569 3,838 181 49 2,142 31,779 2041 16,225 7,102 107 0 1,793 25,227 2042 9,093 3,211 44 0 1,790 14,139 2043 4,003 435 0 0 1,788 6,226 2044 4,014 436 0 0 1,793 6,243 2045 4,003 435 0 0 1,788 6,226 2046 4,003 435 0 0 1,788 6,226 2047 4,003 435 0 0 1,788 6,226 2048 4,014 436 0 0 1,793 6,243 2049 4,003 435 0 0 1,788 6,226 2050 4,003 435 0 0 1,788 6,226 2051 4,003 435 0 0 1,788 6,226

.2052 4,014 436 0 0 1,793 6,243 2053 4,003 435 0 0 1,788 6,226 2054 4,003 435 0 0 1,788 6,226 2055 4,003 435 0 0 1,788 6,226 2056 4,014 436 0 0 1,793 6,243 2057 4,003 435 0 0 1,788 6,226 2058 4,003 435 0 0 1,788 6,226 2059 4,003 435 0 0 1,788 6,226 2060 4,014 436 0 0 1,793 6,243 2061 4,023 1,212 0 1 10,384 15,620 2062 2,269 1,080 0 75 1,664 5,088 415,076 99,415 6,141 102,601 99,739 722,972 TLG Services, Inc.

Cooper Nuclear Station Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 3, Page 26 of 29 TABLE 3.5 2034 Delayed DECON SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2008 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2034 36,504 3,172 1,016 87 7,982 48,762 2035 38,173 8,992 676 1,988 11,278 61,108 2036 12,064 4,843 214 62 3,851 21,034 2037 12,031 4,830 213 62 3,841 20,977 20:38 12,031 4,830 213 62 3,841 20,977 2039 8,934 2,969 164 60 2,877 15,004 2040 5,276 763 107 58 1,739 7,944 2041 5,262 761 107 58 1,735 7,922 2042 5,262 761 107 58 1,735 7,922 2043 5,262 761 107 58 1,735 7,922 2044 5,276 763 107 58 1,739 7,944 2045 5,262 761 107 58 1,735 7,922 2046 5,262 761 107 58 1,735 7,922 2047 5,262 761 107. 58 1,735 7,922 2048 5,276 763 107 58 1,739 7,944 2049 5,262 761 107 58 1,735 7,922 2050 5,262 761 107 58 1,735 7,922 2051 5,262 761 107 58 1,735 7,922 2052 5,276 763 107 58 1,739 7,944 2053 5,262 761 107 58 1,735 7,922 2054 5,262 761 107 58 1,735 7,922 2055 5,262 761 107 58 1,735 7,922 2056 5,276 763 107 58 1,739 7,944 2057 5,262 761 107 58 1,735 7,922 2058 5,262 761 107 58 1,735 7,922 2059 5,262 761 107 58 1,735 7,922 2060 5,276 763 107 58 1,739 7,944 2061 5,339 763 109 58 1,732 8,001 2062 33,523 1,412 1,066 77 743 36,822 2063 43,666 15,393 1,039 17,523 6,519 84,140 2064 40,561 14,137 934 27,554 8,817 92,002 2065 39,319 6,395 799 15,559 3,313 65,385 2066 39,319 6,395 799 15,559 3,313 65,385 TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 3, Page 27 of 29 TABLE 3.5 (continued) 2034 Delayed DECON SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2008 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2067 24,928 2,963 221 820 761 29,693 2068 13,393 6,872 107 0 38 20,410 2069 8,014 4,112 64 0 23 12,213

___ 478,387 104,080 9,875 80,685 95,387 768,414 TLG Services, Inc.

Cooper Nuclear Station Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 3, Page 28 of 29 TABLE 3.6 2034 SAFSTOR SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2008 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2034 36,504 3,172 1,016 87 7,982 48,762 2035 38,173 8,992 676 1,988 11,278 61,108 2036 12,064 4,843 214 62 3,851 21,034 2037 12,031 4,830 213 62 3,841 20,977 2038 12,031 4,830 213 62 3,841 20,977 2039 8,934 2,969 164 60 2,877 15,004 2040 5,276 763 107 58 1,739 7,944 2041 5,262 761 107 58 1,735 7,922 2042 5,262 761 107 58 1,735 7,922 2043 5,262 761 107 58 1,735 7,922 2044 5,276 763 107 58 1,739 7,944 2045 5,262 761 107 58 1,735 7,922 2046 5,262 761 107 58 1,735 7,922 2047 5,262 761 107 58 1,735 7,922 2048 5,276 763 107 58 1,739 7,944 2049 5,262 761 107 58 1,735 7,922 2050 5,262 761 107 58 1,735 7,922 2051 5,262 761 107 58 1,735 7,922 2052 5,276 763 107 58 1,739 7,944 2053 5,262 761 107 58 1,735 7,922 2054 5,262 761 107 58 1,735 7,922 2055 5,262 761 107 58 1,735 7,922 2056 5,276 763 107 58 1,739 7,944 2057 5,262 761 107 58 1,735 7,922 2058 5,262 761 107 58 1,735 7,922 2059 5,262 761 107 58 1,735 7,922 2060 5,276 763 107 58 1,739 7,944 2061 5,256 760 107 58 1,732 7,912 2062 3,063 249 107 56 671 4,146 2063 3,063 249 107 56 671 4,146 2064 3,072 249 107 57 673 4,157 2065 3,063 2491 107 56 671 4,146 2066 3,063 2491 107 156 1 671 4,146 TLG Services, Inc.

CooperNuclearStation DocumentN01.1590-002, Rev. 1 DecommissioningCostAnalysis Section 3, Page29 of 29 TABLE 3.6 (continued) 2034 SAFSTOR SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2008 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2067 3,063 249 107 56 671 4,146 2068 3,072 249 107 57 673 4,157 2069 3,063 249 107 56 671 4,146 2070 3,063 249 107 56 671 4,146 2071 3,063 249 107 56 671 4,146 2072 3,072 249 107 57 673 4,157 2073 3,063 249 107 56 671 4,146 2074 3,063 249 107 56 671 4,146 2075 3,063 249 107 56 671 4,146 2076 3,072 249 107 57 673 4,157 2077 3,063 249 107 56 671 4,146 2078 3,063 249 107 56 671 4,146 2079 3,063 249 107 56 671 4,146 2080 3,072 249 107 57 673- 4,157 2081 3,063 249 107 56 671 4,146 2082 3,063 249 107 56 671 4,146 2083 3,063 249 107 56 671 4,146 2084 3,072 249 107 57 673 4,157 2085 3,063 249 107 56 671 4,146 2086 3,063 249 107 56 671 4,146 2087 3,063 249 107 56 671 4,146 2088 25,078 1,070 801 72 725 27,745 2089 41,651 10,681 1,054 7,544 3,410 64,340 2090 41,223 17,574 981 30,995 11,207 101,980 2091 39,269 6,326 799 15,413 3,257 65,064 2092 39,376 6,343 802 15,456 3,266 65,243 2093 30,670 3,086 387 4,610 1,515 40,268 2094 13,995 6,615 112 3 72 20,796 2095 11,307 5,802 90 0 32 17,231 557,843 110,367 12,641 79,152 112,799 872,803 TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 Decommissioning CostAnalysis Section 4, Page 1 of 22

4. SCHEDULE The schedules for the decommissioning scenarios considered in this analysis follow the general sequence presented in the AIF/NESP-036 study, with minor changes to reflect recent experience and site-specific constraints. In addition, the scheduling has been revised to reflect the spent fuel management plans described in Section 3.4.1.

Schedules or the individual sequence of activities for each scenario are presented in Figures 4.1 through 4.6. The schedules reflect the six scenarios identified in Section

2. The key activities listed in the schedules do not reflect a one-to-one correspondence with those activities in the detailed cost tables (shown in the Appendices C and D), but divide some activities for clarity and combine others for convenience. The schedule was prepared using "Microsoft Project Professional 2003" computer software. [28]

4.1 SCHEDULE ESTIMATE ASSUMPTIONS The schedules are generated using a precedence network and associated software. Activity durations are based upon the actual man-hour estimates calculated for each area (Appendix F). The schedules are assembled by sequencing the work areas, consider work crew availability and material access/egress. The following assumptions were made in the development of the decommissioning schedule(s).

o The fuel handling area of the Reactor Building is isolated until such time that all spent fuel has been discharged from the spent fuel pool to the DOE and/or the ISFSI. Decontamination and dismantling of the fuel handling area is initiated once the pool is emptied (DECON scenarios).

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

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

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

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 Decommissioning CostAnalysis Section 4, Page 2 of 22 For plant systems removal, the systems with the longest removal durations in areas on the critical path are considered to determine the duration of the activity.

4.2 PROJECT SCHEDULE The period-dependent costs presented in Appendices C and D are based upon the durations developed in the various schedules for decommissioning.

Durations are established between several milestones in each project period; these durations are used to establish a critical path for the entire project. In turn, the critical path duration for each period is used as the basis for determining the period-dependent costs.

Scenario timelines are provided as Figures 4.2 and 4.3. Milestone dates are based on either a 2014 or 2034 shutdown. In all cases, the fuel pool is emptied approximately 5Y years after shutdown, with ISFSI operations continuing at the site until the DOE can complete the transfer of assemblies to its geologic repository.

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002 Rev. 1 DecommissioningCost Analysis Section 4, Page3 of22 FIGURE 4.1 2014 DECON ACTIVITY SCHEDULE Cooper Nuclear Station 2014 hUlmOWn - I--

PLANTSHUTDOWN DATE- January 18, 2014 Wet Storage Delay 5 years. 6 months Preparaoton tar reactor vessel removal Reactor vessel 8 internals Recirt Pumps and Piping Drywell (Systems Pemoval)

TORUS

............. I Clean Structures Demolition in support of systems removal Reactor 903 Elevation Reactor El 903 Areal Turbine 932 Elevation Main Turtine/Generator Turbine El 932 Areal Turbine El 932 Area2 Turbine El 932 Area3 Turbine 903 Elevation Main Condenser Dry fuel operations Fuel storage pool operations Muoti-Purpose Building Multi-Purpose Facility Mula-Purpose FacilityDECON APW Building Augmented Radwaste El 929 Augmented RtoowasteEl 918 Augmented Racwaste El 903 Augmented Padwaste El 877 Augmented Radlwaste Decon Protected Area Yard (contaminated structmures Dhwell Lner Reactor 859 Elevation Reactor El 859 Area2 Reactor El 859 Areal Reactor El 859 Area3 Reactor El 859 Area4 Reactor El 859 Area5 Reactor 903 Elevation Reactor El 903 Area2 Reactor El 903 Area3 Reactor El 903 Area4 v V I

TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 4, Page4 of 22 FIGURE 4.1 2014 DECON ACTIVITY SCHEDULE (continued)

TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 4, Page5 of 22 FIGURE 4.1 2014 DECON ACTIVITY SCHEDULE (continued)

DESCRIPTION Y-6 IY-2 MY3 Ii17 IyU IY15 Y19

. Y23 1Y27 1Y31 Reactor 976 Elevation Reactor El 976 Areal ReactorEl976Areti2 Reactor 1001 Elevation Reactor El 1001 Areal PostFuelDECON Dry fuel operations Building demolitons, backlill and landscaping Demolition0fOtherStructures Demolition0f Turbine, Cnntiol&ReactorBldg LantiscapeSite Per~oS 3c Fuel Storage Operallons &Snipping Peno Periotd 3d GTCC Snipping 3eISF5 Decontamnination

,..oo. ,,*,,o....... ........ . !

Penod 3' ISFSI Site Restoration Epd ofProject July , 2047 TLG Services, Inc.

Cooper NuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 4, Page6 of 22 FIGURE 4.2 2014 Delayed DECON ACTIVITY SCHEDULE aECiFNlI IYS IY9 Y13 IY17 IY21 IY25 IY29 I Y3 !Y7 IY41 Plant Shutdown January 18, 2014 Pe0od 13Shutdown Through Transibon Period tOLimited DECON ACtroles Period lc Preparations for SAFS TOP Period 20 SAFS TOP Dormancy / Wet Fuel

'. 1 Peirold 2 SAFSTOP Dormancy/ Dry Fuel 1

Period 2c SAFSTOI Donmancy / No Fuel Reactrvate Site Reconfigure plant ......

Site speotic decommissioning cost estimate submitted Pecontgure plant (continued)

Prepare detailed worn procedures Decon NSSS J Preparation for reactor vessel remroval Reactor vessel & internals Pecirc Pumps &Piping Orywell (Systems Removal)

TORUS 0, Turbine 932 Elevation Main Turnine/Generator Turbine El 932 Areal TurbIne El 932 Are32 I

Turbine El 932 Area3 Turbine 903 Elevaton Main Condenser APW Building Augmented Pactwaste EP 929 Areal Augmented Padoaste El 916 Arear Augmented Radwaste El 903 Arear Augmented Radwaste El 877 Areal Augmented Radwaste Decon Protected Area Yard (contaminated structures)

I4; , :ý " 7* ,1, t, Drywell Liner Reactor 903 Elevaton

.. .............. ... ..... .... h ........

Reactor El 903 Areal Reactor El 903 Area2 Reactor 859 Elevation Reactor El 859 Area2 Reactor El 859 Areal ------ -

Reactor El 859 Area,?

ReItrEl89Ira'Ii TLG Services, Inc.

CooperNuclearStation DocumentNO1-1590-OO Rev. 1 Decommissioning Cost Analysis Section 4, Page 7 of 22 FIGURE 4.2 2014 Delayed DECON ACTIVITY SCHEDULE (continued)

)ESCRIPTION i yl I y5 (r 113 IYl7 I 21 IY25 IY29 Y33 IY37 IY41 Reac~or E1u59 Area4 Reactor El 859Area5 Reactor 903 Elevation Reactor El 903 Area3 Reactor El 903 Area4 Reactor 931 Elevation Reactor El 931 Areal Reactor El 931 Area2 Reactor El 931 Area3 Reactor El 931 Areat Reactor El 931 Area5 Reactor 958 Elevation Reactor El 958 Areal Reactor El 958 Area2 Reactor El 958 Area3 Reactor 976 Elevation Reactor El 976 Areal

...I Reactor El 976 Area2 Reactor t001Elevation Reactor El 1001Areal Post Fuel DECON Reactor Building DECON irhrip. 903 Flevatlnn Turbine El 903 Areal Turbine El 903 N.e32 Turbine El 903 Area3 Turbine El 903 Nea4 l "

Turbine 802 Elevation - ... ... .... . .....

Turbine El 882 Areal Turbine El 882 Area2 Turbone El 82 Area3 Turbine Bl0g . DECON a Control Bulding Control El 932 Areal

........i

..... ....... .......... ~ 1. i ,,,..... .. .

Control El 918 Areal Control El 903 Areal 082 Areal Control El Radwaste Building RacW3ste El 949 Areal Racteraste El 934 Area2 Radwaste El 934 Areal Radwaste El 918 Areal Raclwaste El 918 Area2 Pactwaste El 918 Area3 Ractwaste El 903 Area3 Raitwaste El 903 Area2 TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 4, Page8 of22 FIGURE 4.2 2014 Delayed DECON ACTIVITY SCHEDULE (continued) 3 DESCRIPTION YI IY5 I9M Iy1 IY17 Y21 !Y25 IY29 ]Y33 Y37 IY41 Ractwaste El 903Areal Radw~aste El .877Areal RadwasteEl 877Area2 Raileaste El 877Area3 Racreaste-DECON Multi-Purpose Buldiog . . .  : .

Multi-Purpose Facilyit Multi-Purpose FacilityDEC00 Protected Area Yad(emoians truturerstr)ue Uicense Terminated B8011dlgdem olrttons. tiacIk1l1and lanldscaping.. ....... ......... ....... .... .. . . . ... ... ..... . . ....... .... . . . . ..

Demoltinounof Turoine. Control & Reactor 81dgs Landscape Site ieRestoraton Complete- August 8. 2r04e TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 4, Page9 of 22 FIGURE 4.3 2014 SAFSTOR ACTIVITY SCHEDULE cecoluninNi T ooperNaucear Station 2034 Shutdown Plant Shutdown January 18, 2014 Period la Shutdown Through Transiion Perod lb ULmitedDECON Actir4es Perod Ic Preparations for SAFS TOP Period 2a SAFSTOR Dormancy I Wet Fuel Peirod 2b SAFSTOR Dormancy/ODi Fuel Period 2c SAFSTO: Dormancy / No Fuel Reactvate Site Date set at 1/18184 51vr- Lr-~vteý t' Reconfigure plant Site specific decommissioning cost estimate submitted Pecoengure plant (continued)

Prepare detailed work procedures Decon NSSS Preparabon for reactor vessel removal Reactor vessel & internals Recirt Pumps &Piping Drwell (Systems Removal)

TORUS Tiriune 032 FlPiatinn Main Turbine/Generator Turbine E1932 Areal Turbine El 932 Area2 Turbine E1932 Area3 Turbine 903 Elevation ---- - - ----

Main Condenser ARW Building Augmented Raomaste El 929 Areal Augmented Radtwaste El 918 Areal Augmented Ractwaste El 903 Areal Augmented Racwaste El 877 Areal Augmented Radwaste Decon I Protected Area Yard (contaminated structures)

Drywell Uner Reactor 903 Elevation Reactor El 903 Areal Reactor El 903 Area2 Reactor 859 Elevation Reactor El 859 Area2 Reactor El 859 Areal Reactor El 859 Area3 TLG Services, Inc.

Cooper NuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 4, Page 10 of22 FIGURE 4.3 2014 SAFSTOR ACTIVITY SCHEDULE (continued)

DESCRIPTION Y? 1Y5 IY9 IY13 IY17 IY21 1Y25 1(29 IY33 IY37 IY41 1'(45 1Y49 I Y53 1Y57 IY61 Reactor El 859 Areat ..-.

ReactorEl 859ArearO Reactor 903 Elevation Reactor El 903 Area3 Reactor El 903 Area4 Reactor 931 Elevation Reactor El 931 Areal Reactor El 931 Area2 Reactor El 931 Area3 Pe el. c o l9 8 A .. .. ........... ............. ..------- ... ........ [...

Reactor El 931 Areat Reactor El 931 Are'a Reactor 958 Elevatl ON RPeactor El 908 Areal Reactor El 908 Area2 Reactor El 908 Area3 Reactor976Elevation Reactor El 976 Areal Reactor El 976 Area2 Reactor1 Elev Areatio PostFuelDECOR ReactorBuildingDECOR TIM-,0 9113Flevorio Turbine El903 Areat Tur**ne El 903 Area2 TurbineEl 903Ar003 Turbine El 903 irea4 Turbine882Elevat~on TurbinfeE01882 ArealI Tur*iane E1862 Nea2r I* a~iw s te B Uld l .....

• J . ..... . .. . .... ....... ...... .. .... ... .... .. .. .. . . .... . . ..... ........ ...

TurbilneEl1882 Area3 Turbine 8ldg9-DECOR Nl ControlBuiling.

ControlEl 922Areal ControlEl 918Areal ControlEl 903Areal Control Areal 901882 ....

RactwasteBuilding RaltwasateEl1949 Areal RactreasteEl 934Area2 Ractreaste El 934Areal Ractwaste El 918Areal Rartwaste El 918Aea2 01l~~e l918 Area3 Radaraste 01903Nea33 Radineaste El1903Area2 0

TLG Services, Inc.

CooperNuclear Station Document N01-1590-002,Rev. 1 DecommissioningCost Analysis Section 4, Page 11 of 22 FIGURE 4.3 2014 SAFSTOR ACTIVITY SCHEDULE (continued)

DESCRIPTION Yl IY5 IY9 1Y 13 JYl7 IY21 IY25 IY29 lY33 IY37 IY41 1Y45 IY49 Y53 Y57 Y61 Padwaste El 903 Areal MaI*-oste El -877neal RadtwaSteEl 877 Area2 Ractwaste El 877 Area3 Radreaste-DECON 1 MUlti-Purpose Facility[

Mutlr-Purpose Facility DEC ON Protected Area Yard (clean structures)

Intake License Termination Survey NRC Review License Terminated 60 yr after shutdown - January 18,.2074 ...... ........

Building demoaitions, backfill and landscaping D emoliton of 010CerStructures Demolition of Turbine. Control &Reactor Elctgs Landscape Site Site Restoration Complete - ictooer 30, 2095 -

TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 4, Page 12 of 22 FIGURE 4.4 2034 DECON ACTIVITY SCHEDULE TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 4, Page 13 of 22 FIGURE 4.4 2034 DECON ACTIVITY SCHEDULE (continued)

DESCRIPTION Y-6 ]Y-2 IY* IY? IYll IY15 IY19 IY23 IY27 IY31 Reactor~ec~

El 9903 Ar.-.-.-...-.-.---..

Areaa 3 i iiiiii!iiiiiiiiiiiiii~iiiiiiiiiiiii -.-.-.-.--.-...-.

Reactor 931 Elevation Reactor El 931 Areal Reactor El 931 Area2 --------

Reactor El 931 Area3 Reactor938Elevation ReactorEl 938Areal ReactorEl 958Area2 ReactoreEl 9031 Neal Reactor El 958 Area3 Reactor BuillOlngDEC09 ""

r.rlne El 903 ,.ea2 ..

TurbineC983 Elevation Tea -DErOuldng Poractoe El 903E Area4 Reac-nte 8 Elevatron Turbirre El 983 Area3 earatoe El 958 Areal Reactore El 958 Area2 Reacste El 958 Area3 urbainaste El 97Aneal Trbinase El903 Nreal Raurbaste El903 Area2 Trabiane82Elev877onel-Trbinte El 903 Area2

,.93 ... -n...

CoTuroln El 832Area3 Tuatroe El 903Area3 RtadwrasteElru934* Dealn RCoentro El Ut8Neng PRoatec ted AEa14 Ae aeraite El 877AreaI c.....n -ar

.. .tr.ct....

ard cnteEl 877Areas TLG Services, Inc.

CooperNuclearStation DocumentN01.1590-002, Rev. 1 Decommissioning Cost Analysis Section 4, Page 14 of 22 FIGURE 4.4 2034 DECON ACTIVITY SCHEDULE (continued)

IFOOPITIfN I 11 -

Dry fuel operations I...........

Fuel storage pool operations Reactor 976 Elevation Reactor El 976 Areal I...........

Reactor El 976 Area2 Reactor 1001 Elevabon Reactor El 1001 Areal Post Fuel DECON Dry fuel operations p

ULcense Terminaton Survey NRC Review Dry fuel operations Building demolitions, backfill and landscaping Demoohton of Other Structures Demolition of Turbine. Control &Reactor Bldg Landscape SOte Period 3: Fuel Storage Operations &Shipping Period 3d GTCC Snipping Period 3e ISFSI Decontamrnaton Period 3 ISFSI Site Pestoration End of ProjectJuly 1, X62 4 TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 4, Page 15 of 22 FIGURE 4.5 2034 Delayed DECON ACTIVITY SCHEDULE r 1

ýy-I IY5 IY9 IY13 JY17 IY21 I Y25 IY29 IY33 i Cooper Nuclear Station 2034 Shutdown

... ----'I Plant Shutdowndanuary 18, 2034 Penod la Shutdown Through Transion Period I0 Limited Decon Activties Period Ic Preparations for SAFSTOR n Pelod 2a SAFSTOR Dormancy/Wet Fuel Peirod 21bSAFSTOR Dormancy/Dry Fuel Period 2c - N ot Used Reactriate Site Date set at 1/18154 Reconftgure plant Site specific decormlssionlng cost estimate submitted Recontfgure plant (continued)

Prepare detailed worli procedures Decon NSSS Preparation for reactor vessel removal Reactor vessel & internals Recirc Pumps &Piping Dryiell (Systems Removal)

TORUS Turbine 932 Elevation Main Turbine/Generator Turbine El 932 Areal Turtine El 932 A/ea2 Turbine El 932 Area3 Turbine 903 Elevation Main Condenser ARW Building Augmented Radwaste El 929 AreaI Augmented Radeaste El 918 AreaI Augmented Paciarste El 903 Areal Augmented Radwaste El 877 Areal Augmented Ractwaste Decon Protected Area Yard (contaminated struc tures)

Drywell Lner Reactor 903 Elevation Reactor El 903 Areal Reactor El 903 Area2 Reactor 859 Elevation Reactor El 859 Area2 TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCostAnalysis Section 4, Page 16 of 22 FIGURE 4.5 2034 Delayed DECON ACTIVITY SCHEDULE (continued)

Pnrtor F! 909 Area I I Reactor El 859 Area3 Reactor El 859 Area4 Reactor El 859 Area5 Reactor 903 Elevation Reactor El 903 Area3 Reactor El 903 Area4 Reactor 931 El evareon Reactor El 931 Area]

Reactor El 931 Area2 Reactor El 931 Area3 Reactor El 931 Area4 Reactor El 931 Area5 Reactor 958 Elevaton Reactor El 958 Areal Reactor El 958 Area2 Reactor El 958 Area3 Reactor 976 Elevation Reactor El 976 Areal Reactor El 976 Area2 Reactor 1001 Elevation Reactor El 1001 Areal Post Fuel DECON Reactor Building DECON Turbine 903 Elevation Turbine El 903 Areal Turbine El 903 Area2 Turbine El 903 ANea3 Turbine El 903 Area4 Tu~rtlne 882 Elevation Turbine El 882 Areal Turbine El 882 Area2 Turbine El 882 Area3 Turbine Bldg - DECON Control Building Control El 932 AreaI Control El 918 Areat Control El 903 Areal Control El 882 Area I RoadwasteBuilding Radwaste El 949 Areal Ractwaste El 934 Area2 Raowaste El 934 Areal Radwaste El 918 Areal TLG Services, Inc.

CooperNuclear Station Document N01-1590-002,Rev. 1 Decommissioning Cost Analysis Section 4, Page 17 of 22 FIGURE 4.5 2034 Delayed DECON ACTIVITY SCHEDULE (continued) iFOCOiDTifltJ T Radwaste El 9IiArea2 Radlwaste El 918 Area3 Radwaste El 903 Area3 Racteaste El 903 Area2 Pa3ctrwasteEl 903 Areal Radwaste El -877 Area1 Padwaste El 877 Area2 Radwaste El 877 Area3 Pactwaste-DE CON Multi-Purpose Building Multi-Purpose Facility Multi-Purpose Facility DECON Protected Area Yard (clean structures)

Intake Ucense Termination Survey NRC Review ucense Terminated Building demolitions, backfill and landscaping Demolition of Oiler Structures Demolition of Turline. Control & PeactOr Slugs Landscape Site Site Restoration Complete - August P. 2069

_____________________________ J____________ - ____________ - ____________

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 4, Page 18 of 22 FIGURE 4.6 2034 SAFSTOR ACTIVITY SCHEDULE

______ V_____________

I11 49 ,

Ii Plant ShutdowneJanuary 18, 2034 Period la Shutdown Through Transicon Period b imited DECON Acdtes Perod Ic Preparations for SAFSTOR

............x........-

Pe0od 2a SAFSTOR Dormancy / Wet Fuel Peirod bSAFSTOR Dormancy/Dry Fuel Perod 2 SAFSTOR Dormancy /No Fuel Reactrvate Site Reconfigure plant Site specific decommissioning cost estimate sucmitted Reconfigure plant (conbnued)

Prepare detailed work procedures Decon NSSS Preparabon tor reactor vessel ren uval Reactor vessel &internals Recire Pumps &Piping Driwell (Systems Remov3l)

TORUS Turbine 932 Elevabon Main Turoine/Generator Turbine El 932 Areal Turbine El 932 Area2 Turbine El 932 Area3 Turbine 903 Elevation Main Condenser ARW Building Augmented Radwaste El 929 Areat Augmented Padwaste El 918 Areal Augmented Racdaste El 903 Areal Augmented Raroaste El 877 Areal Augmented Pacwaste Decon Protected Area Yard (contaminated structures)

,£j it , tl:- ":r:-,r , It'r ------ ------

Drywell Liner Reactor 903 Elevabon Reactor El 903 Areal Reactor El 903 Area&

Reactor 059 Elevation Reactor El 859 Area2 TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 Decommissioning CostAnalysis Section 4, Page19 of 22 FIGURE 4.6 2034 SAFSTOR ACTIVITY SCHEDULE (continued)

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 4, Page20 of 22 FIGURE 4.6 2034 SAFSTOR ACTIVITY SCHEDULE (continued)

DESCRIPTION Y! IY5 I Y9 IY13 IY17 IY21 IY25 1Y29 IY33 IY37 IY41 IY45 IY49 lY53 IY57 IY61 Radwaste El 918 Area2 Padw~aste El 918Ate33 Racwaste El 903 Area3 Raiwaste El 903 Area2 Rad'waste El 903 Areal Radwaste El -877 Areal i . .. .. .

Radwaste El 877 Area2 Rardwaste El 877Area3I-Radwaste-DECON Mult-Purpose Building Mult-Purpose Facility Multi-urpose Faclity DECON Protected Area Yard (clean structures)

Intake License Termllation Survey NPC Review License Terminated 60 yr after shutdown - January 18, i 2094 Buildingdemolitions.

Bo~~ld~~og~

o ,,a molooos*~

,od a,o.

tiacllflll san landscaping

.... 1121

.... iiiiii] ..

Demolition of Other Structures Demolition of Turtine. Control & Reactor Bl.gs Ltnesc ape Stee Site Restoration Comrplete - Octoter 30. 2095 TLG Services, Inc.

0 CooperNuclear Station DocumentN01-1590-002, Rev. I DecommissioningCost Analysis Section 4, Page21 of 22 FIGURE 4.7 DECON TIMELINES SCENARIO 1 1 Shutdown 2014 Y ISFS1with capacity of 50 casks Prompt Decommissioning ISFSI Operational Post - Decomrassionng ISFSI Operations I

2014 Decon Part110Licens ISFSIDemolition

• rt 7* I i*n*

Part 72 License In lb 2a 2b 2c 2e 3b 3c 3d 3e 3f End 18-Jan-14 18-Jan-15 19-Jul-15 27-Jan-17 18-Jul-19 16-Dec-19 15-Sep-20 06-Jun-22 17-Dec-46 31-Dec-46 01-May-47 02-Jul-47 Sub Period Duratin 1.0 0.50 1.5 2.5 0.41 0.75 1.7 24.53 0.04 0.33 0.17 Elapsed Time 1.5 3.0 5.5 5.9 6.7 8.4 32.9 33.0 33.3 33.5 SCENARIO 4

S Shutdown 2034 Prompt Decommissioning ISFSI Operational F Post - Decommissioning ISFSI Operations ISFSI with capacjty of 79 casks T f 2034 Decon iP'aar uLinwn 7 Part 72 License ISFSI Deioittion la lb 2a 2b 2c 2e 3b 3c 3d 30 3f End 18-Jan-34 18-Jan-35 19-Jul-35 27-Jan-37 18-Jul-39 16-Dec-39 15-Sep-40 06-Jun-42 17-Dec-61 31-Dec-61 01-May-62 02-Jul-62 Sub Period Duration 1.0 0.50 1.5 2.5 0.41 0.75 1.7 19.53 0.04 0.33 0.17 Elapsed Time 1.5 3.0 5.5 5.9 6.7 8.4 27.9 28.0 28.3 28.5 TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. I Decomnmissoning Cost Analysis Section 4, Page 22 of 22 FIGURE 4.8 DELAYED DECON and SAFSTOR TIMELINES I

SCENARIO Wet & Dry Fue Doo-acoy ISFSI Ope*..onal Delayed Decomnisng 2

2014 Delayed ISPSIoeth caoy, of 50 canE, iSFSI DeoIo4bo De-o- Part 50 U~oln 1l lb 1C 2a 3a 3b 4a 4b 40 5b End 184Jon-14 18-J-n15 18-Ap-15 18-Jui-t5 18-Jul.19 31-D.,-46 31-Dec-46 31-D.-47 01-Juo48 14-Aul.49 18-Jan-52 20-Ot-52 08-Aug-54 db S0b PenKt DOat 10 025 025 40 2746 100 050 1 12 243 0.75 180 Elapsed T.e. 12 15 55 330 339 34.5 356 380 388 40.6 SCENARIO I

Delayed Demo:nosnlng 3 201 Opetbott0 SF51-- Dottony tSFSIOn8tc~,onty of 500mb. ISFSI Demotbon 2014 Safator P8,150 L.o.nn lb 1C 2a 2b 2c 30 3b 4a 4b 4e 5b End 18-J-n-14 18-Jon-I15 l-_Aor-l5 18-JuO-15 18-Ju-19 31-Dec-46 12-Aprt-8 12-Apr-09 12-Oct-6S 08-Nov-70 19-Apt-73 18-Jan-74 06-Nov-75 Sub Pew Donsod 10 0.25 0.25 40 2746 21 28 1.00 050 107 2.44 0.75 1.80 Elapsed Time 12 1S5 5.5 33.0 54.2 552 557 50.0 59.2 600 61.8 SCENARIO Stloidoon f.p*ast Wet & Dry Fuel Ontn80y 2034 Sal Delayed Deco. -Vnooo 5 f ISFSI Opte~aSorl 2O34 "hfe-Oto9age IOPSI W405 caao~ty of 79 0885.

2034 Dedayed ISFSI D*0-loh De-o, POti 50 Uo.nn 18 lb 1C 28 25 38 3b 48 4b 48 5b End 18-Jan-34 18-Jan-35 18-Apr-35 18-Jui-35 18-Jul_39 31-Dec-61 31-Dec-62 02-J1.-63 14-Aug-,4 1.-Jan-7 21-Oct.67 08-Au-69 Sub P'iod Doa1-on 10 0.25 0.25 4.0 2246 10 0.50 1 12 2.43 0.75 1.80 ElapsedTime 12 15 55 280 290 29.5 306 33.0 33.8 3&6 SCENARIO Delayed Decotmmeconito

,.SF04 capotlyof 79 cas5s ISFSI Demolbon 203458.0 P8,50Ucn 18 1b 10 2b 20 38 3b 4a 4b 40 5b End 18-Jan-34 18-Jar-35 18-Apr-35 18-Jt-35 18-Jul-39 31-Dec-61 12-Aprt-8 12-Apt-8 12-Oct-89 08-No-90 19-Apt-93 18-Ja-94 06-Nov-95 Sub Petiod Durtoon 10 0.25 025 40 2246 2628 1.00 050 107 2.44 0.75 1580 Elapoed Teme 12 15 55 280 542 852 557 568 59.2 60.0 619 TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 5, Page1 of 9

5. RADIOACTIVE WASTES The objectives of the decommissioning process are the removal of all radioactive material from the site that would restrict its future use and the termination of the NRC license. This currently requires the remediation of all radioactive material at the site in excess of applicable legal limits. Under the Atomic Energy Act,[2 91 the NRC is responsible for protecting the public from sources of ionizing radiation. Title 10 of the Code of Federal Regulations delineates the production, utilization, and disposal of radioactive materials and processes. In particular, Part 71 defines radioactive material as it pertains to transportation and Part 61 specifies its disposition.

Most of the materials being transported for controlled burial are categorized as Low Specific Activity (LSA) or Surface Contaminated Object (SCO) materials containing Type A quantities, as defined in 49 CFR Parts 173-178. Shipping containers are required to be Industrial Packages (IP-1, IP-2 or IP-3, as defined in 10 CFR

§173.411). For this study, commercially available steel containers are presumed to be used for the disposal of piping, small components, and concrete. Larger components can serve as their own containers, with proper closure of all openings, access ways, and penetrations.

The volumes of radioactive waste generated during the various decommissioning activities at the site are shown on a line-item basis in Appendices C and D, and summarized in Tables 5.1 through 5.7. The quantified waste volume summaries shown in these tables are consistent with Part 61 classifications. The volumes are calculated based on the exterior dimensions for containerized material and on the displaced volume of components serving as their own waste containers.

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

In calculating disposal costs, the burial fees are applied against the liner volume, as well as the special handling requirements of the payload. Packaging efficiencies are lower for the highly activated materials (greater than Type A quantity waste),

where high concentrations of gamma-emitting radionuclides limit the capacity of the shipping canisters.

No process system containing/handling radioactive substances at shutdown is presumed to meet material release criteria by decay alone (i.e., systems radioactive at shutdown will still be radioactive over the time period during which the decommissioning is accomplished, due to the presence of long-lived radionuclides).

While the dose rates decrease with time, radionuclides such as 13 7Cs will still control the disposition requirements.

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 5, Page2 of 9 The waste material produced in the decontamination and dismantling of the nuclear units is primarily generated during Period 2 of DECON and Period 4 of SAFSTOR. Material that is considered potentially contaminated when removed from the radiological controlled area is sent to processing facilities in Tennessee for conditioning and disposal. Heavily contaminated components and activated materials are routed for controlled disposal. The disposal volumes reported in the tables reflect the savings resulting from reprocessing and recycling.

For purposes of constructing the estimates, the cost for disposal at the EnergySolutions facility was used as a proxy for future disposal facilities. Separate rates were used for containerized waste and large components. Demolition debris including miscellaneous steel, scaffolding, and concrete was disposed of at a bulk rate. The decommissioning waste stream also included resins and dry active waste.

Since EnergySolutions is not currently able to receive the more highly radioactive components generated in the decontamination and dismantling of the reactor, disposal costs for the Class B and C material were based upon the last published rate schedule for non-compact waste for the Barnwell facility (as a proxy).

Additional surcharges were included for activity, dose rate, and/or handling added as appropriate for the particular package.

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 5, Page3 of 9 TABLE 5.1 DECOMMISSIONING WASTE

SUMMARY

Decommissioning Scenario 1 2 3 4 5 6 Waste Waste Waste Waste Waste Waste Class Volume Volume Volume Volume Volume Volume Waste Stream [1] (ft3) (ft3) (ft3) (ft3) (ft3) (ft3)

Low-Level Radioactive A 233,906 207,449 277,370 234,031 199,891 227,217 Waste (near-surface disposal) B 3,877 1,377 1,377 3,647 4,111 1,252 C 976 344 344 1,205 470 470 Fmq m 1. t I I 1- -t 1 FGreater than Class C (geologic repository) GTCC 508 508 508 508 508 508 Processed/Conditioned (off-site recycling center) A 319,826 384,277 384,676 319,826 384,277 384,676 Total [2] 559,092 593,956 614,276 559,217 589,257 614,123

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

[2] Columns may not add due to rounding.

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 5, Page4 of 9 TABLE 5.2 2014 DECON DECOMMISSIONING WASTE

SUMMARY

Waste Volume Mass Waste Cost Basis Class [1] (cubic feet) (pounds)

Low-Level Radioactive EnergySolutions A 233,906 17,533,514 Waste (near-surface disposal) Barnwell B 3,877 505,964 Barnwell C 976 68,415 Greater than Class C Spent Fuel (geologic repository) Equivalent GTCC 508 89,497 Processed/Conditioned Recycling (off-site recycling center) Vendors A 319,826 13,449,330 Total [21 559,092 31,646,720

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

[21 Columns may not add due to rounding.

TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 5, Page5 of 9 TABLE 5.3 2014 Delayed DECON DECOMMISSIONING WASTE

SUMMARY

Waste Volume Mass Waste Cost Basis Class [1] (cubic feet) (pounds)

Low-Level Radioactive EnergySolutions A 207,449 12,564,095 Waste (near-surface disposal) Barnwell B 1,377 166,192 Barnwell C 344 41,290 Greater than Class C Spent Fuel (geologic repository) Equivalent GTCC 508 89,497 Processed/Conditioned Recycling (off-site recycling center) Vendors A 384,277 16,115,520 Total [21 593,956 28,976,594 (Ul Waste is classified according to the requirements as delineated in Title 10 CFR, Part 61.55

['a Columns may not add due to rounding.

0 TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 5, Page6 of 9 TABLE 5.4 2014 SAFSTOR DECOMMISSIONING WASTE

SUMMARY

Waste Volume Mass Waste Cost Basis Class [1] (cubic feet) (pounds)

Low-Level Radioactive EnergySolutions A 227,370 12,678,887 Waste (near-surface disposal) Barnwell B 1,377 166,192 Barnwell C 344 41,290 Greater than Class C Spent Fuel (geologic repository) Equivalent GTCC 508 89,497 Processed/Conditioned Recycling (off-site recycling center) Vendors A 384,676 16,159,800 Total [21 614,276 29,135,666

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

[2] Columns may not add due to rounding.

TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 5, Page 7 of 9 TABLE 5.5 2034 DECON DECOMMISSIONING WASTE

SUMMARY

Waste Volume Mass Waste Cost Basis Class [1] (cubic feet) (pounds)

Low-Level Radioactive EnergySolutions A 234,031 17,535,998 Waste (near-surface disposal) Barnwell B 3,647 477,867 Barnwell C 1,205 96,512 Greater than Class C Spent Fuel (geologic repository) Equivalent GTCC 508 89,497 Processed/Conditioned Recycling (off-site recycling center) Vendors A 319,826 13,449,330 Total [21 559,217 31,649,204

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

[21 Columns may not add due to rounding.

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 5, Page8 of 9 TABLE 5.6 2034 Delayed DECON DECOMMISSIONING WASTE

SUMMARY

Waste Volume Mass Waste Cost Basis Class [1] (cubic feet) (pounds)

Low-Level Radioactive EnergySolutions A 199,891 12,233,558 Waste (near-surface disposal) Barnwell B 4,111 444,306 Barnwell C 470 59,220 Greater than Class C Spent Fuel (geologic repository) Equivalent GTCC 508 89,497 Processed/Conditioned Recycling (off-site recycling center) Vendors A 384,277 16,115,520 Total [2] 589,257 28,942,101

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

[21 Columns may not add due to rounding.

TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 5, Page9 of 9 TABLE 5.7 2034 SAFSTOR DECOMMISSIONING WASTE

SUMMARY

Waste Volume Mass Waste Cost Basis Class [I] (cubic feet) (pounds)

Low-Level Radioactive EnergySolutions A 227,217 12,679,105 Waste (near-surface disposal) Barnwell B 1,252 148,262 Barnwell C 470 59,220 Greater than Class C Spent Fuel (geologic repository) Equivalent GTCC 508 89,497 Processed/Conditioned Recycling (off-site recycling center) Vendors A 384,676 16,159,800 Total [21 614,123 29,135,884

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

[21 Columns may not add due to rounding.

TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 6, Page 1 of 5

6. RESULTS The estimates described in this report are based on numerous fundamental assumptions, including regulatory requirements, project contingencies, low-level radioactive waste disposal practices, high-level radioactive waste management options, and site restoration requirements. The decommissioning scenarios assume continued operation of the station's spent fuel pool for a minimum of 51/2 years following the cessation of operations for continued cooling of the assemblies. An ISFSI will be used to safeguard the spent fuel, once sufficiently cooled, until such time that the DOE can complete the transfer of the assemblies to its repository.

The primary cost contributors, identified in Tables 6.1 and 6.2, are either labor-related or associated with the management and disposition of the radioactive waste.

Program management is the largest single contributor to the overall cost. The magnitude of the expense is a function of both the size of the organization required to manage the decommissioning, as well as the duration of the program. It is assumed, for purposes of this analysis, that NPPD will oversee the decommissioning program, using a DOC to manage the decommissioning labor force and the associated subcontractors. The size and composition of the management organization varies with the decommissioning phase and associated site activities.

However, once the operating license is terminated, the staff is substantially reduced for the conventional demolition and restoration of the site, and the long-term care of the spent fuel (for the DECON alternative).

As described in this report, the spent fuel pool will remain operational for a minimum of 51/2 years following the cessation of operations. The pool will be isolated and an independent spent fuel island created. This will allow decommissioning operations to proceed in and around the pool area. Over the 51/2-year period, the spent fuel will be packaged into transportable canisters for loading into a DOE-provided transport cask. The canisters will be stored in concrete modules at the ISFSI until the DOE is able to receive them. Dry storage of the fuel under a separate license provides additional flexibility in the event the DOE is not able to meet the current timetable for completing the transfer of assemblies to an off-site facility and minimizes the associated caretaking expenses.

The cost for waste disposal includes only those costs associated with the controlled disposition of the low-level radioactive waste generated from decontamination and dismantling activities, including plant equipment and components, structural material, filters, resins and dry-active waste. As described in Section 5, disposition of the low-level radioactive material required controlled disposal is at the EnergySolutions' facility. Highly activated components, requiring additional TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 Decommissioning Cost Analysis Section 6, Page2 of 5 isolation from the environment (GTCC), are packaged for geologic disposal. The cost of geologic disposal is based upon a cost equivalent for spent fuel.

A significant portion of the metallic waste is designated for additional processing and treatment at an off-site facility. Processing reduces the volume of material requiring controlled disposal through such techniques and processes as survey and sorting, decontamination, and volume reduction. The material that cannot be unconditionally released is packaged for controlled disposal at one of the currently operating facilities. The cost identified in the summary tables for processing is all-inclusive, incorporating the ultimate disposition of the material.

Removal costs reflect the labor-intensive nature of the decommissioning process, as well as the management controls required to ensure a safe and successful program.

Decontamination and packaging costs also have a large labor component that is based upon prevailing wages. Non-radiological demolition is a natural extension of the decommissioning process. The methods employed in decontamination and dismantling are generally destructive and indiscriminate in inflicting collateral damage. With a work force mobilized to support decommissioning operations, non-radiological demolition can be an integrated activity and a logical expansion of the work being performed in the process of terminating the operating license. Prompt demolition reduces future liabilities and can be more cost effective than deferral, due to the deterioration of the facilities (and therefore the working conditions) with time.

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

Decontamination is used to reduce the plant's radiation fields and minimize worker exposure. Slightly contaminated material or material located within a contaminated area is sent to an off-site processing center, i.e., this analysis does not assume that contaminated plant components and equipment can be decontaminated for uncontrolled release in-situ. Centralized processing centers have proven to be a more economical means of handling the large volumes of material produced in the dismantling of a nuclear unit.

License termination survey costs are associated with the labor intensive and complex activity of verifying that contamination has been removed from the site to the levels specified by the regulating agency. This process involves a systematic survey of all remaining plant surface areas and surrounding environs, sampling, isotopic analysis, and documentation of the findings. The status of any plant TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 6C,Page3 of 5 components and materials not removed in the decommissioning process will also require confirmation and will add to the expense of surveying the facilities alone.

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

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 Decommissioning CostAnalysis Section 6, Page4 of 5 TABLE 6.1 COST

SUMMARY

2014 Cessation of Operations (thousands of 2008 dollars)

Delayed Cost Element DECON DECON SAFSTOR Decontamination 12,832 18,547 18,399 Removal 73,606 74,005 75,346 Packaging 13,340 9,827 9,577 Transportation 8,571 6,672 6,346 Waste Disposal 75,482 43,839 44,260 Off-site Waste Processing 35,573 42,626 42,743 Program Management [1] 360,232 426,204 490,053 Corporate A&G 15,657 10,100 10,100 Spent Fuel Management [21 77,077 69,839 69,839 Insurance and Regulatory Fees 53,616 62,853 76,914 Energy 6,141 10,408 12,641 Characterization and Licensing Surveys 16,568 16,568 16,568 Miscellaneous Equipment 23,364 31,112 34,923 Total [31 772,058 822,600 907,708 Cost Element License Termination 506,078 475,790 674,963 Spent Fuel Management 231,584 309,463 195,398 Site Restoration 34,396 37,347 37,347 Total [3J 772,058 822,600 907,708

[1] Includes engineering and security costs

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

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

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 6, Page5 of 5 TABLE 6.2 COST

SUMMARY

2034 Cessation of Operations (thousands of 2008 dollars)

Delayed Cost Element DECON DECON SAFSTOR Decontamination 12,832 18,581 18,438 Removal 74,270 74,184 76,329 Packaging 13,342 9,820 9,871 Transportation 8,571 6,704 6,578 Waste Disposal 75,618 46,649 44,999 Off-site Waste Processing 35,573 42,626 42,743 Program Management [R1 340,929 400,786 479,929 Corporate A&G 15,657 10,100 10,100 Spent Fuel Management [21 53,484 47,535 47,535 Insurance and Regulatory Fees 46,578 54,706 72,081 Energy 6,141 9,875 12,641 Characterization and Licensing Surveys 16,568 16,568 16,568 Mfiscellaneous Equipment 23,408 30,280 34,989 Total [31 722,972 768,414 872,803 Cost Element License Termination 506,207 476,185 676,510 Spent Fuel Management 182,368 254,881 158,945 Site Restoration 34,396 37,348 37,348 Total [31 722,972 768,414 872,803

[M1Includes engineering and security costs

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

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

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Section 7, Page1 of 3

7. REFERENCES

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

2. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.159, "Assuring the Availability of Funds for Decommissioning Nuclear Reactors," October 2003

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

4. U.S. Code of Federal Regulations, Title 10, Parts 20 and 50, "Entombment Options for Power Reactors," Advanced Notice of Proposed Rulemaking, Federal Register Volume 66, Number 200, October 16, 2001

5. U.S. Code of Federal Regulations, Title 10, Parts 2, 50 and 51, "Decommissioning of Nuclear Power Reactors," Nuclear Regulatory Commission, Federal Register Volume 61 (p 39278 et seq.), July 29, 1996

6. "Nuclear Waste Policy Act of 1982 and Amendments," U.S. Department of Energy's Office of Civilian Radioactive Management, 1982

7. Testimony of Edward Sproat, Director, Office of Civilian Radioactive Waste Management, before a U.S. House of Representatives subcommittee on the status of Yucca Mountain, July 15, 2008

8. U.S. Code of Federal Regulations, Title 10, Part 50, "Domestic Licensing of Production and Utilization Facilities," Subpart 54 (bb), "Conditions of Licenses"

9. "Low Level Radioactive Waste Policy Act," Public Law 96-573, 1980

10. "Low-Level Radioactive Waste Policy Amendments Act of 1985," Public Law 99-240, 1986

11. Waste is classified in accordance with U.S. Code of Federal Regulations, Title 10, Part 61.55

12. U.S. Code of Federal Regulations, Title 10, Part 20, Subpart E, "Radiological Criteria for License Termination," Federal Register, Volume 62, Number 139 (p 39058 et seq.), July 21, 1997 TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCostAnalysis Section 7, Page 2 of 3

7. REFERENCES (continued)

13. "Establishment of Cleanup Levels for CERCLA Sites with Radioactive Contamination," EPA Memorandum OSWER No. 9200.4-18, August 22, 1997

14. U.S. Code of Federal Regulations, Title 40, Part 141.16, "Maximum contaminant levels for beta particle and photon radioactivity from man-made radionuclides in community water systems"

15. "Memorandum of Understanding Between the Environmental Protection Agency and the Nuclear Regulatory Commission: Consultation and Finality on Decommissioning and Decontamination of Contaminated Sites," OSWER 9295.8-06a, October 9, 2002

16. "Multi-Agency Radiation Survey and Site Investigation Manual (MARSSIM),"

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

17. T.S. LaGuardia et al., "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates," AIF/NESP-036, May 1986

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

Department of Energy, DOE/EV/10128-1, November 1980

19. "Building Construction Cost Data 2008," Robert Snow Means Company, Inc.,

Kingston, Massachusetts

20. Project and Cost Engineers' Handbook, Second Edition, p. 239, American Association of Cost Engineers, Marcel Dekker, Inc., New York, New York, 1984

21. Civilian Radioactive Waste Management System Waste Acceptance System Requirements Document, Revision 5" (DOE/RW-0351) issued May 31, 2007

22. U.S. Department of Transportation, Title 49 of the Code of Federal Regulations, "Transportation," Parts 173 through 178, 2007

23. Tri-State Motor Transit Company, published tariffs, Interstate Commerce Commission (ICC), Docket No. MC-427719 Rules Tariff, March 2004, Radioactive Materials Tariff, February 2006 TLG Services, Inc.

Cooper NuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Section 7, Page3 of 3

7. REFERENCES (continued)

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

25. R.I. Smith, G.J. Konzek, W.E. Kennedy, Jr., "Technology, Safety and Costs of Decommissioning a Reference Pressurized Water Reactor Power Station,"

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

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

27. "Financial Protection Requirements for Permanently Shutdown Nuclear Power Reactors," 10 CFR Parts 50 and 140, Federal Register Notice, Vol. 62, No. 210, October 30, 1997

28. "Microsoft Project Professional 2003," Microsoft Corporation, Redmond, WA.

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

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002,Rev. 1 DecommissioningCost Analysis Appendix A, Page I of 4 APPENDIX A UNIT COST FACTOR DEVELOPMENT TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Appendix A, Page2 of 4 APPENDIX A UNIT COST FACTOR DEVELOPMENT Example: Unit Factor for Removal of Contaminated Heat Exchanger < 3,000 lbs.

1. SCOPE Heat exchangers weighing < 3,000 lbs. will be removed in one piece using a crane or small hoist. They will be disconnected from the inlet and outlet piping. The heat exchanger will be sent to the waste processing area.

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

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

+ Respiratory protection adjustment (25% of critical duration) 64

+ Radiation/ALARA adjustment (14% of critical duration) 35 Adjusted work duration 354

+ Protective clothing adjustment (30% of adjusted duration) 106 Productive work duration 460

+ Work break adjustment (8.33 % of productive duration) 38 Total work duration (minutes) 498

• • • Total duration = 8.30 hr ***

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

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Appendix A, Page3 of 4 APPENDIX A (continued)

3. LABOR REQUIRED Duration Rate Crew Number (hours) ($/hr) Cost Laborers 3.00 8.300 $19.65 $489.29 Craftsmen 2.00 8.300 $44.85 $744.51 Foreman 1.00 8.300 $46.12 $382.80 General Foreman 0.25 8.300 $47.12 $97.77 Fire Watch 0.05 8.300 $19.67 $8.15 Health Physics Technician 1.00 8.300 $43.95 $364.79 Total Labor Cost $2087.31

4. EQUIPMENT & CONSUMABLES COSTS Equipment Costs none Consumables/Materials Costs

-Blotting paper 50 @ $0.45 sq ft (1} $22.50

-Plastic sheets/bags 50 @ $0.13/sq ft {2} $6.50

-Gas torch consumables 1 @ $8.02/hr x 1 hr (3} $8.02 Subtotal cost of equipment and materials $37.02 Overhead & profit on equipment and materials @ 16.00 % $5.74 Total costs, equipment & material $42.76 TOTAL COST:

Removal of contaminated heat exchanger <3000 pounds: $2,130.07 Total labor cost: $2,087.31 Total equipment/material costs: $42.76 Total craft labor man-hours required per unit: 60.59 TLG Services, Inc.

CooperNuclear Station DocumentN01-1590-002, Rev. 1 Decommissioning Cost Analysis Appendix A, Page 4 of 4

5. NOTES AND REFERENCES

• Work difficulty factors were developed in conjunction with the Atomic Industrial Forum's (now NEI) program to standardize nuclear decommissioning cost estimates and are delineated in Volume 1, Chapter 5 of the "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates," AIF/NESP-036, May 1986.

• References for equipment & consumables costs:

1. McMaster-Carr, Item 7193T88, Spill Control

2. R.S. Means (2008) Division 01 56, Section 13.60-0200, page 20

3. R.S. Means (2008) Division 01 54 33, Section 40-6360, Reference-10

" Material and consumable costs were adjusted using the regional indices for Lincoln, Nebraska.

TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 Decommissioning CostAnalysis Appendix B, Page1 of 7 APPENDIX B UNIT COST FACTOR LISTING (DECON: Power Block Structures Only)

TLG Services, Inc.

CooperNuclearStation DocumentN01-1590.002, Rev. 1 DecommissioningCost Analysis Appendix B, Page2 of 7 APPENDIX B DECON UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit($)

Removal of clean instrument and sampling tubing, $/linear foot 0.26 Removal of clean pipe 0.25 to 2 inches diameter, $/linear foot 2.59 Removal of clean pipe >2 to 4 inches diameter, $/linear foot 3.97 Removal of clean pipe >4 to 8 inches diameter, $/linear foot 8.81 Removal of clean pipe >8 to 14 inches diameter, $/linear foot 16.12 Removal of clean pipe >14 to 20 inches diameter, $/linear foot 20.96 Removal of clean pipe >20 to 36 inches diameter, $/linear foot 30.84 Removal of clean pipe >36 inches diameter, $/linear foot 36.64 Removal of clean valve >2 to 4 inches 56.13 Removal of clean valve >4 to 8 inches 88.12 Removal of clean valve >8 to 14 inches 161.25 Removal of clean valve >14 to 20 inches 209.60 Removal of clean valve >20 to 36 inches 308.39 Removal of clean valve >36 inches 366.43 Removal of clean pipe hanger for small bore piping 17.53 Removal of clean pipe hanger for large bore piping 58.45 Removal of clean pump, <300 pound 148.39 Removal of clean pump, 300-1000 pound 437.99 Removal of clean pump, 1000-10,000 pound 1,691.23 Removal of clean pump, >10,000 pound 3,269.60 Removal of clean pump motor, 300-1000 pound 184.32 Removal of clean pump motor, 1000-10,000 pound 704.73 Removal of clean pump motor, >10,000 pound 1,585.64 Removal of clean heat exchanger <3000 pound 908.50 Removal of clean heat exchanger >3000 pound 2,285.25 Removal of clean feedwater heater/deaerator 6,439.66 Removal of clean moisture separator/reheater 13,235.93 Removal of clean tank, <300 gallons 190.93 Removal of clean tank, 300-3000 gallon 602.49 Removal of clean tank, >3000 gallons, $/square foot surface area 5.37 TLG Services, Inc.

CooperNuclear Station . Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Appendix B, Page3 of 7 APPENDIX B DECON UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit($)

Removal of clean electrical equipment, <300 pound 81.09 Removal of clean electrical equipment, 300-1000 pound 300.10 Removal of clean electrical equipment, 1000-10,000 pound 600.21 Removal of clean electrical equipment, >10,000 pound 1,457.82 Removal of clean electrical transformer < 30 tons 1,012.43 Removal of clean electrical transformer > 30 tons 2,915.64 Removal of clean standby diesel generator, <100 kW 1,034.12 Removal of clean standby diesel generator, 100 kW to 1 MW 2,308.21 Removal of clean standby diesel generator, >1 MW 4,778.47 Removal of clean electrical cable tray, $/linear foot 7.57 Removal of clean electrical conduit, $/linear foot 3.31 Removal of clean mechanical equipment, <300 pound 81.09 Removal of clean mechanical equipment, 300-1000 pound 300.10 Removal of clean mechanical equipment, 1000-10,000 pound 600.21 Removal of clean mechanical equipment, >10,000 pound 1,457.82 Removal of clean HVAC equipment, <300 pound 81.09 Removal of clean HVAC equipment, 300-1000 pound 300.10 Removal of clean HVAC equipment, 1000-10,000 pound 600.21 Removal of clean HVAC equipment, >10,000 pound 1,457.82 Removal of clean HVAC ductwork, $/pound 0.28 Removal of contaminated instrument and sampling tubing, $/linear foot 0.74 Removal of contaminated pipe 0.25 to 2 inches diameter, $/linear foot 10.42 Removal of contaminated pipe >2 to 4 inches diameter, $/linear foot 17.53 Removal of contaminated pipe >4 to 8 inches diameter, $/linear foot 30.13 Removal of contaminated pipe >8 to 14 inches diameter, $/linear foot 56.53 Removal of contaminated pipe >14 to 20 inches diameter, $/linear foot 67.65 Removal of contaminated pipe >20 to 36 inches diameter, $/linear foot 92.88 Removal of contaminated pipe >36 inches diameter, $/linear foot 109.76 Removal of contaminated valve >2 to 4 inches 225.71 Removal of contaminated valve >4 to 8 inches 275.44 TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 Decommissioning CostAnalysis Appendix B, Page 4 of 7 APPENDIX B DECON UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor CostlUnit($)

Removal of contaminated valve >8 to 14 inches 531.78 Removal of contaminated valve >14 to 20 inches 675.48 Removal of contaminated valve >20 to 36 inches 895.33 Removal of contaminated valve >36 inches 1,064.12 Removal of contaminated pipe hanger for small bore piping 57.98 Removal of contaminated pipe hanger for large bore piping 175.66 Removal of contaminated pump, <300 pound 474.63 Removal of contaminated pump, 300-1000 pound 1,131.61 Removal of contaminated pump, 1000-10,000 pound 3,609.88 Removal of contaminated pump, >10,000 pound 8,757.44 Removal of contaminated pump motor, 300-1000 pound 494.41 Removal of contaminated pump motor, 1000-10,000 pound 1,474.09 Removal of contaminated pump motor, >10,000 pound 3,326.88 Removal of contaminated heat exchanger <3000 pound 2,130.07 Removal of contaminated heat exchanger >3000 pound 6,206.46 Removal of contaminated feedwater heater/deaerator 15,545.56 Removal of contaminated moisture separator/reheater 33,630.07 Removal of contaminated tank, <300 gallons 790.67 Removal of contaminated tank, >300 gallons, $/square foot 16.09 Removal of contaminated electrical equipment, <300 pound 362.30 Removal of contaminated electrical equipment, 300-1000 pound 899.95 Removal of contaminated electrical equipment, 1000-10,000 pound 1,736.08 Removal of contaminated electrical equipment, >10,000 pound 3,557.00 Removal of contaminated electrical cable tray, $/linear foot 17.95 Removal of contaminated electrical conduit, $/linear foot 8.46 Removal of contaminated mechanical equipment, <300 pound 412.08 Removal of contaminated mechanical equipment, 300-1000 pound 1,027.95 Removal of contaminated mechanical equipment, 1000-10,000 pound 1,985.03 Removal of contaminated mechanical equipment, >10,000 pound 3,557.00 Removal of contaminated HVAC equipment, <300 pound 412.08 TLG Services, Inc.

CooperNuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCostAnalysis Appendix B, Page 5 of 7 APPENDIX B DECON UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit($)

Removal of contaminated HVAC equipment, 300-1000 pound 1,027.95 Removal of contaminated HVAC equipment, 1000-10,000 pound 1,985.03 Removal of contaminated HVAC equipment, >10,000 pound 3,557.00 Removal of contaminated HVAC ductwork, $/pound 1.13 Removal/plasma arc cut of contaminated thin metal components, $/linear in. 1.97 Additional decontamination of surface by washing, $/square foot 3.85 Additional decontamination of surfaces by hydrolasing, $/square foot 21.10 Decontamination rig hook up and flush, $/ 250 foot length 3,504.89 Chemical flush of components/systems, $/gallon 12.58 Removal of clean standard reinforced concrete, $/cubic yard 53.52 Removal of grade slab concrete, $/cubic yard 60.83 Removal of clean concrete floors, $/cubic yard 254.88 Removal of sections of clean concrete floors, $/cubic yard 751.47 Removal of clean heavily rein concrete w/#9 rebar, $/cubic yard 77.08 Removal of contaminated heavily rein concrete w/#9 rebar, $/cubic yard 1,154.71 Removal of clean heavily rein concrete w/#18 rebar, $/cubic yard 104.43 Removal of contaminated heavily rein concrete w/#18 rebar, $/cubic yard 1,523.99 Removal heavily rein concrete w/#18 rebar & steel embedments, $/cubic yard 327.04 Removal of below-grade suspended floors, $/cubic yard 146.31 Removal of clean monolithic concrete structures, $/cubic yard 626.97 Removal of contaminated monolithic concrete structures, $/cubic yard 1,150.82 Removal of clean foundation concrete, $/cubic yard 493.01 Removal of contaminated foundation concrete, $/cubic yard 1,071.14 Explosive demolition of bulk concrete, $/cubic yard 22.86 Removal of clean hollow masonry block wall, $/cubic yard 56.99 Removal of contaminated hollow masonry block wall, $/cubic yard 159.69 Removal of clean solid masonry block wall, $/cubic yard 56.99 Removal of contaminated solid masonry block wall, $/cubic yard 159.69 Backfill of below-grade voids, $/cubic yard 21.24 Removal of subterranean tunnels/voids, $/linear foot 73.39 TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Appendix B, Page6 of 7 APPENDIX B DECON UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit($)

Placement of concrete for below-grade voids, $/cubic yard 112.21 Excavation of clean material, $/cubic yard 2.30 Excavation of contaminated material, $/cubic yard 24.06 Removal of clean concrete rubble (tipping fee included), $/cubic yard 174.10 Removal of contaminated concrete rubble, $/cubic yard 16.10 Removal of building by volume, $/cubic foot 0.23 Removal of clean building metal siding, $/square foot 0.60 Removal of contaminated building metal siding, $/square foot 1.87 Removal of standard asphalt roofing, $/square foot 1.23 Removal of transite panels, $/square foot 1.45 Scarifying contaminated concrete surfaces (drill & spall), $/square foot 8.02 Scabbling contaminated concrete floors, $/square foot 4.06 Scabbling contaminated concrete walls, $/square foot 10.43 Scabbling contaminated ceilings, $/square foot 35.09 Scabbling structural steel, $/square foot 3.70 Removal of clean overhead crane/monorail < 10 ton capacity 449.46 Removal of contaminated overhead crane/monorail < 10 ton capacity 1,017.50 Removal of clean overhead crane/monorail >10-50 ton capacity 1,078.74 Removal of contaminated overhead crane/monorail >10-50 ton capacity 2,442.15 Removal of polar crane > 50 ton capacity 4,565.92 Removal of gantry crane > 50 ton capacity 18,222.75 Removal of structural steel, $/pound 0.15 Removal of clean steel floor grating, $/square foot 3.51 Removal of contaminated steel floor grating, $/square foot 7.70 Removal of clean free standing steel liner, $/square foot 8.05 Removal of contaminated free standing steel liner, $/square foot 18.86 Removal of clean concrete-anchored steel liner, $/square foot 4.02 Removal of contaminated concrete-anchored steel liner, $/square foot 21.87 Placement of scaffolding in clean areas, $/square foot 11.97 Placement of scaffolding in contaminated areas, $/square foot 16.37 TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Appendix B, Page 7 of 7 APPENDIX B DECON UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor CostlUnit($)

Landscaping with topsoil, $/acre 19,274.92 Cost of CPC B-88 LSA box & preparation for use 1,407.31 Cost of CPC B-25 LSA box & preparation for use 1,235.45 Cost of CPC B-12V 12 gauge LSA box & preparation for use 1,209.41 Cost of CPC B-144 LSA box & preparation for use 7,583.15 Cost of LSA drum & preparation for use 102.27 Cost of cask liner for CNSI 14 195 cask 106.24 Cost of cask liner for CNSI 8 120A cask (resins) 5,700.21 Cost of cask liner for CNSI 8 120A cask (filters) 581.58 Decontamination of surfaces with vacuuming, $/square foot 0.41 TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Appendix C, Page 1 of 35 APPENDIX C DETAILED COST ANALYSES 2014 CESSATION OF OPERATIONS T able C -1, D E C O N ............................................................................................... C -2 Table C-2, Delayed DECON ............................................................................... C-13 T able C -3, SA FSTO R .......................................................................................... C -24 TLG Services, Inc.

Cooper NuclearStation Document N01.1590-002, Rev. I Appendix C, Page 2 of 35 DecamnmieaioningCost Analysis Table C-i Cooper Nuclear Station 2014 DECON Decommissioning Cost Estimate (thousands of 2008 dollars) off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and

- Devon Removal Packaging Transport Processing Disposal Other Total Total Lit. Term. Managenment Restoraton Volume Clans A Class B ClassC GTCC Processed Craft Contractor A-c-nty Cst cost Costs Costs Costs Costs Csts Colnuoun,, Costs Costs Cots Costs Cu. Feet Cu. Feet Cu. Feet Cu. Fet Cu. Faet WL. Lbs. Manhours Manhourst ex A. v 0I n PERIOD Is - Shutdown through Transition Period 1a Direct Decommissioning Activites 1:.1.1 Prepare preliminary decommissioning cost 130 20 150 150 1,300 I 1.2

, Notificationof Cessation of Operations l.1 .3 Remove ue & source material rd.8 Ia.1.4 Notification of Permanent Defueling la.1.5 Deactivate plant systems &process waste la.1.6 Prepare and submit PSDAR 200 30 230 230 2.000 4600 69 529 529 4,600 la.1.7 Review plant dwgs &specs.

10.,1.8 Perform detailed red survey 100 15 115 115 1,000 10.1.9 Estimate by-product inventory 100 15 115 115 1,000 1:.1.10 End product description 130 20 150 150 1,300 I0.1,11 Detailed by-productinventory 750 113 863 863 7.500 la.1.12 Define major work sequence 310 47 357 357 3.100 10.1.13 Perform SER and EA 75 575 575 5,000 l.1e--14. Perform Site-Specitic Cost Study 500 410 61 471 471 4.096 1a.1.15 Prepare/submit License Termination Plan la.1.16 Receive NRC approval of termnnation plan a Activty Specifcations 492 74 566 509 57 4.920 la.1.17.t Plant & tenporary facilities 4,167 Ia.1.17.2 Plart systems 417 63 479 431 48 50 8 58 58 500 la.1.17.3 NSSS Decontamination Flush 710 107 517 817 7,100 la.1.17.4 Reactor ieamte 6,500 la.1.17.5 Reactr essel 650 98 748 748 5D 8 58 58 5oo 10.1.17.6 Sacrificial shield 100 15 115 115 1,000

1. 1.17.7 Moisture soparatoesnrheaters 160 24 184 92 92 1,600 1a.1.17,8 Reinforced concrete 209 31 240 240 2,088 1a.1.17.9 Main Turline 209 31 240 240 2,088 la.1.17.10 Main Condensers 2,000 la.1.17.11 Pressure suppression structure 200 30 230 230 160 24 184 184 1,600 la.1.17.12 Drpwell 312 47 359 179 179 3,120 Ia.1.1713 Plantstructures &buildings 460 69 529 529 4.600 la.1.17.14 Waste managernt 90 14 104 52 52 900 1a.1.17.15 Facility& site doseaout 4.268 640 4,909 4.481 428 42.683 1a.1.17 Total PlRnning& Site Preparations 240 36 276 276 2,400 la 1.18 Prepare dimantling seqience 1l.1.19 Plant prep. &temp. svtes Z,700 405 3,105 3,105 140 21 161 161 1.400 1a.1.20 Desig watermdeanup system 1.1.21 RiggiugfCord. Cntd Envlpsntoofingletc. 2,100 315 2,415 2.415 123 18 141 141 1.230 la.1.22 Procure casksilinens &containers 12.661 1,899 14.560 14,132 428 78.609 la.1 Subtotal Period la Actirty Cots Period la Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 10,335 1,550 11.886 11,888 1a.3.2 Corporate Overheads 3,105 468 3,570 3,570 2,016 15,458 3,570 11,888 10.3 Subtotal Period la Collateral Costs 13.440 Period 10 Period-Dependent Costs 18.4.1 Insurance 1,600 160 1,760 1,760 1.4.2 Property taxes 4 0 4 4 la.4.3 Health jorysics supplies 370 93 463 463 10.4A Heavy equiplent rental 368 55 423 423 TLG Services, Inc.

Cooper Nuclear Station DocumentN01-1590-002, Rev. I DecoomissioningCodt Analysis Appendix C, Page 3 of 35 Table C-1 Cooper Nuclear Station 2014 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sit. LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utiity and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic.Term. Management Restoration Volume Clans A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contllnency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet - Wt. Lbs. Manhours Manhours Period la Period-Dependert Costs (continued) 1a.4.5 Disposal of DAWgenerated 73 19 100 100 1,575 14,445 la.4.6 Plant energy budget 927 139 1,066 1,066 la.4.7 NRC Fees 706 71 776 776 1a.4.8 Emergency Planning Fees 1-185 118 1.303 1,303 1a.4.9 Spent Fuel Pool O&M 745 112 857 857 la.4.10 ISFSI Operating Costs 85 13 88 98 la.4.11 Secuity Staff Cost 5,483 822 6,306 6,306 157,471 la.4.12 UtilityStaff Cost 22.690 3.403 26.093 260.03 423,400 la.4 Subtotal Period la Period-Oependemt Costs 738 5 3 73 33.424 5,006 39,249 30,991 2.258 1,575 14,445 5 580,871 1a.0 TOTAL PERIOD la COST 738 5 3 73 59,525 8.921 69,265 54,693 14,144 428 1,575 14,445 5 659.480 PERIOD lb - Decommissioning Preparations Period 1b Direct Decommissioning Activities Detailed Wor Procedures lb.1.1.1 Plant systems 473 71 544 490 54 4,733 lb.1.1,2 NSSS Decontamiation Flush 100 15 115 115 1,000 lb.1.1.3 Reactor intemals 400 s0 460 460 4,000 It.1.1.4 Remaining buildings 135 20 155 39 116 1,350 lb.1.1.5 CRDhousings &Nts 100 15 115 115 '1.000 10.1.1.6 Inore instrumaentation 100 15 115 115 1,000 1b.1.1.7 Removal primnarycontainment 200 30 230 230 2,000 1b.1.1.8 Reactor yessel 363 54 417 417 3,630 1b.1.1.6 Facility closeout 120 18 138 69 69 1.200 1b.1.1.10 Sacrificial shield 120 18 138 138 1,200 1b.1.1.11 Reinforced conete 100 15 115 so 58 1,000 1b.1.1.12 Man Turbine 208 31 239 239 2,080 lb.1.1.13 Main Condensers 209 31 240 240 z088 1b.1.1.14 Moisture separators &reheaters 200 30 230 230 2.000 1b.1.1.15 Raortasta building 273 41 314 283 31 2,730 lb.1.1.16 Reactor building 273 41 314 283 31 2,730 1b.1.1 Total 3,374 506 3,880 3,520 300 - 33,741 Ib.1.2 Decon NSSS 348 174 523 523 1.067 I1b.1 Subtotal Period lb AcxtvityCosts 348 3,374 680 4.403 4,043 360 1,067 33,741 Period b Addriional Costs 1b.2.1 Spent Fuel Pool Isolation 9.407 1.411 10,818 10.818 I b.2.2 Site Charcterization - 5,395 1,619 7.014 7,014 1b.2.3 Asbestos Insulation Disposal 773 1 65 558 - 265 1,662 1.662 10,333 134.329 10,002 lb.2 Subtotal Period lb Additional Costs 773 1 65 558 14,802 3,295 19,493 19,493 10,333 134.329 10,002 Period lb Collateral Costs lb.3.1 Decon equipment 713 107 820 820 lb.3.2 DOC staff relocation expenses 912 137 1,049 1,049 1b.3.3 Process liquid waste 64 - 48 249 1,800 525 2,690 2,690 427 543 85.905 189 1b.3.4 Small tool allouwance "11 2 12 12 lb.3.5 Pipe cutting equipment - 1,000 150 1,150 1,150 lb,3.6 Decon rig 1,400 210 1,610 1,610 1b.3.7 Spent Fuel Capital and Transfer 3,054 458 3,512 - 3,512 1b.3.*8 Corporate Overheads - 1,554 233 1,787 1,787 249 1,806 5,520 1,822 12,631 9,118 3,512 427 543 85,905 186 1b.3 Subtotal Period lb Collateral Costs 2,177 1.011 48 TLG Services, Inc.

0 Cooper NuclearStation Document N01-1590-002, Rev. I DeconmirsioningCost Analysis Appendix C,Page 4 of85 Table C-1 Cooper Nuclear Station 2014 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utility and Activty Decon Removal Packaging Transport Processing Disposal Other Total Total LiU.Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Continaency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Foot Cu. Foot Wt. Lbs. Manhours Manhours Period l b Period-Dependmnt Costs 1b.4.1 Decon supplies 22 4 5 27 27 1b.4.2 Insurance 244 24 269 269 lb.4.3 Properlty taxes 2 0 2 2 lb.4. Health physics supplies

• 242 60 302 302 Ib.4.5 Heavy equipment rental 183 27 211 211 Disposal of DAW generated 3 2 43 11 58 58 920 8.439 3 Ib.4.6 ib.4.7 Plant energy budget 924 139 1,063 1,063 Ib.4.8 NRC Fees 352 35 387 387 lb.4.9 Emergency Planning Fees 591 59 650 650 1b.4.10 Spent Fuel Pool O&M 372 56 427 427 lb.4.1 ISFSI Operating Costs 42 6 49 49 Ib.4.12 Security Staff Cost Z734 410 3,144 3,144 78,520 Ib.4.13 DOC Staff Cost 4,759 714 5,473 5,473 83.440 Ib.4.14 UitiityStaff Cost S 11,380 1.707 13,086 13,086 212,160 Sb.4 Subtotal Period 1b Penod-Dependent Costs 22 425 3 2 43 21,400 3,255 25,149 24,023 1,126 920 8,439 3 354,120 1b.0 TOTAL PERIOD 1b COST 2,547 2,209 49 316 2,407 45,096 9,052 61,676 56,677 4,638 360 11,680 543 228,674 11,261 387,861 PERIOD I TOTALS 2.547 2.947 54 318 2.480 104,622 17,973 130,940 111,370 18.782 788 13,255 543 243,119 11265 1,047.341 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Actvities Nucear Steam Supply System Removal 2a.1.1.1 Reciclation System Piping &Valves 90 71 14 20 303 142 639 639 997 120,597 4,031 20.1.1.2 Recircudation Pumps & Motom 33 28 11 29 321 109 532 532 1.188 132,888 1,683 2 .1.1.3 CRDMs & NIs Removal 133 139 377 92 317 232 1,291 1,291 6,935 - 126,494 0,209 2L.1.1.4 Reactor Vessel Internals 110 2,382 5,343 2,09 16,355 218 11,879 30,285 38,285 1,878 1,205 676 376,084 28,075 1,255 2a.1.1.5 Reactor Vessel 56 5,457 1,460 762 5,358 218 7,388 20,700 20,700 11,211 2.128 - 1,440,354 28,075 1,255 20.1.1 Totals 431 8,058 7,205 2,912 22.653 437 19.751 61,447 61,447 22,209 3,334 976 2.196,409 68,073 2,510 Removal of Major Equipment 2a.1.2 Main Turtine/Generator 171 028 379 6,057 309 1,188 0,011 9,011 08,524 1,725 2,788,381 4,555 2a.1.3 Main Condensers 722 552 273 3,773 812 1,045 7,177 7.177 36,456 3,604 1,63.840 19,066 Cascading Costs from Clean Building Demolition 2a.1A.1 Reactor 260 39 299 299 2,488 25 4 28 28 235 2a.1 .4.2 Augmented Radwaste 2a.1A.3 Radsoste 43 7 50 50 359 20.1.4. Turbineto 285 43 328 328 4,419 2a.l.4 Totals 613 92 705 705 7,498 Disposal of Plant Systems 2a.1.5.1 Augmented Radwrste El 877 ArealA 207 28 28 432 167 862 062 2,055 172,205 5,783 2a.1 5.2 Augmented Redwaste a 903 ArealA 68 6 7 104 45 230 230 460 41,606 1,889 2a.1.5.3 Augmented Redwaste 918 al AralA 53 10 9 139 50 261 261 765 55.345 1,451 2a.1.5.4 Augmented Radwaste El 929 AmalA 21 4 5 73 25 128 128 324 29,038 591 2a.1.5.5 Augmented Redwaste El 929 AreaoB 3 0 0 3 0 1 8 8 38 1 1,538 77 28.1.5.0 DRYVVELLArealA 534 85 84 1.289 477 2,470 2,470 5,726 513,627 15,069 28.1.5.7 DRYWVELL AealB 134 3 5 54 28 50 274 274 577 126 34,718 4,142 2a.1.5.8 Muib-Purpose Facility 202 6 15 201 47 95 566 560 2,148 214 105,982 5,547 29.1.5.9 Reactor El 903 AJOelA 404 56 42 - 651 276 1,428 1,428 2,892 259,190 10,573 2a.1.5.10 Reactor a 903 ArealB 462 13 34 443 131 221 1.305 1,305 4,739 583 244,706 12,864 20.1.5.11 Turbine El 032 ArealB 332 52 99 882 725 416 2.505 2.505 9,442 3,220 672,225 9,481 8 1 9 0 237 2a.5.5.t2 Turbine El 932 Aea2C TLG Servcees, Inc.

Cooper Nuclear Stoaton Document N01-1590-002, Rev. I Decommissioning Cost Aoodyaie Appendix C, Page 5 of 35 Table C-1 Cooper Nuclear Station 2014 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sit. LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Continenc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt, Lbs. Manhours Manhours Disposal of Plast Systems (coninued) 2a.1.5,13 Turbine El 932 Area3C 67 . . . . 10 78 78 - - - 2.083 2a.1.5.14 YardAfealB 518 110 284 3.535 1.198 1,013 6,657 6,657 37,846 5,399 2,014,081 14.477 2a.1.5 Totals 3,013 374 612 5,117 4,817 2.847 16.780 16,693 87 54.788 21,774 4,144.259 84,262 2a. 1.6 Scaffolding in support of decommissioning 2,070 24 11 168 23 553 2,848 2,848 1,621 101 81,992 28.092 2a.1 Subtotal Penod 2a ActivityCosts 431 14,647 8,983 4,188 15,116 28.694 437 25,476 97,968 97,881 87 151,388 49.413 3,334 976 11,174,880 212,445 2.510 Period 2a Collateral Costs 2a.3.1 Process liquid waste 135 - 44 231 264 173 847 847 - - 921 55,244 185 -

2a.3,2 Small tool allowance 124 19 143 129 14 2a.3.3 Spent Fuel Copital and Transfer 8.576 1,286 9,862 - 9,862 2a.3.4 Crporate Overheads - 3.202 480 3,682 3,682 2a.3 Subtotal Period 2a Collateral Costs 135 124 44 231 264 11,778 1,.58 14,534 4,657 ,9982 14 621 55.244 180 Period 2a Perieo-Dependent Costs 2a.4.1 Decce supplies 81 15 78 76 2a.4.2 Insurance 688 69 756 756 2a.4.3 Property taxes 6 1 6 6 2a.4.4 Health physics supplies 1.262 315 1,577 1,577 20.4.5 Heavy equipment rental 2,480 372 2,852 2,852 2a.4.6 Disposal of DAWgenerated 34 19 537 - 140 730 730 11,545 105,898 35 2a.4.7 Plant energy budget - 1,235 185 1,420 1,420 2a,4.8 NRC Fees 923 92 1,016 1.016 2a.4.9 Emergency Planning Fees 1,183 118 1,301 1,301 2a.4.10 Spent Fuel Pool O&M 1.046 157 1,203 1,203 2e.4.11 ISFS0Operating Costs 119 18 137 - 137 2a,4.12 Security Staff Cost 6,631 995 7,626 7,626 185.051 2a.4.13 DOC Staff Cost 16,275 2,441 18,718 18.716 222,354 2a.4.14 UtilityStaff Cost 22,962 3,444 26,407 26,407 413,989 2a.4 Subtotal Period 2a Pedod.Dependent Costs 61 3,741 34 19 537 51,067 8,363 63,822 61,182 2,640 1 11,545 - 105.898 35 821,394 2a.0 TOTALPERIOD 2a COST 627 18,513 9,060 4,437 15,116 29,494 63.282 35,797 176,325 163,720 12,503 102 151,388 61,878 3.334 976 11,336.020 212,660 823,904 PERIOD 2b - Site Decontamination Period 2b Direct Decommissioning Activities Disposal of Ptant Systems 2b.1.1.1 Control El 882 Arealt 285 17 42 554 147 199 1,243 1,243 - 5,929 674 299,222 7,975 2b.1.1.2 Control El 903 AreatC 170 25 185 195 - - 5,155 2b.t1..3 Control Ei 918 ArealC 66 10 76 76 2,100 2b.1.1.4 Control El 932 AmealC 22 3 26 26 702 101 15 116 116 - 3,136 2b.1.1.5 Intake 18Radwraste Cl877 ArealA 2b.1.t.6 405 75 62 948 355 1,845 1,845 5,097 377,917 11.133 2b.1.t.7 Raoteaste 8877 Area2A 44 9 7 113 41 214 214 613 44,992 1,207 2b 1.1.8 Radwaste El 877 Area3A 84 16 13 201 75 388 308 1.156 79,963 2,349 2b.1.1.9 Radsaste 8 903 AnalA 113 9 10 153 69 355 355 684 81,153 3,102 2b.1.1.10 Radastes 8 9D3 Arsa2A 192 36 29 439 166 961 891 1.955 175.093 5,412 2b.1..t11 Radwaste E 903 Area3A 37 6 7 104 37 191 191 463 41,366 1,047 2b.1.1.12 Radwasts [ 9168AalA 21 2 2 30 13 68 68 135 12,033 572 2b.1.t.13 Radwast= C 918 Amea2A 17 3 3 39 15 76 76 201 15,667 455 2b.1.1.14 Radwasta 8916Atea3A 188 23 22 338 137 710 710 1,690 134,827 5,152 2b.1.1.15 Rafsts El 934 AreaeA 26 3 4 60 22 11t 115 266 23,735 692 2b.1.1.16 Radwaste  : E934 Area2A 100 11 12 177 72 372 372 808 70,665 2.706 2b.1.1.17 Radwasta ]S49ArealA 12 1 2 24 9 47 47 105 9,381 310 TLG Services, Inc.

Cooper Nuaclar Station Docoarars NOI.-1590.002, Rev. I Decoamss~aioning CoatAnalsayis Appendix C, Page6 ef 85 Table C-1 Cooper Nuclear Station 2014 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utilityand Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie.Term. Management Restoration Volume ClansA Class B Class C GTCC Processed Craft Contractor Inde. Activity Oscription Cost Cost Costs Costs Costs Costs Costs Contiagenco Costs Costs Costs Costs Cu. Feet Cu. Feet Ce. Cu.Fon Cu. Font CFot Wt. Lbs. Manhours Manhouns Disposal of Rant Systems (continued) 2b.1.1.18 Reactor El 859 AralA 72 15 16 - 248 83 432 432 1,091 97,874 2,068 344 317 1.914 1,914 7,624 1.526 448,483 12,746 2b.1.1.19 Reactor Elt59 ArealB 449 28 64 712 2b.1.1.20 Reactor El 859 Area2A 73 25 26 401 125 650 650 - 1,780 159,714 2,137 2b 1.1.21 Reactor El 859 Area2B 70 3 8 99 40 44 264 264 1,055 177 58.760 2.009 2b.1.1.22 Reactor El 859 Ara3A 48 9 9 137 49 252 252 6O8 54,543 1,356 34 2 3 23 23 18 103 103 249 103 19,362 975 2b.1.1.23 Reactor El 859 Area3B 51 9 8 117 44 229 229 - 520 46,666 1,416 2b.1.1.24 Reactor El 859 Area4A 17 1 2 19 14 11 65 65 208 62 14,010 487 2b.1.1.25 Reactor El 659 Area4B 262 86 445 445 1,163 104,381 1,839 2b,1.1.26 Reactor El 859 Are"SA 64 16 17 2b.1.1.27 Reactor El 859 AraSB 38 2 3 23 23 19 107 107 242 102 18,927 1,114 4 0 0 8 3 14 14 26 2,372 123 2b.1.1.28 Reactor El 903 Area2A 71 5 12 149 51 55 342 342 1,594 225 84,943 1,983 2b.1.1.29 Reactor EJ903 Area2B 2b.1.1.30 Reactor C 903 Area3A 37 10 11 - 167 54 279 279 - 741 68,516 1,109 2b.1.1.31 ReactorEl 903 Area3B 25 2 3 37 17 17 101 101 401 77 23,200 744 2b.1.1.32 Reactor El 903 Area4A 31 8 9 136 44 229 229 608 54,373 928 2b.1.1.33 Reactor EJ903 Area4B 24 1 3 38 17 17 101 101 411 75 23,408 717 25 3 3 - 52 20 104 104 - 232 20.858 681 2b.1.1.34 Reactor El 931 ArealA 2b.1.1.35 Reactor El 931 Areal B 307 22 45 483 256 222 1,334 1,334 5,169 1,137 311.878 8,640 31 2 2 - 35 17 87 87 154 13,824 881 2b.1.1.36 Reactor Ei931 Area2A 2b.1.1.37 Reactor EC931 Aroe2B 3 0 0 1 0 1 5 5 7 1 380 91 123 23 22 336 120 625 625 1.651 134,007 3,509 2b.1.1.38 Reactor E 931 Area3A 2b.1.1.39 ReactworE 931 Area3B 3 0 0 1 0 1 4 4 7 0 345 85 2b.1.1.40 Reactor EJ931 Area4C 24 4 28 28 767 1 8 - 8 - 213 2b.1.1.41 ReactorEl 931 AreaSC 7 2b.1.1.42 Reactor El 958 ArealA 57 9 10 149 54 279 279 - 662 59,432 1,492 18 209 88 100 594 594 2,238 392 128,002 4,814 2b.1.1.43 Reactor El 958 ArealB 171 8 10 10 - 153 53 276 276 - 681 61,083 1.425 2b.1.1.44 Reactor El 958 Ar-a2A 49 15 1 1 6 14 8 46 46 66 63 8,331 430 2b.1.1.45 Reactor EJ 558Area2B 4 3 - 48 22 116 116 - 214 19,185 1,070 2b.1.1.48 ReactorB 958 Area3A 38 17 1 1 6 12 8 45 45 60 54 7.250 491 2b.1.1.47 Reactor El 958 AreM33

- 50 23 117 117 - 222 19,878 1,028 2b.1.1.48 Turbine El 882 AalA 38 3 3 46 95 1,101 476 402 2.515 2,515 11,784 2,117 868.352 11.459 2b.1.1.49 Turbine El 882 AralB 394 2b.1.1.50 Turbine El 882 Area2A 22 2 2 29 13 68 68 - 129 11,556 597 10 23 301 89 125 762 762 3,227 405 166,542 5,929 2b51.1.51 Turbine C 882 Area2B 213 2 1 - 23 10 53 53 - 101 9.017 461 2b.1.1.52 Turbine El 882 Ares3A 17 633 637 4,068 4,068 20,984 2,817 1.104.460 17,788 2b.1.1.53 Turaln El 882 Area3B 820 82 156 1.960 15 6 33 33 - 68 6.127 239 2b.1.1.54 Turbine E8 903 ArealA 9 I 1 -

134 271 2.726 1.717 1,141 6,983 6,983 29,180 7.631 1,868,932 28,509 2b.1.1.55 Turbine El 903 Areal B 995 5 4 20 20 - 42 3,729 145 2b.1.1.56 Turbine El 903 Area2A 1 1 - 9 3 a 105 30 62 355 355 1,122 133 57,476 4,141 2".1.1.57 Turbine El 903 Area2B 147 3 0 2 33 2 7 48 48 357 9 15,340 97 2.1.1.1.58 Turbine EC903 Area3B 16 124 124 - 3,412 2b.1.1.59 Turbine 5 903 Aea3C 108 2b.1.1.60 Turbine El 903 Ama4B 12 0 2 26 3 8 50 50 276 11 12,251 367 2b.1.1.81 YardAVatIC 197 30 227 227 - 5,770 21.1.1 Totals 6,646 693 1,087 8,611 8,996 8,365 31,398 30,598 80 92,188 41,682 7.327,776 189,487 2b.1.2 Scaffolding in support of decommissioning 2,588 30 14 210 28 691 3.560 3,560 2,026 126 102,490 35.115 Decontamination ofSe Buildings 2b.1.3.1 Reactor 2,702 1,457 131 320 4,748 1,116 2,767 13.241 13,241 50,830 16.343 3,680,298 101.984 32 7 10 23 119 71 316 316 242 2.189 228,383 2,299 28,1.3.2 Augmented Radwaste 55 377 174 15 43 759 74 372 1,815 1,815 8,129 679 395,527 13,327 2b.,1.3.3 Miscellaneous Structures - Contaminated 2b.1.3.4 Mueti-urpose Facility 72 73 11 19 115 172 118 579 579 1,234 3,087 356.985 3.680 167 88 18 26 38 319 196 850 850 404 5,888 603,975 6.839 2b.1,3.5 Radvaste 2b.1.3.6 Turbine 552 267 70 97 64 1,261 689 3,001 3,001 688 23.302 2,357,288 21,920 2b,1.3 Totals 3,924 2.088 252 515 5,747 3,061 4C214 19,801 19,80t 61,526 51,485 7,*22,455 150,050 TLG Services, Inc.

Cooper Nuclear Station DocumentN01.1590.002, Rev. I De-omrissioning Cost Analysis Appendix C, Page 7 of 35 Table C-1 Cooper Nuclear Station 2014 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volures Burial I Utility and Activity Oe0n Removal Packaging Transport Processing Disposal Other Total Total LIc. Term. Management Restoration Volume Clans A Class B Clans C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Coste Costs C Cost Csts Contin en Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu.Feet Cu. Feet WL. Lbs. Manhours Manhours 2b.1 Subtotal Pedod 2b Actvity Costs 3,924 11,322 975 1.616 14.567 12,086 - 10,269 54,759 53,960 - 800 155.741 93,273 - - 15,052,720 374.651 -

Period 2b Collateral Costs 2b.3.1 Process liquid waste 164 - 54 283 323 211 1.035 1,035 1,126 67,588 220 2b.3.2 Small tool allowance - 195 - 29 225 225 2b.3.3 Spent Fuel Capital and Transfer - - 17.873 2,681 20.554 - 20,554 2b.3A Corporate Overheads . . . 5,754 863 6,618 6,618 2b.3 Subtotal Period 2b Collateral Costs 164 195 54 283 323 23,627 3.784 28,431 7,877 20.554 1,126 87,588 220 Period 2b Period-Dependent Costs 2b.4.1 Decon supplies 1,318 - - 330 1,648 1,648 2b.4.2 Insurance 1,273 127 1,400 1,400 2b94.3 Property taxes 10 1 11 11 2b.4.4 Health physics supplies 2.257 - 564 2,822 2,822 2b.4.5 Heavy equipment rental 4,559 - 684 5,243 5,243 2b.48 Disposal of DAWgenerated - 53 29 835 - 218 1,135 1,135 17,954 164,691 55 2b.4.7 Plant energy budget - 1.805 271 2,076 2,076 2b.48 NRC Fees 1,709 171 1,880 1,880 2b.4.9 Emergency Planning Fees 2,190 219 2,409 2,409 2b.4.10 Spent Fuel Pool O&M 1,939 290 2,227 - 2,227 2b.4.1 1 Liquid Radwaste Processing EquipmentlServices 487 73 560 560 2b.4.12 ISFSI Operating Costs 220 33 254 - 254 2b.4.13 Security Staff Cost 12,279 1,842 14,120 14,120 342.634 2b.4.14 DOC Staff Cost 29.008 4,351 33,359 33,359 395,451 2b.4.15 UtilityStaff Cost 40,864 8,130 46,993 46.993 734,023 2b.4 Subtotal Petiod 2b Period-Dependent Costs 1,318 6.816 53 29 835 91,781 15,304 116,137 111,248 4,889 17,954 164,691 55 1,472,109 2b.0 TOTAL PERIOD 2b COST 5,407 18,334 1,081 1,928 14,567 13,243 115,409 29,358 199,327 173,085 25.442 800 155,741 112,354 15,285,000 374,926 1,472.109 PERIOD 2c - Decontamination Following Wet Fuel Storage Period 2c Direct Decommissioning Acitvities 2c.1.1 Remove spent ftel racks 267 33 79 89 1.348 500 2,316 2,316 5,986 537,141 1,004 Disposal of Plant Systems 2c.1.2.1 Reactor Ff 1001 Amea1A 50 7 8 121 45 231 231 - 537 48,175 1.273 2c.1.2.2 Reactor El 1001 AremtB 64 1 4 54 13 28 164 164 578 57 28,513 1,737 2c.1.2.3 Reactor l 976 Are1A 11 1 1 16 7 36 38 - 72 6,482 304 2c.1.2.4 ReactorElg7 97eArWel ISO 11 27 328 115 121 752 752 3,516 511 188,501 4,017 2c. 1.2.5 Reactor El 976 Aee2A 7 1 1 - 13 5 26 26 - 57 5,136 174 2c.1.2.6 Reactor El 976 Are2B 38 1 3 42 16 20 121 121 449 72 24,474 1.056 2c.1.2 Totals 321 23 44 424 293 226 1,331 1,331 4,543 1,305 301,281 8,561 Decratamivatioa of Site Buddngs 2c 1.3.1 Reactor (post fuel) 257 510 97 138 163 1.742 747 3,856 3,656 1,749 32,119 3,281.859 18,302 2c.1.3 Totals 257 510 97 138 183 1.742 747 3,656 3,656 1,749 32,119 3.281,659 18,302 20 1.4 Scaffonldig In support of deconvrvussioning 518 8 3 42 g 138 712 712 405 25 20,498 7,023 2c.1 Subtotal Peitod 2c ActivityCosts 525 1,382 205 273 630 3,389 1,611 8,014 8,014 6,697 39,437 4.140.579 34,890 Period 2c Additional Costs 2c.2.1 Final Site Survey 1.205 362 1,567 1.567 12,480 2c.2 Subtotal Period 2c AdditbonalCosts 1,205 362 1,567 1,597 12,480 TLG Services, Inc.

S Cooper NuclearStation Documenl N01-1590-002, Rev. I Appendix C, Page 8 of"35 DecommssnioningCast Analysis Table C-1 Cooper Nuclear Station 2014 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed BurialVolumes Burial I Utilityand Activity Devon Removal Packaging Transport Processing Disposal Other Total Total Lic.Term. Management Restoration Volume Clan A Clans B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contln Oscy Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt. Lbs. Manhours Manhours Period 2c Collateral Costs 101 - 33 175 200 130 639 639 696 41,756 136 2c.3.1 Process liquid waste

- 22 - 3 25 25 2c 3.2 Smau tool aliomance 303.507 88 621 84 - 130 973 973 6,000 373 2c.3.3 Decommissiong Equipment Disposition 88 50 1,595 239 1,834 - 1,834 2c.3A4 Spent Fuel Capital and Transfer 345.263 224 101 22 121 225 621 284 1,595 503 3,471 1,637 1,834 6,000 1,069 2c. 3 Subtotal Pennd 2c Colsateral Costs Period 2c Period-Dependent Costs

- 23 113 113 2c.4.1 Decon supplies 90 197 20 217 217 2c4.2 Insurance

- 2 0 2 2 2c.4.3 Property taxes 256 - 64 320 320 2C.44 Health physics supplies

- - - 106 813 813 2c.4.5 Heavy equipment rntal 707 3,949 36,227 12 6 184 - 48 250 250 2c.4.6 Disposal of DAWgenerated - 12

- 149 22 172 172 2c.4.7 Plant energy budget 265 27 292 292 2c.4.8 NRC Fees 373 340 34 373 -

2c.4.9 Emergency Planning Fees 151 23 174 174 2c.4.10 Liquid Radwaste Processing EquipmentrServicos 34 5 29 - 39 2c.4.11 ISFSI Operating Costs 27,930 1,159 174 1,333 1,333 2c.4.12 Security Staff Cost 42,000 2c.4.13 DOC Staff Cost 3,126 469 3,595 3,595 705 5,404 5,404 80,220 2c-4.14 UtilityStaff Cost 4,699 150,150 1,719 13,096 12,684 413 3,949 38,227 12 2c.4 Subtotal Period 2c Penod-Dependent Costs 90 983 12 6 184 10,123 716 2,367 337 504 1,251 3,858 12,922 4,194 26.148 23.902 2,247 12,697 44,455 4,522,069 35,126 162,630 2c.0 TOTAL PERIOD 2c COST PERIOD 2e - License Ternination Period 2e Direct Decommissioning Activioes 2e 1.1 ORISE confiratoty survey 147 44 191 191 2e 1'2 Terrmnate license 147 44 191 191 2e.1 Subtotal Period 2e ActivityCosts Period 2e Additonal Costs 5,998 1,799 7,797 7,797 148,435 6,240 2e.2.1 Final Stte Surney - - - - - - 148,435 6,240 Subtotal Period 2e Addibonal Costs - , - - - - 5,890 1,799 7,797 7,797 2e.2 Period 2e Collateral Costs 2e.3.1 DOC staff relocatio expenses 912 137 1,049 1,049 217 33 250 - 250 - - - - -

2e.3.2 Spent Fuel Capital and Transfer 1,129 169 1,299 1,049 250 - - - - -

2e.3 Subtotal Period 2e Collateral Costs Period 2e Period-Dependent Costs 327 33 360 360 2e.4.1 Insurance 3 0 3 3 2e.4 2 Property taxes 737 - - 184 921 921 2e.4.3 Health physics supplies 8,380 3

- 3 1 42 11 58 58 914 2e.4.4 Disposal of DAWgenerated 139 21 160 160 2e.4.5 Plant energy budget 2e.4.6 NRC Fees 530 53 583 583 633 63 696 - 696 2e.4.7 Emergency Planning Fees 64 10 73 - 73 2e.4.8 ISFSI Operatig Costs 2,125 319 2,444 2,444 50,886 2e.4.9 Security Staff Cost 57,149 2ed.410 DOC Staff Cost 4,442 666 5,108 5,108 5,071 761 5,832 5,832 - 80.634 2e.4.11 UtilityStaff Cost 8.380 3 1888669 737 3 1 42 13.334 2.121 16,238 15,468 769 914 2e.4 Subtotal Period 2e Pedod-Dependent Costs 737 3 1 42 20,608 4.134 25.525 24,506 1,019 914 8,380 148,438 194,909 2e.0 TOTAL PERIOD 2e COST TLG Servicee, Inc.

Cooper NuclearStation Documrent NOI-1590-002, Rev. I DecommissioningCost Analysis Appendix C, Page9 of35 Table C-1 Cooper Nuclear Station 2014 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sits .LLRW NRC Spent Fuel Sits Processed Borial Volurmes Burial I Utilityand Actvtty Oeson Removal Packaging Transport Processlng Disposal Other Total Total Lit. Torm Management Restoration Volume Clan A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost costs costs Costs Costs Costs Continencv Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt. Lbs. Manhours Manhours PERIOD2TOTALS 6.750 39,950 10.481 6,870 30,933 46,637 212,221 73,483 427,325 385,213 41,211 901 319,826 219.601 3,334 976 - 31,151,470 771,150 2.653,551 PERIOD3b - Site Restoration Period 32DirectDecommissioning Acfivýies Demolition of Remaining Site Buildngs 3b.1.1.1 Reactr 1,473 221 1,694 1,694 14,089 3b.1.1.2 Augmented Radwaste 222 33 255 255 2,119 3b.1.1.3 Control 214 32 246 246 1,655 3b.1.1.4 Intake Structure 523 78 602 602 5,621 3b.1.1.5 LLRW Storage Pad 145 22 167 167 1,227 3b.1.1.6 Misceuaneous Structures - Clean 1,196 179 1,375 1,375 11.837 3b,1.1.7 Miscellaneous Structures -Contaminrated 27 4 30 30 572 3b.1.1.8 Muli-Purpose Facility 123 1 141t 141 1.982 3b.1.1.9 OWC Gas Generator 3 20 20 283 1t8 3b.1.1.10 Offce 156 23 179 179 1,920 3b.1.1.11 Radwaste 391 59 449 449 3,229 3b.1.1.12 Seat Well 17 3 20 20 166 3b.1.1.13 Sewage Treatment Area 4 1 5 5 53 3b.1.1.14 Transformer Yard 20 3 24 24 172 3b21.1.15 Tubine 2,596 389 2,985 2,985 40.503 3b.1.1.16 Turbine Pedestal 277 42 318 318 2.100 3b.1.1.17 Reactor(post fuel) 18 3 21 21 512 3b.1.1 Totals 7,418 1,113 8,531 8,531 88,040 Site Closeout Acivites 3b.1.2 Remove Rubble 424 64 488 488 3,286 3b. 1.3 Grade &landscape site 578 - 87 665 665 1,578 3b.14A Final report to NRC 156 23 179 179 -S 1,560 3b.1 Subtotal Period 3b Activity Costs 156 1,286 9,863 179 9,684 92,904 1.580 8,421 Period 3b Additional Costs 3b.2.1 Conorete Crushing 499 a 76 582 582 3,045 3b.2.2 Cofferdam 458 69 527 627 5,130 3b.2 Subtotal Period 3b Additional Costs 957 8 145 1,109 1,109 8,175 Period 3b Collateral Costs 3b.3.1 Small tool aflomnce 53 8 61 - 61 S92183 3b,32 Spent Fuel Capital and Transfer 27 211 211 3b.3 Subtotal Period 3b Collaeral Costs 53 183 35 271 211 61 Period 3b Period-Dependent Costs 3b.4.1 Insurance 751 75 826 826 3b24.2 Property taxes 7 3b.4.3 Heavy equipment rental 4,053 608 4,661 4,681 3b.4.4 Plant energy budget - 160 24 184 - 184 3b.4.5 NRC ISFSI Fees 339 34 373 373 32,4.8 Emergency Planning Fess 1,453 145 1,598 1,598 3b.4,7 iSFS Operating Costs 146 22 168 18 25.48 Security Staff Cost 4.878 732 5,610 4,937 673 116,814 3b.4.9 DOC Staff Cost 9.777 1,467 11,244 - 11,244 122,206 3b.4.10 UtilityStaff Cost 5.903 885 6,789 0 1,697 5,091 97,944 3b.4 Subtotal Period 3b Period-Dependent Costs 4,053 23,415 3,993 31,460 8 9,607 21,853 336.964 3b.0 TOTAL PERIOD 3b COST 13,483 23,762 5,459 42,704 179 9.818 32,707 101,079 338,524 TLG Servicea, Inc.

DocurentN01-1590-002, Rev. 1 Cooper NuclearStations Appendix C, Page10 of 35 Decommissuioninrg Coot Anralysis Table C-i Cooper Nuclear Station 2014 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Ott-Site LLRW NRC Spent Fuel site Proeessed Burial volumes Burial i Utilrty a Decon Reeontal Packaging Transport Processing Disposal Other Total Total LUc.Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor sInde Activity Oescrlption Cost Cost Costs Costa Costs CasTS COSts Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt. Lbs. Manhours Manhours PERIOD 3c -Fuel Storage Operations/Shipping Period 3c Collateral Costs 3c.3.1 Spent Fuel Capital and Transfer 16,015 2,402 18,418 18,418 3c.3 Subtotal Period 3c Collateral Costs 16,01b 2,402 18,418 18,418 Period 3c Period-Deperdent Costs 3c.4.1 Insurance 10,708 1,071 11.776 11,776 3C.4.2 Propenty taxes 98 10 108 108 3c.4.3 Plant energy budget 3c.44 NRC ISFSI Fees 6,234 623 6,857 6,857 3c.4.5 Emergency Planning Fees 20,704 2,070 22.774 22,774 3c.4.6 ISFSI Operating Costs 2.085 313 2,398 2.398 61,192 9,179 70,371 70,371 1,383,017 3c.4.7 Security Staff Cost 3CA4,8 UtilityStaff Cost 21,209 3,181 24,390 24,390 345,754 3c.4 Subtotal Period 3c Peiodt-Dependent Costs 122,227 16,447 138,674 138,674 1,728,771 138.242 18,849 157,092 157,092 1.728,771 3c.0 TOTAL PERIOD 3c COST PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Acilvities Nuclear Steam Supply System Removal 3d.1.1.t Vessel & Internals GTCC Disposal 660 7,470 1,188 9,316 9.316 508 89,497 3d.1.1 Totals 660 7,470 1,186 9.316 9,316 508 89.497 660 7,470 1.186 9.316 9,316 508 89,497 3d.1 Subtotal Period 3d Actisly Costs Period 3d Collateral Costs 3d.3.1 Spent Fuel Capital and Transfer * * - 78 11 87 - 87 -- -

3d.3 Subtotal Period 3d Collateral Costs - - - 78 11 87 87 - - . . -

Period 3d Period-Dependent Costs 3d.4.1 Insurance 17 2 18 18 3d.4.2 Property taxes 0 0 0 0 3d.4.3 Plant energy budget 3d.4.4 NRC ISFSI Fees 8 1 8 8 3d.4.5 Emergency Planning Fees 32 3 36 36 3 0 4 4 3d..8 ISFSI Operating Costs 3d.4.7 Security Staff Cost 96 14 110 110 3d.4.8 UtilityStaff Cost 33 5 38 38 - . * * . . 540 3M.4 Subtotal Period 3d Period-Dependent Costs 189 25 214 214 - . - * . - Z700 3d.0 TOTALPERIOD 3d COST 660 7.470 265 1,223 9.618 9,316 302 *. .5-089 89.497 - 2,700 PERIOD 3a - ISFSI Decontamination Period 3e Direct Decommissioning Activites Period 3e Additinal Costs 3e.2.1 ISFSI Decorntamination 656 4 24 55 1.192 360 2.290 2290 1,050 162,629 17,515 2,560 1.050 3e.2 Subtotal Period 3e Additlonal Costs 656 4 24 55 1'192 360 2,290 2!290 162,629 17,515 2,560 Period 3e Collateral Costs 3a.3.1 Small tool alowaunce 9 1 10 10

• 0 1 6 3e.32 Spent Fuel Capital and Transfer

- 9 -

• 6 2 18 16 30.3 Subtotal Period 3e Cotlateral Costs TLG Service., Ine.

Cooper Nuclear Stationa Document N01.1590-02, Rev. I Decrommissionting CoastAnsalysis Appendix C, Page 11 of"35 Table C-1 Cooper Nuclear Station 2014 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes BurialI Utilityand Activtty Oecon Removal Packaging Transport Processing Disposal Other Total Total Li. Ter-T. Management Restoration Volume Clans A Class 8 Class C GTCC Processed Craft Contractor Index AcvitiitsDescription Cast Cost Costs Costs Costs Costs ste Contintesc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet WI. Lbs. Manhours Manhours Period 30 Period-Dependent Costs 30.4.1 Insurance 145 14 159 159 0 1 1 -

3e.4.2 Propery taxes 30.4.3 Heavy equipment rental 232 35 267 267 3e.4.4 Plant energy budget 3e.4.5 Securnty Staff Cost 303 46 349 349 5,013 3e.4.6 UtilityStaff Cost 249 37 287 287 3,803 30.4 Subtotal Period 3e Period-Dependent Costs 232 699 132 1,063 1,063 - 68,816 3e.0 TOTALPERIOD 30 COST 897 4 24 55 1,896 495 3,370 3,370 1,050 162,629 17,515 11,376 PERIOD 3f - ISFSI Site Restoration Period 31Direct Deconmissioning Adivities Period 31Additional Costs 3f.2.1 ISFSI Demolition 487 44 80 611 4,336 160 3f2 Subtotal Period 3f Additional Costs 487 44 80 611 611 4.336 18S

- 2t7 Period 31Collateral Costs 31.3.1 SmaI tool anowance O 3 3 - - - - - -

- 2 - -

0 3 31.3 Subtotal Period 31Collateral Costs 3 - - - - - -

Period 3f Period-Dependent Costs 3f.4.1 Insurance 3f.4.2 Property taxes 1 0 1 1 3f.4.3 Heavy equipment rental 79 12 91 91 3f.4.4 Plant energy budget 3f.4.5 Security Staff Cost 155 23 179 179 2,569 3f.4.9 Utaity Staff Cost - 110 16 126 126 1,594 3f.4 Subtotal Period 3WPeriod-Dependent Costs 79 266 52 396 396 4,163 3f.0 TOTALPERIOD 31 COST 568 - - 310 132 1,010 1,010 - 4.336 4.323 PERIOD 3 TOTALS 14,948 664 24 - 7.524 164.475 26,158 213,793 9,495 171,591 32.707 1.050 - 508 252.126 122,930 2,085,694 TOTALCOST TO DECOMMISSION 9.296 57,845 11.199 7,212 30.933 56,640 481,317 117.614 772,058 516,078 231,584 34.396 319.826 233,906 3,877 976 508 31,646,710 905,345 5,788.586 TLG Services, Inc.

Cooper Nacka, Sotation DocumentN01-1590.002, Rev. I De-i-~muioning Cast An.aLyxia Appendix C, Page 12 of 35 Table C-1 Cooper Nuclear Station 2014 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Situ LLRW NRC Spent Fuel Situ Processed Burial Volumes Burial I Utilityand Activity Decon Removal Packaging Transport Processing Disposal Other Total Total LIc.Turm. Management Restoration Volume Class A Class B Claus C GTCC Processed Craft Contractor Index Activity Descriptin Cost Cost Costs Costs Costs Costs Costs Continaencv Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt. Lbs. Manhours Manhours TOTALCOST TO DECOMMISSIONWITH 17.97% CONTINGENCY: $772,058 thousands of 2008 dollars TOTALNRC UCENSE TERMINATIONCOST IS 65.55% OR: $606,078 thousands of 2008 dollars SPENTFUEL MANAGEMENTCOST IS 30% OR: $231,584 thousands of 2008 dollars ON-NUCLEARDEMOUTION COST IS 4.46% OR: $34,396 thousands of 2006 dollars TOTALLOW-LEVE RADIOACTIVEWASTE VOLUMEBURIED (EXCLUDINGGTCC): 238,758 cubic feet TOTALGREATER THANCLASS C RADWASTE VOLUMEGENERATED: 600 cubic feet TOTALSCRAP METAL REMOVED: 30,345 tons

'OTALCRAFT LABOR REQUIREMENTS: 905,346 man-hours End Notes:

Weu- indicates that this actsty not charged as decommissioning expense.

a - indicates that this activity performed by decommissioning staff.

0 - indicates trat this value is less than 0.5 but is non-zero.

a ceal cotaining"-" indicates a zero value TLG Services, Inc.

0 Cooper NuclearStalin DocumentN01.1590-002, Rev. I Appendix r, Page 13 of 35 DecommissioningCoal Analysis Table C-2 Cooper Nuclear Station 2014 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Situ LLRW NRC Spent Fuel Site Processed Burial Volumes Burial IaUoiy end I Activity II Ind.. A*tlvllv I*¢* ;'inl]nn Decon Cnst Removal cost Packaging costs Transport costs Processing Costs Disposal Costs Other Costs Total Continaeny Total Casts Lic. Term.

Costs Management Costs Restoration Costa Volume Cu. Feet Class A Cu. Feet Class B Class C Cu. Feet Cu. Feet GTCC Cu. Feet Processed Wt. Lbs.

Craft Manhours Contractor Manhours Index Acdvttv Description I

PERIOD Ia -Shutdown through Transition Peried 1a Direct Decommissioning Activties Sa.1.1 SAFSTOR site characterization survey 346 104 450 450 130 20 150 150 1,300 la. 1.2 Prepare preliminary decommissioning cost la.1.3 Notificion of Cessation of Operations a la.1.4 Remove fuel &source material la.1.5 Notilicationof Permanent Defueling a la.e 16 Deactivate plant systems &process waste 200 30 230 230 2,000 la.1.7 Prepare and submit PSDAR 130 20 10 150 1,300 la.1.8 Review piant dwgs &specs.

1l.1.9 Perform detailed red survey 100 15 115 115 1,000 10.1.10 Estimate by-product inventory 100 15 115 115 1,000 1:.1.11 End product description 150 23 173 173 1,500 la.1.12 Detailed by-product inventory 100 15 115 115 1,000 la.1.13 Define major work sequence 310 47 357 357 3,100 1.1.14 Perform SER and EA o0o 75 575 575 5,000 1a8..15 Perform SitsSpecttc Cost S"udy Activity Specifcations la.16,1.1 Prepare plant and facilies for SAFSTOR 74 566 566 4,920 63 479 479 4,167 Ia.1.16.2 Plant systems 417 47 359 359 3,120

,a.1-16.3 Plant structures and buildings 312 200 30 230 230 2,000 18.1.16.4 Waste management

• 200 30 230 230 2,000 la.1.16.5 Facilityand site dormancy

• 1,621 243 1,864 1,864 16,207 la:1.1816 Total Detailed Work Procedures

• - - - l11 18 136 136 1,183 10.1.17.1 Plantsystems 120 18 138 138 1,200 10.1.17.2 Facilitiycloseout &dormancy * - - -

238 36 274 274 2.383 la.1.17 Total - - . -

la.1.18 Procure vacuum drying system 10 2 12 12 1]0o 1l.1,19 Draintde-energize non-cont. systems la 1,20 Drain &dry NSSS 1I.1.21 Drainlde~energbe contaminated systems a 1:.122 Oeconssecure contaminated systems 35.890 3,935 642 4.577 4,577 la.1 Subtotal Period 1aActivity Costs Penod 18 Collateral Costs 18.3.1 Spent Fuel Capital and Transfer - - - - 10,335 1,550 11,886 11.888 6

la.3.2 Corporate Overheads * - - - 3,105 468 3,570 3,570 18.3 Subtotal Period 18 CoUeateralCosts - . - - 13.440 2,016 15,456 3.570 11,888 6

Period 18 Period-Dependent Costs la.4.1 Insurance 1,600 160 1,760 1,760 10.4.2 Property taues 4 0 4 4 la,4.3 Health physics supplies 370 93 463 463 la.4.4 Heavy equipment rental 368 55 423 423 73 - 19 100 100 1,575 14,445 1 18.4.5 Disposealof DAW generated 18.4.6 Plant energy budgel 927 139 1,066 1,066 1a.4.7 NRC Fees 706 71 776 776 a8.4.8 Emergency Planning Fees 1,185 118 1,303 10.4.9 Spent Fuel Pool OAM 745 112 857 857

'a.4.10 ISFSI Operating Costs 85 13 98 - 98 6,021 903 6.924 6,24 157,471 1..4.11 Security Staff Cost TLG Services, Inc.

Cooper Nuclear Station Document NI01.1590-002, Rev. 1 DecomnmissionintgCast Annalysis Appendix C, Page 14 of 35 Table C-2 Cooper Nuclear Station 2014 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollarsu)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and I I Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Tenn. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor m InnA* A*nYl*

• nn1*n Cost Cost Costs Costs Costs Cests Costs Contingencv costs Costs Costs Costs Co. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt. Lbs. Manhours Manhours n ex Ac ý c at n Period la Period-Dependent Costs (continued) la.4.12 UtilityStaff Cost - 22,690 3,403 26,093 26,093 S- - 423.400 1a.4 Subtotal Period Ia Period-Dependent Costs 738 73 33,962 5,087 39,867 37,609 2,258 1.575 14.445 5 580,871 la.0 TOTAL PERIOD oa COST 738 73 51,338 7.745 59,901 45,757 14,144 1,575 14,445 5 616,761 PERIOD lb - SAFSTOR Limited DECON Activities Period l b Direct Decornmissiornng Actevities Decartarinaion of Site Buildings lb.1.1.1 Reactor 2,929 - 1.465 4,394 4,394 - 68,438 -

l1b.1.1.2 Augmented Radwaste 52 26 78 78 1,562 lb.1.1.3 Miscellaneous Struaurns - Contaminated 376 188 565 565 8.542 lb.1.1.4 Mult-Purpese Facility 68 34 101 101 2.036 lb.1.1.5 Radwaste 158 79 237 237 4.761 lbit.1.6 Turbine 520 260 780 780 15.667 1.1.1 Totals 4.103 2,052 6,155 6,155 101,008 10b.1 Subtotal Period lb Activity Costs 4.103 2,052 6.155 6,155 101.006 Period lb Additional Costs lb.2.1 Spent Fuel Pool Isolation .- 9,407 1,411 10,818 10,818 134,329 10.002 1b.2.2 Asbestos Insulation Disposal 773 1 65 558 - 265 1,662 1,662 10,333 0b.2 Subtotal Period l b Additional Costs 773 1 65 558 9,407 1,676 12,480 12,480 10.333 134.329 10,002 Period lb Collateral Costs lb.3.1 Decon equipment 713 107 820 820 l b.3.2 Process liquid waste 229 74 392 448 293 1,436 1,436 1.561 93,644 304 10b3.3 Small tool allowance - 70 11 81 81 1b.3.4 Spent Fuel Capital and Transfer 1,510 227 1,737 - 1.737 lb.3.5 Corporate Overheads - 768 115 880 880 1b.3 Subtotal Period l b Collateral Costs 942 70 74 392 448 2,276 752 4,954 3,217 1,737 1,561 93,644 304 Perod lb Period-Dependent Costs lb.4.1 Decon supplies 1,156 289 1,445 1,445 1b.4.2 Insurance 121 12 133 133 lb.4.3 Property tones - 1 0 1 1 1b.4.4 Health physics supplies 473 118 592 592 1b.4.5 Heavy equipment rental 91 14 104 104 1b0.4 Disposal of DAW generated 5 3 81 - 21 110 110 1,741 15.968 5 0b.4.7 Plant energy budget 229 34 203 263 1b.4.6 NRC Fees 174 17 191 191 lb4.9 Emergency Planning Fees 292 29 321 321 1b04.10 Spent Fuel Pool O&M 184 28 211 211 1b.4.11 ISFSI Operating Costs 21 3 24 - 24 1b.4.12 Security Staff Cost 1.485 223 1,707 1,707 X30829 1b.4.13 Utlity Staff Cost - 5,595 839 8,434 8.424 104,400 10.4 Subtotal Period 1b Peoitod-Dependent Costs 1,156 564 5 3 81 8,101 1,628 11.538 10,981 557 1,741 15,908 5 143,229 1b.0 TOTAL PERIOD Ib COST 6.201 1.407 850 480 1,087 19.783 8,107 35,126 32,833 2,294 13,635 243,942 111,318 143,229 TLG Services, lne,

Cooper Nuclear Station Document NO1.1590-002,Rev. I Deromnmissonieong Cost Analysis Appendix C, Page 15 of 35 Table C-2 Cooper Nuclear Station 2014 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial / Utilty and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total LIc. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activt Description Cost Cost Costs Costs Costs Costs Costs Contln en costs costs s Costs Cu. Feet Cu. Feet Cu. Feet Co. Feet Co. Feel Wt Lbs. Manhours Manhours PERIOD lc - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 387 58 445 445 3.000 1c.1 . Inslall containment pressure equal. lines 31 700 5 36 36 Ic.1.3 Interim survey prior to dormancy 733 220 953 953 15,696 1c.1.4 Secure building accesses a 1c. 1.5 Prepare &submit interim report 58 9 67 67 583 1c.1 Subtotal Period 1cActivity Costs 419 791 291 1,501 1,501 19,396 583 Period Ic Collateral Costs Ic.3.1 Process iquid oaste 235 76 403 460 301 1,475 1,475 1,603 96.195 313 ic.3.2 Small to0 altuwance 0 3 3 1c.3.3 Spent Fuel Capital and Transfer 1,527 229 1,756 - 1,756 1c.3.4 Corporate Overneads - 774 116 890 890 lc.3 Subtotal Period lc Collatera Costs 235 76 403 460 2,301 646 4,124 2,368 1,756 1,603 96,195 313 Period 1 c Period-Dependent Costs 0l.4.1 Insurance 122 12 134 134 1c.4.2 Property taces 1 0 1 1 IC.4.3 Helth physics supplies 160 40 200 200 1c.4.4 Heavy equipment rental 92 - 14 105 105 393 lc.4 5 Disposal of DAW generated 18 - 5 25 25 3,601 1 lc.4.6 Plant energy budget 231 35 266 266 lc.4.7 NRC Fees 176 18 194 194 1c.4.8 Emergency Planning Fees 295 30 325 - 325 le.4.9 Spent Fuel Pool O&M 186 28 214 214 1.4.10 ISFS1Operatong Costs 21 3 24 - 24 1c.4.11 Security Staff Cost 1,501 225 1,726 1,726 39,260 1C.4.12 U~ty Staff Cost 5,657 849 6,505 6,505 105,560 1c.4 Subtotal Period Ic Period-Dependent Costs 252 1 1 18 8,191 1257 9,720 9,157 563 393 3,601 1 144,820 1c.0 TOTALPERIOD 1c COST 235 673 77 404 478 11.283 2,195 15,345 13,026 2,319 1,996 99,796 19,710 145,403 PERIOD I TOTALS 8.437 2,818 162 866 1,638 82,404 16,047 110,372 91,616 18,757 17,205 358,183 131.033 905,393 PERIOD 2a - SAFSTOR Dormancy wRh Wet Spent Fuel Storage Period 2a Direct Decommissioning Activities 2a.1.1 QuarteplyInspection 2a.1.2 Sermi-annualenvionmental survey 2a. 1.3 Prepare reports 2a 1.4 Bituminous roof replacement - - . . . - 63 9 72 72 20.1.5 Maintenance supplies - . . .503 126 629 629 2a.1 Subtotal Period 2a ActivityCosts - . . . . . 568 135 701 701 Period 2a Co/Lateral Costs 2B.3.1 Spent Fuel Capital and Transfer - . . - 26.468 3,970 30,435 - 30,435 - -

2a.32 Corporate Overheads * . . - 4,139 621 4,759 4,759 20.3 Subtotal Period 2a Collateral Costs -. - . - 30,604 4,501 35,195 4,759 30,435 . -

Period 2a Period-Dependent Costs 2a.4.1 Insurance 1,962 196 2,158 2,158 . -

2a.4.2 Property laces 16 2 18 - 18 2a.4.3 Health physics supplies 344 88 430 430 4LG Services, Inc.

0 DocumentN01-1590-002, Rev. I Coop~er Nuclear Station Appendix C, Page 16 of 35 Decomsmissioning CastAnaslysis Table C-2 Cooper Nuclear Station 2014 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial / Utility and Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Teom. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor IActivity Continmescy Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt, Lbs. Manhours Manhours E In*BX AC*V* *cno[* H Cost Cost Costs Costs Cost. Costs Costs n ex Peoted 2a Period-Dependent Costs (continued) 2a.4.4 Disposal of DAWgenerated 13 198 - 52 270 270 - 4.267 39,139 13 2a.4.5 Plant energy budget 742 111 853 - 853 20a.4.6 NRC Fees 807 81 887 887 -

2a.4.7 Emergency Planning Fees 3,374 337 3,712 3.712 2a.4.8 Spent Fuel Pool O&M 2,984 448 3,431 3,431 2a.4.9 ISFSI Operating Costs 340 51 391 391 20.4.10 Security Staff Cost 17,728 2,659 20,387 20,387 444,561 2a.4.11 Utity Staff Cost 18.816 2,822 21,639 21,639 - -329,769 20.4 Subtotal Period 2a Period-Dependent Costs 344 13 198 46,768 6,845 54,176 1,587 52,588 4,267 39,139 13 774,330 344 13 198 77,939 11,571 90,072 7,048 83,024 4.267 39,139 13 774,330 20.0 TOTALPERIOD 2a COST PERIOD 2b. SAFSTOR Dormancy with Dry Spent Fuel Storage Period 2b Direct Decommissioning Activities 2b.1.1 Quarterly Inspection 2b.1.2 Semi-annual environmental survey a 2b.1.3 Prepare reports 2b.1.4 Bituminous roof replacement 432 65 497 497 2b..1.5 Maintenance supplies 3,453 863 4,317 4,317 2b.1 Subtotal Period 20 ActivityCosts 3,886 928 4,814 4,814 Pertod 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 18.092 2,714 20.806 20,806 2b.3 Subtotal Period 2b Collateral Costs 18,092 2,714 20,806 20,800 Period 2b Period-Dependent Costs 2b.4.1 InsuSrnce S11.977 1,198 13.174 13.174 2b.4.2 Property tooas 110 11 121 - 121 2b.4.3 Health physics supplies 1,981 - 495 2,476 2,476 2b.4A. Dopoe l of DAWgenerated 80 44 1,268 - 332 1,725 1,725 - 27,278 250,212 84 2b.4.5 Plant energy budget 2,546 382 2,928 2,928 2b.4.6 NRC Fees 5,536 554 6,090 6,090 20.4.7 Emergency Planning Fees 23,161 2,316 25,477 25,477 20.4.8 ISFS1Operating Costs 2,332 350 2,682 2,682 2).4.9 Security Staff Cost 70,072 10,511 80,583 80,583 1,547,177 2b.4.10 UtilityStaff Cost 51,313 7,697 59,010 - 59,010 916.846 1,981 80 44 1.268 167,047 23,845 194,266 10,290 183,976 27,278 250.212 84 2.464,023 2b.4 Subtotal Period 20 Peorid-Dependent Costs 2b.0 TOTALPERIOD 2b COST 1,981 80 44 1.268 189,025 27,487 219,886 15,104 204,781 27.278 250.212 84 2.464,023 31,545 289,351 97 3,238,353 PERIOD 2 TOTALS 2.325 93 51 1.467 266.964 39,058 30%,957 22,152 287,805 PERIOD 3 - Reactivate Sits Following SAFSTOR Dormancy Peaod 3a Direct Decommissioring Acrvities 32.1.1 Prepare preliminary decommnssioning cOst 130 20 150 150 1,300 3a.1.2 Review plant dwgs &specs. 460 69 529 529 4,600 3a.1.3 Perform detailed red survey 3a.1.4 End product description 100 15 115 115 1,000 3a.1.5 Detailed by-product inventory 130 20 150 150 1,300 3a.1.6 Define major work sequence 750 113 863 863 7,500 310 47 357 357 3,100 3a.1.7 Perform SER and EA 3a.1.0 Perform Site-Speolc Cost Study 500 75 575 575 5,000 3a.1.9 Prepare/submit License Termination Plan 410 61 471 471 4,090 3a.1.10 Receive NRC approval of termination plan a TLG Service., Inc.

Doeumnent N01-1590.002, Rev. I Cooper NuclearStation Appendix C, Page 17 of 35 DecommissioningCost Analysis Table C-2 Cooper Nuclear Station 2014 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sits LLRW NRC Spent Fuel Site Processed Burial Volures Burial I Utilityand Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic.Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index ActivSitDescription Cost Cost Costs Costs Costs Costs Costs Contingenc Costs Costs Costs Costs Cu. Feet Cu. Foet Co.Fecl Ca. Fot Cu. Feet WLtLbs. Manhours Manhours ActivitySpecifiations 737 ill 848 763 85 7,370 3a.1.11.1 Re-activate plant &temporary facilities 4,167 30.1.11.2 Plant systems 417 63 479 431 48 710 107 817 817 7,100 3a.1.11.3 Reactor internals 650 98 748 748 6,500 3a.1.11,4 Reactor vessel O5D 3a.1.11.5 Sacrif-al shield 50 8 58 58 100 15 115 115 1,00O 3a.1.1 1.6 Moisture separatorslroheateo "92 160 24 184 92 1.600 3a 11, 7 Relnforced concrete 209 31 240 240 2,088 3a.,. 1.1 Main Turbie 2,088 3a.1.11.9 Main Condelsers 209 31 240 240 200 30 230 230 2,000 3a. 1.11.10 Pressure suppression structure 160 24 184 184 1,600 3a.1.1111 Dryrele 3,120 3a 1.11 2 Plant structures & buildings 312 47 359 179 179 3a.11.13 Wastse asagement 460 69 529 529 4.600 14 104 52 52 900 3a.1.1 1.14 Facility & site ciut 90 44,633 4.463 669 5,133 4,677 456 - - -

3.1.11 Total Plann & site Preparations 240 36 276 276 2,400 3a.1.12 Prepare dismantling sequence 3a. 1.13 Plant prep. &temp. svces 2,700 405 3,105 3.105 140 21 181 161 t1,400 3s.1,14 Design vater ciearnup system 3a.1.15 Rigging/Cont Cntt Envlps/totlitgletc. 2,100 315 2,410 2,415 3a..116 Procure casks/finers & containers 123 18 141 141 1.230 3a, 1 Subtotal Period 3a Acivity Costs 12,558 1,883 14,439 13.683 456 - - - 77,559 Perod 3a Period-Dependent Costs 3a.4.1 'osuraro 420 42 462 462 3a.4-2 Propefry tanes 4 0 4 4 324 405 3..4.3 Healt physics supplies 81 405 3a.4.4 Heavy equipment rental 368 55 423 423 4 2 62 - 16 84 84 1.329 12,190 4 3a.4.5 Disposal of DAWgenerated 3a.4.6 Plant energy budget 927 139 1,066 1,066 3a.4.7 NRC Fees 249 25 274 274 2,855 428 3,283 3,283 65,179 3a.4.8 Security Staff Cost

- 14,190 2,128 16,318 16,318 2 258,629 3a.4.9 UtilityStaff Cost 691 4 2 62 18,644 2,915 22,318 22,318 1,329 12.190 4 323,807 3a.4 Subtotal Period 3a Period-Dependeol Costs 3a.0 TOTAL PERIOD 3a COST - 691 4 2 62 31,200 4,799 36,758 36,302 456 1,329 12.190 4 401,366 PERIOD 3b - Decomrissioning Preparations Penod 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 473 71 544 490 4,733 400 60 460 460 4,000 3b.1.1.2 Reactor internals 135 20 155 39 118 - - - 1,350 3b.1.1.3 Remaining budings 100 15 115 115 t1.000 3b.1.1.4 CRDousigs & Nis 100 15 115 115 1,000 3...1. 5 Incoreinstumrentation 200 30 230 230 2.000 31,.1. 6 Removal primary cosotarnmnt 363 54 417 417 3,630 3b.1.1.7 Reactor vessel 120 18 138 69 69 - - 1,200 3b.1.1.8 Faciity ckOo*out 120 18 138 138 1,200 31b.1 .9 Sacriofna shreld 100 15 115 56 1,000 3b.1.1.10 Reinforced concrete 3b.1 111 Main Turbie 208 31 239 239 2,080 209 31 240 240 2,088 3b.1.1.12 Man Condensers TLG Services, Inc.

Cooper Nuclear Statdion Document NO1-1590-002,Rev. 1 DecuraraissioniagCost Anobait. Appendix C, Page 18 of 35 Table C-2 Cooper Nuclear Station 2014 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

On-site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I UUtty and I jA tinvti D0con Removal Packaging Transport Processing Disposal Other Total Total Lie. Termo Management Restoreaton Volume Class A Class B Class C GTCC Processed Craft Contractor n exU *V* L~~ l Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet WL. Lbs. Manhourm Manaoure I Detaied Work Procedures (continued) 3b.1.1.13 Moisture separators& reheatars 200 30 230 230 2,000 3b.1.1.14 Radwaste building 273 41 314 283 31 2.730 3b.1.1.15 Reactor building 273 41 314 283 31 2,730 3b.1.1 Total 3.274 491 3,765 3,405 360 32,741 3b.1 Subtotal Period 3b Acivity Costs 3,274 491 3,765 3,405 360 32,741 Period 3b Additioeal Costs 3b.2.1 Site Characterization 5,395 1,619 7,014 7,014 3b.2 Subtotal Period 3b Additional Costs 5,390 1.619 7,014 7,014 Pedod 30 Collateral Costs 3b.3.1 Decon equipment 713 107 820 820 3b.3.2 DOC ldaff relocation expenses 912 137 1,049 1,049 3b.3.3 Pipe cutting equipment t1,000 150 1,150 1,150 3b.3 Subtotal Period 3b Collateral Costs 713 1,000 912 394 3,019 3.019 Period 3b Period-Dependent Costs 3b.4.1 Decon srupplas 22 - - 5 27 27 3b.4.2 Insurance 246 25 270 270 3b.4.3 Property tuaes 2 0 2 2 3b.4.4 Health physics supplies 179 45 224 224 3b.4.5 Heavy equipment rental 184 - 28 212 212 3b.4.6 Disposal of DAW generated 35 - 9 48 48 754 6,913 2 3b.4.7 Plant energy budget 465 70 534 034 3b.4.8 NRC Fees 125 12 137 137 3b.4.9 Security Staff Cost 1,431 215 1,648 1,646 32,679 3b.4.10 DOC Staff Cost 4,378 657 5.035 5.035 58,560 3b.4.11 Utlity Staff Cost - 7.114 1,067 8,181 8.181 - - 129,669 3b.4 Subtotal Period 3b Period-Dependent Costs 22 363 35 13,781 2,133 16,317 16,317 754 6.913 2 220,907 3W.0 TOTAL PERIOD 3b COST 735 1,363 35 23,342 4,830 30,115 29,755 360 754 6,913 2 253,648 PERIOD 3 TOTALS 735 2,055 3 97 54,542 9,435 68,872 66.056 816 2,083 19,104 6 655,014 PERIOD 4a -Large Component Removal Period 4a Diract DecomnmissioningActivites Nuclear Steam Supply System Removal 4a.1.1.1 Recirculation System Piping & Valves 18 70 14 14 25 272 101 512 512 100 897 119,606 2,487 4a.1.1.2 Recircutatio Pumps &Motors 6 28 11 26 321 95 488 488 - 1,188 132,880 1,125 4a.1.1.3 CRDMs &Nis Removal 24 139 377 68 317 174 1,099 1,099 6,935 - - 126,494 3,972 4a,1.1.4 ReactorVessel Internals 86 1.959 3,871 912 4,981 155 5,222 17,185 17,185 1,878 1.377 344 - 359,044 18,900 888 4a.1.1.5 Vessel &Internals GTCC Disposal - 7,470 - 1,120 8,590 8,590 - 508 89,497 - -

4a.1.1.6 Reactor Vessel 5,054 906 351 3,006 155 5,631 15,103 15,103 - 14,106 - - - 1,447,089 18,900 888 4a.1.1 Totals 132 7,.50 5,179 1,371 25 16,367 309 12,343 42,977 42,977 100 25.004 1,377 344 508 2,274,810 45,384 1,776 Removal of Major Equipment 4a. 1.2 Main TurbiterGeneatorr 167 845 372 6.376 1,138 8,898 8,898 61,604 2,772,179 4,438 4a. 1 .3 Main Condensers 708 588 259 4,439 940 6,932 6,932 42,889 1,930,000 18,519 Cascading Costs from Clean Budding Demolition 4a.1.4.1 Reactor 260 39 299 299 2,486 4a.1,4.2 Augmented Radheuste 25 4 28 28 235 4a.1.4.3 Radwaste 43 7 50 50 359 TLG Servivea, Inc.

Cooper NuclearStation Document N01-1590-002,Rev. I DeconmissioningCost Analysis Appendix C, Page 19 of 35 Table C-2 Cooper Nuclear Station 2014 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars) off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Decon Removal Packaging Transport Processing Disposal Other Total Total Lit. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor 1

IActivity I*MAY A*VJ*

• MnT* M C,..s Cos Cost. Coo. uts Costs C os*

c*ts Contlononen Crste Costs Coto Centst C... Feat Co. Feet Cu. Feet Co. Feet Co. Feet WE Lbs. Munoutoos Monhouts ex v c of It cost cast costs costs costs C;0sts Costs ContInQencv costs costs costs costs Cu Feet Cu Fast Cu Feet Cu Feet Cu Fast WL Lbs. Manhours Manhours Cascading Costs from Clean Building Demolition (coninued) 4a.1.4.4 Turbine - 285 - 43 328 328 4.419 4a 1 .4 Totals 613- . 92 705 705 7,498 Disposal of Plant Systems 4a.1.5.1 Augmented Radwaste El 877AreslA 203 28 28 432 166 857 857 2,055 172,205 5,668 4a. 1.5.2 Augmented Radwaste El 903 Ar.elA 66 6 7 104 44 228 228 469 41,608 1,842 4a.1.5.3 Augmented Radmuste El 918 ArealA 52 10 9 139 50 260 260 765 55,345 1,432 4a.1.5.4 Augmented Radwaste El 929 ArealA 21 4 5 - 73 25 127 127 -. 324 29,038 579 4a.1.5.5 Augmented Radwaste El 929 Aeal B 3 O 0 4 - 1 8 8 38 1,529 75 4a.1.5.6 DRYWELLArealA 457 85 84 1,289 458 2,373 2,373 5,726 513.627 12,634 4a. 1.5.7 DRYWELLArea16 112 1 5 75 2 41 235 235 806 10 33,576 3,384, 4a.1 .5'8 Turbine El 932 ArealB 324 16 86 1.477 - 317 2,220 2,220 - 15.808 641,963 9,170 4a 1.5.9 Turbine El 932 Area2C 1 9 9 - 237 4a 1.5.10 Turbine El 932 Ara3C 67 10 78 78 - 2,083 4a. .5 11 YardArealB 518 00 264 4,517 - 852 6,201 6,201 - 48,385 - 1,964,114 14,340 4a15 Totats 1,831 202 487 6.073 2,040 1,964 12,597 12,510 87 65,016 9,348 3,453,003 51.444 4a 1.6 Scaffolding in support of decommissioning - 2,049 24 11 168 23 547 2,821 2.821 1,621 101 81,992 27,411 4a.1 Subtotal Period 4a Acviaty Costs 132 12,816 6,828 2,500 17,081 18,430 309 17,025 74,831 74,844 117 171,229 34,453 1,377 344 508 10,511,780 155,694 1,776 Period 4a Coulateml Costs 4a.3.1 Process iquid aste 61 - 21 113 129 82 409 408 - 451 - 27,075 88 -

48.3.2 Small tool allowance - 90 14 104 94 10 -

4a.3 Subtotal Period 4a Collateral Costs 61 90 21 113 129 96 512 502 10 451 27,075 88 Perod 4a Perod-Dependent Costs 4a.4.1 Decon supplies 49 12 61 61 4a4.2 Insurance 549 55 604 604 4a4.3 Property laxes 4 0 5 4 0 4.4.4 Health physics supplies 944 236 1,180 1,180 4as4.5 Heavy equipment rental 1,981 297 2,278 2,278 4a.4.6 Disposal of DAWgenerated 26 14 405 - 106 551 551 8,708 79,878 27 4a.47 Plant energy budget 9-87 148 1,135 1,135 484.8 NRC Fees 737 74 811 811 4a.4.9 Liquid Radwaste Processing Equipment/Services 420 63 483 483 4a.4.10 Security Staff Cost 3,199 480 3,679 3,679 73,036 4a'4.11 DOC Staff Cost 11,638 1,746 13,384 13,384 161,263 4.4.812 Uility Steff Cost 16,014 2,402 18,416 18,416 292,143 4a.4 Subtotal Period 4a Period-Dependent Costs 49 2,925 26 14 405 33,548 5,619 42,586 42,585 0 - 8,708 - 79,878 27 526,441 4a.0 TOTALPERIOD 4o COST 242 15,631 6.885 2,628 17,081 18,964 33,858 22,740 118,029 117,931 98 171,229 43,613 1,377 344 508 10,618,740 155,809 528,217 PERIOD 4b - Site Decontamination Period 4b Direct Decommissioning Actvities 4b81.1 Remove spent fuel rocks 262 33 78 68 - 1,348 498 2,306 2,308 5,986 - 537,141 1,004 Disposal of Plant Systems 4b.1.2.1 ContrlElO2 Areul- 280 7 39 674 176 1,176 1,178 - 7.213 292,908 7,797 4b1 .2.2 Contro El 03 Amel C 8170 25 195 - 195 5,155 4b.1.2.3 Control El 918 AealC 66 10 76 76 2,100 4b.1.2.4 Control El 932 AmealC 22 3 28 26 702 4b5.1.2.5 Intake 101 15 118 116 - 3,136 4b.1,2.6 Mult-Purpose Fauility 198 3 14 239 88 541 541 2,558 103,862 5,430 4b 12.7 Radwaste El 877 ArealA 398 75 62 - 949 353 1,838 1,836 - 5,097 377,917 10,930 MTG Services, Inc.

CooperNuclear Station Document N01.1590-002, Rev. I Appendix C, Page20 of 35 Decommissioning Cost Analysis Table C-2 Cooper Nuclear Station 2014 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Tero. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor IActivity Cost Cost Costs Costs Off-Sits Costs LLRW Costs Costs Contingeney Costs NRC Costs spent Fuel Costs Sit e Costs Processed Ca. Feet Co. Feet Cu.Burial Feet Volume ws Cu. Feet Cu. Feet turLbs.

WtL ialIU Manhours tiita .. I Manhours n as - .- Y- I-.. -

Disposal of Plant Systems (continued) 4b.1.2.8 Radwaste EJ877 Aea2A 7 113 41 213 213 613 44.992 1,189 13 201 72 372 372 M,56 79.963 1,969 4b.1.2.9 Redwaste El 877 Area3A 10 153 68 351 351 684 61,153 3,015 4b.1,210 Radwase El 903 AnealA 29 439 165 856 856 1.955 175.093 5,282 4b11.2.11 Radwaste El 903 Area2A 7 104 37 190 190 463 41.66 1,029 4b.1.2.12 RadweseEl 903 Area3A 2 30 12 64 64 135 12.033 477 4b.1.2.13 Radwaste El 918 ArealA 3 39 15 75 75 201 15,667 448 4b.1.2.14 Radwasas El 918 Area2A 22 338 136 705 705 1,690 134,827 5,045 4b.1,2.15 Radwaste E 918 Area3A 4 60 22 115 115 266 23.735 680 41,h*2.16 Rawasis El 934 ArealA 12 177 72 370 370 808 70,665 Z663 4b.1.2.17 Radwaste El 934 A0ea2A 2 24 9 47 47 105 9.381 305 4b.1t...18 Radwaste El 949 ArealA 48,175 1,261 4b.1.2.19 Reactor El 1001 ArealA 8 121 45 230 230 537 4 64 26 157 157 689 27,979 1,681 4b.1.2.20 Reactor EC1001 Areal B 16 246 83 430 430 - 1.091 97,074 2,024 41b12.21 Reactor El 859ArealA 58 994 - 269 1,771 1.U71 10,641 432,136 12,411 41,b.2.22 Reactor EC859 ArealB 26 401 125 648 648 - 1,780 159,714 Z094 41b.12.22 Reactor El 859 Area2A 8 131 38 247 247 1,406 - 57,093 1,954 41,1.2.24 Reactor El 859 Area2B 9 - 137 48 251 251 608 54,543 1,321 4b1,.2,25 Reactor al 859 Area3A 2 42 15 93 93 453 18,381 951 41.1.2.26 Reactor C 8599Ae3B 8 117 44 227 227 - 520 46,666 1,374 4b.1.2.27 Reactor El 859 Area4A 2 31 - 9 59 59 331 - 13,424 476 4b.1.2.28 Reactor El 859 Area4B 1,798 17 262 85 443 443 1.163 104,381 41,1.2.29 Reactor El 859 Area5A 2 41 - 16 98 98 442 17.962 1,087 41,1.2.30 Reactor E 859 AreaSB 42 - 651 275 1,424 1.424 - 2,892 259,190 10,497 4b11.2.31 Reactor El 903 AreaA 32 550 201 1,240 1,240 5,890 - 239.197 12.496 4b.1.2.32 Reactor El 903 ArealB 4b.1.2.33 Reactor EC903 Area2A O 6 3 14 14 - 226 2,372 120 11 190 48 320 320 2,039 - 82,815 1,915 4b,1.2.34 Reactor E 903 Area2B iI - 167 52 272 272 - 741 66,518 929 4b.1.2.35 Reactor EC903 Area3A 3 52 - 14 90 90 553 - 22,464 618 41.1.2.38 Reactor EC903 Area3B 4b.1.2.37 Reactor EC903 Area4 9 136 43 223 223 606 54,373 776 3 52 14 90 90 558 22,692 597 4b,1.2.38 Reactor El 903 Area4B 3 52 20 104 164 232 20,858 670 41,1.2.39 Reactor E6931 ArealA 40 692 - 186 1,227 1,227 7.412 301,017 8,410 4b,1.2.40 Reactor El931ArealB 2 35 14 74 74 - 154 13,824 544 4b.1.2.41 Reactor E 931 Amea2A 0 I 0 1 3 3 9 0 371 53 4b.1.2.42 Reactor El 931 Area2B 22 336 109 567 567 1,651 134,007 2,165 41,1.2.43 Reactor EC931 Area3A 1 8- 340 49 4b.1.2.44 Reactor El 931 Area3e 0 1 3 3 4 28 767 41.1.2.45 Reactor EC631Aea4C 1 8 - - 213 4b.1,.2.46 Reactor El 931 Area5C 10 149 54 278 278 662 59,432 1,472 4b.,1.2.47 Reactor EC959 ArealA 16 281 - 87 554 554 3,009 122,212 4,693 4b1,12.48 Reactor El 958 ArealB 4b1.1 .49 Reactor EC958 Arem2A 10 - 153 49 253 253 - 681 61,083 080 1 12 7 6 37 37 125 33 8,024 263 41b1.2.50 Reactor El 958 Area2B 3 48 21 109 109 214 19,185 898 4b.1.2.51 Reactor El 958 Area3A 1 10 6 7 39 39 109 29 7,011 410 4b.1.2.52 Reactor El 958 Afem3B 41b1.2.53 Reactor El 976 ArealA 1 16 7 36 36 72 6,482 298 25 422 104 703 703 4,521 183,615 3,931 4b.1.2.54 Reactor El 976 ArealB 1 13 5 26 26 57 5,136 172 4b.1.2.55 Reactor El 976 Area2A 3 55 - 18 114 114 586 23,813 1,033 4b.1.2.56 Reactor El 976 Arma2B 3 - 50 23 118 116 - 222 19,878 1,004 4b.1.2.57 Turbine 8SU2 ArealA 87 1,490 - 335 2,313 2,313 15,948 647.659 11,113 4b.1.2.58 Turbine El 812 AreamB 2 - 29 13 67 67 - 129 11,556 984 4b,1.2.59 Turbine El 812 Area2A 4b.1.2.60 TurObn El 892 Area2B 22 374 - 112 721 721 4,006 162,678 5,781 4b.1.2.61 Turbine C 882 Area3A 1 - 23 10 52 52 101 9,017 451 145 2,478 - 548 3,805 3,805 26,533 - 1,077,531 17,302

.3.62 Turbine EC882 Area3B 4b1,2 4b.1.2.63 Turbine EC903 ArealA I - 15 6 32 32 S 6988 6,127 232 TLG Services, Inc.

CooperNuclear Station DocumentN01-1590.002, Rev. I Decommissioning Coast Analysis Appendix C, Page 21 of 35 Table C-2 Cooper Nuclear Station 2014 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sits LLRW NRC Spent Fuel Sits Processed Burial Volumes Burial I Utilty and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Tanm. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor SIndex Activt'y Description Cost Cost Costs Costs Costs Costs Costs Continocv Costs Costs Costs Costs Cu. Foot Ca CFoFt Co.Foal Cu. Feet Co. Feet WI. Lbs. Manhours Manhours Disposal of piord Systems (contnued) 4b.12.64 Turbine El 903 ArealB 974 46 241 4.133 " 904 6,299 6,299 44,251 1,797,054 27.874 4b.1 .2.65 Turbine El 903 Area2A 5 1 1 4 20 20 - - 42 3.729 142 4b. 1.2.66 Turbine El 903 Area2B 144 1 7 128 56 337 337 1,375 55,851 4.040 4b. 1.2.67 Turbine El 903 Area3B 3 0 2 35 9 47 47 S

- 376 15,251 97 4bd1.2.68 Turbine El 903 Area3C 108 19 124 - 124 - - 3,412 4b.1.2.69 Turbine El 903 Ae&a4B 12 0 2 29 7 49 49 299 12,139 367 4b.1.2.70 Yard AreaiC 197 30 227 - 227 - - 5,770 4b.1 .2 Totals 7,771 556 1,148 13,202 5,814 5,535 34,027 33,227 o00 141,342 27,486 8,056,388 218,627 4b.1.3 Scaffolding in support of decommissioning - 3,073 36 17 252 34 821 4,232 4,232 2,431 151 122,986 41,117 Decontamination of Site Buildings 4b.1.4.1 Readsr 2.880 1,820 202 422 4,911 2.376 3,310 15,922 15,922 52,579 39,538 6,069,283 115,053 4b.1.4.2 Augmented Radwuast 52 19 4 6 23 60 51 215 215 242 1,099 119,386 1,978 4b.1.4.3 Miscetanleous Strutures - Contaminated 368 167 15 42 759 62 363 1,777 1,777 8,129 452 372,774 12,956 41.1 4.4 MuS-Purpose Facility 68 55 6 12 115 89 90 437 437 1,234 1,567 205,066 3,237 4b 14.5 Radwasto 159 50 9 14 38 161 141 572 572 404 2,953 310,769 5,9963 41,4.6 Turbine 526 142 35 51 64 633 477 1,928 1.928 688 11,664 1,193,496 18,679 4b.1.4 Totals 4,055 2,253 271 547 5,910 3,382 4,432 20,850 20,850 63.275 57,271 8,270.774 157,766 4b.1 Subtotal Period 4b ActivityCosts 4,318 13,131 942 1,800 19,364 10,578 11,285 61,417 60,618 800 207.048 90,895 16,987.290 418,513 Period 4b Addiaonal Costs 49.2.1 ISFSI Decontamination 656 4 24 55 1.192 369 2,290 -. 2,290 * - 1,050 162,629 17,515 2,560 4b.2.2 Final Site Survey * - - 1,205 362 1,567 1,567 - - 12.480 4b.2 Subtotal Period 4b Additional Costs 656 4 24 55 2.397 722 3,857 1,567 2,290 1.050 162,829 17,515 15.040 Period 4b Collateral Costs 4b.3.1 Process liquid waste 128 - 45 238 271 172 853 853 945 56,728 184 4b.3.2 Swall tool allowance 230 35 265 265 40.3.3 Decommissioning Equipment Disposition - - 99 50 62.1 94 130 973 973 6.000 373 303,507 88 4b.3 Subtotal Period 4b Collateral Costs 128 230 133 287 621 355 337 2,091 2,091 69000 1.319 360,233 272 Period 49 Period-Depondent Costs 4b.4.1 Decon supplies 1,252 - 313 1,594 1,564 4b.4.2 Insurance - 1,192 119 1,312 1,312 4b.4.3 Property tares - 10 1 11 11 4.4.4 Health physics supplies 2,373 593 2,966 2,968 4b.4.5 Heavy equipment rental 4,270 641 4,911 4,911 4b.4.6 Disposal of DAWgenerated - 55 31 876 - 229 1,191 1,191 18.832 172,741 58 4b.4.7 Plant energy budget - 1,691 254 1,945 1.945 4b.4.8 NRC Fees 1,601 160 1,761 1,761 4b.4.9 Liquid Radwaste Processng Equipment/Seruices 913 137 1,049 1,049 4b.4.10 Security Staff Cost 6.945 1,042 7,987 7,987 158,571 4b.4.11 DOC Staff Cost 24.622 3,693 28,315 28.315 339.977 4b.4.12 Utity Staff Cost 33,080 4,992 38,042 38,042 598,766 4b.4 Subtotal Period 49 Period-Dependent Costs 1,252 6,43 55 31 879 70,053 12,144 91,053 91,053 18,832 172,741 59 1,097.314 4b.0 TOTALPERIOD 4b COST 5.697 20.681 1,134 2,141 19,985 11,863 72,450 24,487 158,419 155,329 2,290 800 213.046 112.096 17,682,890 436,358 1,112,354 PERIOD 4* - License Termination Perod4o Direct Decommissioning Activities 4e. 1.1 ORISE confinrutary survey 147 44 191 191 4e.1.2 Tenninatolicense 4e. 1 Subtotal Period 4e ActivityCosts 147 44 191 191 TLG Services, Inc.

Cooper Nuclear Station Docuentes NOI.1590-002, Revr.I Decommsosioninaog Cast Analyasi Appeadiv C, Page 22 vf385 Table C-2 Cooper Nuclear Station 2014 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utilityand Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic.Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activit Description Cost Cost Costa Costs Costs Costs Costa Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feat Cu. Feet WL.Lbs. Manhours Manhours Period 4e AddiStonalCosts 4e.2.1 Final Site Survey * . . - 5.998 1,799 7,797 7,797 165,605 6,240 4e.2 Subtotal Period 4e Additional Costs * - . . . 0,900 1,799 7.797 7,797 165,605 6.240 Period 4e Collateral Costs 4e.3.1 DOC staff relocation expenses 912 137 1,049 1,049 4e.3 Subtotal Period 4o Coiateral Costs 912 137 1,049 1,049 Period 4e Period-Dependent Costs 4e.4.1 Insurance 4e.4.2 Property taxes 3 0 3 3 4e.4.3 Health physics supplies 795 - - 199 993 993 4e.4.4 Disposal of DAWgenerated 3 1 42 - 57 57 907 8,324 3 11 4e.4.5 Plant energy budget 140 21 161 161 4e.4.6 NRC Fees 532 53 585 585 4e.4.7 Security Staff Cost 1,012 152 1,164 1,164 18.857 4e.4.8 DOC Staff Cost 4,458 669 5,126 5.126 57,357 4e.4.9 UtilityStaff Cost - 4,895 704 5,399 5,399 - - 74,643 4e.4 Subtotal Period 4e Perrod-Dependent Costs 795 3 1 42 10,839 1,809 13,489 13,489 907 8.324 3 150,857 4e.0 TOTAL PERIOD 4e COST 795 3 1 42 17,697 3,789 22,527 22,527 907 8,324 165.608 157,097 PERIOD 4 TOTALS 5,939 37,086 8,022 4,771 37.066 30,870 124,205 51,016 298,974 295,786 2,290 897 384,277 156,617 1,377 344 508 28,309,950 757,775 1,797,669 PERIOD Sb - Site Restoraion Period 5b Direct Decommissioning Activities Demolition of Remrainig Site Buildings 5b 1.1.1 Reactor 1,491 224 1,715 1,715 14,601 5b. 1.12 Augmented Radwaste 222 33 255 255 - 2,119 5b.1.1.3 Control 214 32 246 246 1,655 5b. 11.4 Intake Structure 523 78 602 602 5,621 5b.1.1.5 LLRW Sturage Pad 145 22 167 167 1,227 5b 1.1.6 Miscet-,eous Structures -Clean 1,196 179 1,375 1,375 11,837 5b.1 .1.7 Miscellaneous Stuctums - Contaminated 27 4 30 30 572 56.1.1.8 Mutt-Purpose Faciity 123 10 141 141 1,982 5b.1.1.9 OWC Gas Generator s1 3 20 20 283 5b.1.1.10 Office 156 23 179 179 1,920 5b.1.1.11 Radwaste 391 59 449 449 3,229 5.1.1.2 Seal Well 17 3 20 20 166 5b.1.1.13 Sewage Treatment Area 4 1 5 5 53 5b.1.1.1.4 TransformnerYard 20 3 24 24 172 5b.1.1.15 Turbine 2,596 389 2,985 2,985 40,503 5b.1.1.16 Turbine Pedestal 277 42 318 318 2,100 5b.11 Totals 7,418 1,113 8,531 8,531 88,040 Site Closeout Activites 51.1 .2 Reonoe Rubble 424 64 488 488 3,286 5b. 1.3 Grade &landscae site 578 87 665 665 1,578 5b. 1.4 Final report to NRC 156 23 179 179 -

• 1,560 8,421 156 1,286 9.863 179 92.904 1,560 5b. 1 Subtotal Period 5b ActivityCosts 9.684 Period 5b Additional Costs 487 611 611 -

5b.2.1 ISFSI Demolition 80 4,336 160 5b.2.2 Concrete Crushing 499 76 582 5a2 3,1045 5b.2.3 Cofferdam 458 69 527 527 5,130 TLG Services, Inc.

Document N01.1590-002, Rev. 1 Cooper NuclearStation Decommisiwoning Coast Analysis Appendix C, Page 23 of"35 Table C-2 Cooper Nuclear Station 2014 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lit. Torm. Management Restoration Volume Class A Class 8 Class C GTCC Processed Craft Contractor index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet WLI Lbs. Manhours Manhours 5b.2 Subtotal Period 5b Additional Costs 1.444 52 224 1,720 611 1,109 12,511 160 Perod 5b Collateral Costs 5b.3.1 Smut tool alnwurnce 55 8 63 63 55 8 63 63 5b.3 Subtotal Period 5b CoUateral Costs Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property tanes - 7 1 8 8 5b.4.3 Heavy eq.ipment rental 4,233 - 635 4,869 4,869 5b.4.4 Pltat energy budget - 167 25 192 192 5b.4.5 Security StuffCost 2.419 363 2,782 2,782 45,051 5b 4.6 DOC Staff Cost 10,212 1.532 11,744 11,744 127,646 5b.4.7 UtilityStuff Cost - 4.507 676 5,183 5.183 73,209 5bA Subtotal Period 5b Perlod-Dependent Costs 4,233 17,312 3.232 24,777 - 24,777 - 245.906 50.0 TOTALPERIOD 5b COST 14,153 17,520 4.751 36,424 179 611 35,634 105.415 247,626 PERIOD 5 TOTALS 14,153 17,520 4.751 36,424 179 611 35,634 105,415 247,626 TOTAL COST TO DECOMMISSION 13,111 58,437 8,282 5,692 37,066 34,071 545,635 120,307 922,600 475.790 309,463 37,347 384,277 207,449 1,377 344 508 28,976,590 994,325 6.844,054 TOTALCOST TO DECOMMISSION WITH17.13% CONTINGENCY: $822,600 thousands of 2008 dollars TOTALNRC LICENSE TERMINATIONCOST IS 57.84%OR: $479,790 thousands of 2008 dollars SPENT FUEL MANAGEMENTCOST IS 37.62% OR: $309,463 thousands of 2008 dollars ON-NUCLEAR DEMOLITIONCOST IS 4.64% OR: $37,347 thousands of 2008 dollars TOTALLOW4.EVEL RADIOACTIVEWASTE VOLUME BURIED (EXCLUDING GTCC): 209,171 cubic feet TOTALGREATER THANCLASS C RADWASTE VOLUMEGENERATED: 508 cubic feet TOTALSCRAP METAL REMOVED: 30,276 tons TOTALCRAFT LABOR REQUIREMENTS: 994,329 tnan-hours End Notes:

n/a - indicates that this activity not charged as decommissioning expense.

a - indicates that this activity perorrmed by deconmmissioning staff.

0 - indicates that this value is less than 0.5 but is ron-zero.

a cell contaihing"*. indicates a zero value TLG Servicea, Inc.

Coaoper Nuclear Station Document N01-1590-00 Rev. I DecommissionaingCastAnalaysis Appendix C, Page 24 of 35 Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommuissioning Cost Estimate (thouisands of 2008 dollars) m Off-Sit. LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Torm. Management Restoration Volume Clan A Class 5 Claws C GTCC Processed Craft Contractor IAct ity Cost Cost Costs costs Contlngency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Fast Wt. Lbs. Manhours Manhours I Index Actlvltv Descriotlon PERIOD Is - Shutdown through Transition Period Ia Direct DecommissioningActivities la.1.1 SAFSTOR nile characterization su0sy 346 104 450 450 la.1.2 Prepare preliminary decrimissioning cost 130 20 150 150 1,300 la.1.3 Notificationof Cessatos of Operations la.14 Remove fuet & sourte material a la.1.5 Notificationof Permanent Defueling la.1.6 Deactivate plant systems &process waste a la.1.7 Prepare and submit PSDAR 200 30 230 230 2,000 ta.1.8 Reoiewplant dwgs & specs. 130 20 100 150 1,300 ta.1.9 Perform detailed rod survey Iai.10 Estirate by-product inventory 100 15 110 115 1,000 la.1.11 End product descrption 100 15 115 115 1,o00 la.1.12 Detailed by-product inventory 150 23 173 173 1,500 ta.1.13 Defne major work sequence 100 15 115 115 1,000 ta.1.14 Perform SER and EA 310 47 357 357 3,100 1 8.1.15 Perform Site-Specific Cost Study 500 75 575 575 5,000 Activity Specifcations Ia:l.1..l Prepare plant and facilities for SAFSTOR *. 492 74 560 566 4,920 Ia.1.16.2 Plant systems 417 63 479 479 4,167 la.1.16.3 Plant structures and bu0l0ings 312 47 359 359 3,120 Ia.1.16.4 Waste management 200 30 230 230 2,000 la.1.16.5 Facility and site dormancy -- 200 30 230 230 2,000 la.1.16 Total *- 1,621 243 1,864 1,884 16,207 Detailed Work Procedures la.1.17.1 Plant systems * . - - - - I11 15 136 130 - - 1,183 la.1.17.2 Facility losout & dormancy - . . . - - 120 15 138 138 - - 1,200 ta.1l17 Total * - * -238 36 274 274 - - - 2,383 1 8al Procure vacuum drying system 10 2 12 12 * - 100 t1o s19 Draundde-energize nos-cont. systems ia.120 Dman &dry NSSS t.1.21 Drain/de-energize cortaminated systems a la.l.22 Decoofsecure contaminated systems 3,930 642 4,077 4,077 35,890 la.t Subtotal Period la Aztvity Costs Period ta Collateral Costs la.3.1 Spent Fuel Capital and Transfer 10,335 1,550 11,880 11,0006 1a.3.2 Corporate Overheads 3,105 468 3,570 3,570

-.3 Subtotal Period In Colateral Costs 13,440 2,016 15,456 3,570 11,886 Period ta Period-Dependent Costs la.4.1 Insurance 1,600 160 1,760 1.760 1:.4.2 Propety taxes 4 0 4 4 ta.4.3 Health physics supplies 370 93 463 463 1:.4.4 Heavy equipment rental 368 55 423 423 la.4.5 Disposal of DAWgenerated 73 - 19 100 100 1,575 14,445 5 la.4.6 Rant energy budget 927 139 1,068 1,060 10.4.7 NRC Fees 706 71 776 776 1t.4.8 Emergency Planning Fees 1,185 118 1,303 1,303 10.4.9 Spent Fuel Pool O&M 745 112 857 857 98 Ia.4.10 ISFSI Operating Costs 85 13 98 6,021 903 6,924 6,924 157,471 18.4.11 Securdy Staff COst TLG Services, Inc.

Cooper Nucleaor Staton~~ Docuerant NOI.1590.002, RemrI Deco~rnms,,aioniag Cc"l Analfysis Appenadix C, Page 25 of 80 Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utilty an0 Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Tenme Management Restoration Volume ClansA Class B Class C GTCC Processed Craft Contractor index Activity Descripton Cost Cost Costs Costs Costs Costs Costs Continuencs Costs Costs Costs Costs Cm.Feet Cu. Feet Cu. Feet Cu.Feet Cu. Feet WLtLbs. Manhours Manhour Period la Period-Dependent Costs (continued) 1a.4.12 Utiity Staff Cost

• 22,690 3.403 26,003 26,093 423.400 73 33.962 5,087 39,867 37,609 2,258 1,575 14.445 5 580,871 1a.4 Subtotal Period 1a Period-Dependent Costs 738 738 73 51.338 7,745 59.901 45,757 14.144 1,575 14.445 5 616,761 18.0 TOTAL PERIOD 10 COST PERIOD lb - SAFSTOR Limied DECON Activities Period 1bDirect Decommissioning Activities Decontamination o1Site Buildings lb.1.1.1 Reactor 2,929 1,465 4,394 4.394 68,438 26 78 78 1.562 lb.1.1.2 Augmented Radwaste 52 188 565 565 8,542 lb.1.1.3 Mlscetaneous Structures -Contaminated 370 34 101 101 2.036 lb.1 .1.4 Muit-Potose Facility 68 79 237 237 4,761 1b1.1.5 Radwaste 158 260 780 780 15.667 lb,1.1.6 Turbine 520 2,052 6,155 6,155 101,006 lb.1.1 Totals 4,103 2.052 6,155 6,155 I01.008 l1b.t Subtotal Period lb ActivityCosts 4.103 Period Ib Additional Costs lb.2.1 Spent Fuel Poci Isolat*on - - 9,407 1,411 10,818 10,815 1 65 558 265 1,662 1.662 10,333 134,329 10,002 b.,2.2 Asbestos Insulation Disposal 773 773 1 65 558 9,407 1,676 12,480 12,480 10,333 134.329 10,002 lb.2 Subtotal Period l b Additional Costs Period l b Collateral Costs lb.3.1 Dec0n equipment 713 - - 107 820 820 229 74 392 448 293 1,436 1.436 1,561 93,6344 304 lb.3.2 Process liquid waste lb3.3 Small tool allowance 70 - 11 91 81 Spent Fuel Capital and Transfer 1,510 227 1,737 - 1,737 lb.3.4 tb.3.5 Corporate Overheads - 766 115 880 0880 942 70 74 392 448 2,276 752 4,954 3,217 1,737 1,561 93,644 304 lb.3 Subtotal Period lb Collateral Costs Perod 1b Period-Dependent Costs Ib.4.1 Deco0 supplies 1,156 - 289 1,445 1,445 121 12 133 133 lb.4.2 Insurance

• - 1 0 1 1 lb.4.3 Property tanes lb.4A Health physics supplies 473 118 592 592 Ib.4.5 Heavy equipment rental 91 14 104 104 5 3 - 81 21 110 110 1,741 15,968 5 1b.4.6 Disposal of DAWgenerated lb,4.7 Rant energy budget 229 34 263 263 lb.4.8 NRC Fees 174 17 191 191 292 29 321 321 lb.4.9 Emergency Plannlig Fees Spent Fuel Pool O&M 184 28 211 211 I b.4.10 b1h4.11 ISFSI Operating Costs 21 3 24 - 24 1.485 223 1,707 1,707 - 38,829 lb.4 12 Security Staff Cost

- - 5,595 839 6,434 6,434 104,400 lb.4.13 Uidity Staff Cost 5 143,229 1,156 564 5 3 81 8,101 1.628 11,538 10,981 557 1.741 15,968 lb.4 Subtotal Period l b Pedtod-Oependent Costs 2,294 13,635 243,942 111,318 143,229 lb.0 TOTAL PERIOD lb COST 6,201 1,407 80 460 1,087 19,783 6,107 35,126 32,833 TLG Services, Inc.

CooperNuclearStation Document N01.1590-002,Rev. I Devommissioning Cost Analysis Appendix C, Page26 of 35 Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommrissioning Cost Estimate (thousands of' 2008 dollars)

Off-SIte LLRW NRC Spent Fuei Sit. Processed Burial Volumes Burial I Utilty and Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor IActiolty I Ind*Y A*VI* *cnnI*N Decon Cust Cust Costs Costs Costs Costs Costs Continoonnv Costs Casts Costs Costs Cu. Feet Cu. Feat Cu. Foot Cu. Feet Cu. Feet WL. Lbs. Manhours ManhoursI n ex iZ&66&Q;-.c ri n Cost Cost Costs costs Costs Costs Costs Costs Cu. Feet Cu.Feet Cu.Feet Cu.Feet Cu.Feet WL. Los. Manhours Manhoom PERIOD 1c - Preparations for SAFSTOR Dormancy Perod Ic Direct Decornmissiounir Activities Ic 1.1 Prepare suppotn equipment for storage 387 58 445 445 3,000 1C.1.2 Install containment pressure equal. lines 31 - 5 36 36 700 Ic.1.3 Interim survey prior to drmnnncy S- 733 220 953 953 15,696 lC.1.4 Secure building accesses 58 9 87 67 S- 583 lC.1.5 Prepare &submit inteim report lc.1 Subtotal Period lc Activity Costs 419 791 291 1,501 1,501 19,396 583 Period l1 Collateral Costs lc.3.1 Process liquid waste 235 76 403 460 301 1,475 1,475 1,603 96,196 313 tc.3.2 Smal tool allowance 3 0 3 3 1c.3.3 Spent Fuel Capital and Transfer I1,527 229 1,756 - 1,756 1c.3.4 Corporate Onerheads - 774 116 090 890 235 3 76 403 460 2,301 646 4,124 2,368 1,756 1,603 96,195 313 1c.3 Subtotal Period Ic Collateral Costs Penod lc Period-Dependent Costs 1c.4.1 Insurance 122 12 134 134 lc.4.2 Property taoes 1 0 1 1 1c.4.3 Health physics supplies 160 - 40 200 200 1c.4. Heavy equipment rental 92 - 14 105 105 1c.4.5 Disposal of DAWgenerated 1 . 1 18 - 5 20 25 393 3,601 1c.4.6 Plant energy budget 231 35 266 266 lc.4.7 NRC Fees 176 18 194 194 lc.4.8 Emergency Planning Fees 295 30 325 325 1c.4.9 Spent Fuel Pool O&M 1-6 28 214 214 lc.4.10 ISFSI Operating Costs 21 3 24 - 24 1c.4.11 Security Staff Cost 1,501 225 1,726 1,726 39,260 1c.4.12 Utlity Staff Cost 5,07 849 6,505 68505 105,560 252 1 1 18 8:191 1,257 9.720 9,157 563 393 3.601 1 144,820 1c.4 Subtotal Period 1c Period-Dependent Costs 1C.0 TOTAL PERIOD 1cCOST 235 673 77 404 478 11283 2.195 15,345 13,026 2,319 96,796 19,710 145,403 PERIOD I TOTALS 6,437 2,818 162 866 1,639 82.404 16,047 110,372 91,616 16.757 17,205 358,183 131,033 905,393 PERIOD 2a - SAFSTOR Dormancy with Wet Spent Fuel Storage Period 28 Direct Decommissioning Acvtindes 2a.1.1 Quarterly Inspoction 2a. 1.2 Semi-annuai ennironmental sutvey a 2a .1.3 Prepare reports 2a.1.4 Bituminous roof replacement 63 9 72 72 23.1.5 Maitemance supplies 503 126 629 629 30.1 Subtotal Period 2a Actioty Costs 566 135 701 701 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 26,466 3,970 30,435 - 30,435 - .-

2a.32 Corporate Overheads 4,139 821 4,759 4,759 2a.3 Subtotal Period 2a Collateral Costs 30.604 4,591 35,195 4,759 30,435 - -

Period 2a Period-Dependent Costs 2a.4.1 Insurance 1,962 196 2,158 1,845 310 . -

23.4.2 Property tanes -8 16 2 18 18 2a.4.3 Health physics supplies 344 86 430 430 TLG Services, Inc.

Doumnent NOI.1590-002, Re-. I Cooper NucLear Station Appendix C, Page 27 of 35 Dectumissiaoniag Cost An~alysis Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommrissioning Cost Estimiate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel site Processed Burial Volumes Burial I Utilty and Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class 8 Class C GTCC Processed Craft Contractor II Actinvy*

FRQ*X ACtlV* *ZCrlD*N Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet C e.et Cu. Feet Cu. Feet Wt, Lbs. Manhours Mlianhours n as c v scr Pit n Period 2s Period-Dependent Costs (coninued) 2a4.4 Disposal of DAW generated 13 198 - 52 270 270 4,267 39,138 13 742 111 853 427 427 2a.4.5 Plant energy budget 807 81 887 887 2A.4.6 NRC Fees 3,374 337 3,712 - 3,712 28.4.7 Emergency Planning Fees 2a,48 Spent Fuel Pool O&M 2,984 448 3,431 3,431 340 51 391 - 391 2a.4.9 ISFSI Operating Costs 444,561 17,728 2,659 20,387 7,788 12,599 2a.4.10 Security Staff Cost 329,769 18.816 2,822 21.639 4,426 17.213 2a.4.11 UtilityStaff Cost 39,139 13 774,330 344 13 198 46768 6,845 94.176 16,092 38,083 4,267 2a.4 Subtotal Period 2a Pedod-Oependent Costs 344 198 77,939 11.571 90,072 21,553 68,519 4,287 39,139 13 774,330 2a.o TOTAL PERIOD 2a COST 13 PERIOD 2b - SAFSTOR Dormancy with Dry Spent Fuel Storage Period 2b Direct Decommissioning Activities 2b.1.1 Quarterly Inspecton a

25.1.2 Semi-annual envronmental suorey 2b.1,3 Prepare reports 2b.1.4 Bituminous roof replacement 432 65 497 497 25.1.5 Maintenance supplies 3,453 863 4,317 4.317 Subtotal Period 2b ActivityCosts 3,886 928 4,814 4,814 2b.1 Period 2b Collateral Costs 21.3.1 Spent Fuel Capital and Transfer 18,092 2,714 20,806 209806 18,092 2,714 20.806 20.606 2b.3 Subtotal Period 2b Colatsral Costs Period 2b Peiod-Dependent Costs 11,977 1,198 13,174 12,683 491 2b.4.1 Insurance 2b0.2 Property taoes 110 11 121 121 1,891 - 495 2,476 2,476 2b.4.3 Health physics supplies 250.212 84 80 44 1,268 - 332 1,725 1,725 27,278 2b.4.4 Disposal of DAWgenerated 2,546 382 2,928 2,928 2b.4.5 Plant energy budget 5,536 554 6,090 6,090 2b4.6 NRC Fees 23,161 2,316 25,477 25,477 2b.4.7 Emergency Plannug Fees 254.8 ISFSI Operating Costs 2,332 350 2.682 2,682 2b.4.9 Security Staff Cost 70,072 10,511 80,583 53.452 27,131 1.547,177 51,313 7.697 59,010 30,376 28,634 916,846 2b.4.10 UtilityStaff Cost 1.981 80 44 1,268 167,047 23,845 194,266 109,850 84.416 27,278 250,212 84 2,464,023 20.4 Subtotal Period 2b Pedod-Dependent Costs 2b.0 TOTALPERIOD 2b COST 1.981 8o 44 1.268 189,025 27,487 219,886 114,664 105.222 27,278 250.212 84 2,464,023 PERIOD2c - SAFSTOR Dormancy without Spent Fuel Storage Period 2c Direct Decomnissioning Activites 2C.1.1 Quarterly Inspection 2c.1.2 Semi-annual environmental survey a 2C.1.3 Prepare reports 2c.1.4 Bituminous roof epslacenmet 335 50 385 385 2c.1.5 Maintenance supplies 2,677 669 3,346 3,346 3,012 719 3.732 3,732 2c.1 Subtotal Period 2c ActivityCosts Period 2c Period-Dependent Costs 2C.4.1 Insurance 8,937 894 9.831 9,831 2C.4.2 Property taxes 85 9 94 94 2C.4.3 Health physics supples 1,444 - - 361 1.805 1,805 2c.4.4 Disposal of DAWgenerated 61 34 961 251 1,308 1,306 20.663 189,540 63 TLG Serviees, Inc.

CooperNuclearStation Document N01-1590-002, Rev. I Deeommaisionting Coat Analysis Appendix C, Page 28 of 35 Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed BurialVolumes Burlal I Utilityand Actvily Decon Removal Packaging Transport Processing Disposal Other Total Total Lic.Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Indei Acivit'yDescription cost Cost Costs Costs Costs Costs Coots Contintflsco Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet WL.Lbs. Manhtours Manhourn Period 2c Period-Dependent Costs (contnued) 2c.4.5 Plant energy budget 1,974 296 2,270 2,270 2c.4.6 NRC Fees

- - 3,866 389 4,275 4,275 2c.4.7 Security Staff Cost 36.028 5,404 41,432 41,432 666,257 2c.4.8 UtilityStaff Cost - 20,474 3,071 23,545 23,545 * - 388,650 1,444 61 34 961 71.384 10,675 84,558 84.558 20,663 189,540 93 1,054,907 2c.4 Subtotal Period 2c Petiod-Dependent Costs 2c.0 TOTALPERIOD 2c COST 1,444 61 34 961 74.396 11,394 68,289 88,289 20,663 189,540 63 1,054,907 PERIOD 2 TOTALS 3,769 154 85 2,427 341,360 50,452 398,247 224,506 173,740 52.208 478,891 160 4,293,260 PERIOD Sa. Reactivate Site FoUowing SAFSTOR Dormancy Period 3a Direct Decommissioning Activities 3a.1.1 Prepare preleninary decommissianing cMst 130 20 150 150 1,300 3a.1.2 Reniew plant dwgs &specs. 460 69 529 529 4,600 3a 1.3 Perform detailed rad survey 30.1 4 End product descrption 100 10 115 115 1,000 30.1.5 Detaied by-product inventory 130 20 150 1O0 1,300 3a.1.6 Deline malor work sequence 750 113 863 663 7,500 3a.1.7 Perform SER and EA 310 47 357 357 3,100 3a.1.8 Perform Site-Specific Cost Study 500 75 575 575 5,000 3a.1 .9 Prepare/subrldt Ucerrse Termination Plan 410 61 471 471 4,099 3aI1AO Receive NRC approval of terrtinatkin plan a Activity Specifications 3a.1.11.1 Re-activate plant &temporary facilities 737 111 846 763 7,370 3a.1.11.2 Plant systems 417 63 479 431 4,167 3a.1.11.3 Reactor internals 710 107 817 817 7,100 3a 1.11.4 Reactor vessel 650 98 748 748 6,500 3a.1.1. 5 Sacrfiioal Shield 8 58 58 500 3a.1.11.6 Moiture saparators/reheatem 100 15 115 115 1.000 3a 111.7 Reinforced concrete 160 24 184 92 92 1,600 3a.01116 Main Turbine 209 31 240 240 2,088 3 111s MaeinCondersers 209 31 240 240 2,018 3a. 1.11.10 Pressure Suppresson structure 200 30 230 230 23000 3a. 1.11.11 Drywl1 -- 160 24 184 164 1,600 3a.1.11.12 Plant Structures & bulidings 312 47 359 179 179 3,120 3a, 1.11.13 Waste management 460 69 529 529 4,600 3a11.1-14 Facility & site closeout 14 104 52 52 900 3a.1.11 Total 4,463 669 5,133 4.677 456 44,633 Planning & Site Preparations 3a.1.12 Prepare dismantrng sequence 240 36 276 276 2,400 3a.1.13 Plant prep. & temp. sVces 2,700 405 3,105 3,105 3a.1.14 Design water dean-up system 140 21 161 161 1,400 3a.1.15 Rigging/Coot Cntrl Envlps/tooling/etc. 2,100 315 2,415 2,415 3a.1.16 Procure casksflaters & containers 123 16 141 141 1.230 3a. 1 Subtotla Period 3a Activity Costs 12,558 1,883 14,439 13,983 456 77,559 Period 3a Period-Dependent Costs 3a.4.1 Insurance 420 42 462 462 3a.4.2 Property tames 4 0 4 4 3a.4.3 Heala physics supplies 324 81 405 405 30.4.4 Heavy equipment rental 368 55 423 423 3a.4.5 Disposal of DAW generated 2 62 16 84 84 - 1,329 12.190 TLG Services, Inc.

Cooper Nuadear Sationuo Do sumentN01.1590-002,Rev. I Appendix C, Page29 of"35 Decommissioninsg CoadAnialysis Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars) m Off-Sit. LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utilty and IActivity Decon Removal Packaging Transport Processing Disposal Other Total Total Li. Termn. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor I Index Actlvits Descriotonn Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu.Feet Cu. Feet Cu. Feet Cu. Feet WLt.Lbs. Manhours Manhour I Index Actlvltv Description Period 3a Pefiod-Dependent Costs (continued) 3a.4.6 Plant energy budget 927 139 1,066 1,966 249 25 274 274 3a.4.7 NRC Fees 65,179 2.855 428 3,283 3,283 3a.4.8 Security Staff Cost -

• 258,629 3.4.9 UWilyStaff Cost - 14,190 2.128 16,318 16,318 2,915 22.318 22,318 1,328 12,190 4 323.807 3a.4 Subtotal Period 3a Penod-Dependent Costs 691 4 62 18,644 36,302 456 1,329 12,190 4 401,366 3s,0 TOTAL PERIOD 3a COST 691 4 62 31.200 4.799 36,758 PERIOD 3b - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 473 71 544 490 54 4.733 3b.1.1.1 Plant systems 4,000 3b.1.1.2 Reactor ilternals 400 60 460 460 20 155 39 1,350 3b.11.3 Remaining buildings 135 100 15 115 115 1,000 3b.1.1.4 CRD housngs & NIS 1,000 3b.1.1,5 Ilncoreinstrumentation 100 15 115 115 200 30 230 230 2.000

3. I.1 .6 Removal primawyconitainrent 3.630 363 54 417 417 3b51.1,7 Reactor vessel 1,200 120 18 138 69 69 3b.1.1.8 Facilitycloseout 1.200 30.1.1.9 Sacrifcial shield 120 18 138 138 "58 1.000 100 15 115 58 3b.1.1.10 Reinforced concrete 2,080 35*1.1.11 Man Turbine 208 31 239 239 240 2,088 3b. 1.112 Man Condensers 209 31 240 30 230 230 2,000 3b 1.1.13 Moisture separatos & reheaters 200 41 314 283 31 2,730 3b.1.114 Ratwaste building 273 273 41 314 283 31 2,730 3b.1.1.15 Reactor bulding 3,274 491 3,765 3,405 360 32,741 3W.1.1 Total 32,741 3b, 1 Subtotal Period 3b Activity Costs 3,274 491 3,785 3,405 Period 3bAdditionsalCosts 3b.2.1 Site Characterization - -- - - . 5,395 1,619 7,014 7,014 3b.2 Subtotal Period 3b Additional Costs - - - - 5,395 1,619 7,014 7.014 Period 3b Collateral Costs 3b.3.1 Deown equipment 713 107 820 820 3b.3.2 DOC staff relocaton expenses 912 137 1,049 1,649 3b.3.3 Pipe cutting equip-met - 1.000 150 1.150 1,150 713 1,000 912 394 3.019 3,019 3b.3 Subtotal Period 3b Couataral Costs Period 35 Perind-Dependent Costs 3b.4.1 Decwn supplies 22 5 27 27 3b.42 Insurance 248 25 270 270 Property tanes 2 0 2 2 3b.4.3 3b.4A Health physics supplies 179 45 224 224 3b.4.5 Heavy eciuipment rental 184 28 212 212 35 9 48 48 754 6.913 2 3b.4.6 Disposal of DAWgenerated 2 3b.4.7 Plant energy budget 465 70 534 534 3b.4.8 NRC Fees 125 12 137 137 1,431 215 1,646 1,646 32,679 3b.4.9 Security StaffCost 58,560 3b.4.10 DOC Staff Cost 4,378 657 5,035 5,035

- 7,114 1,067 8.181 8,181 - 129,669 3b.4.11 Staff Cost tLility 6,913 2 220,907 22 363 35 13,761 2,133 16,317 16,317 754 3b.4 Subtotal Period 3b Period-Dependent Costs TLG Services, Ian.

Cooper Nuclear Station Document N01-1590-002, Rev. I DecommissioningCoast Analysis Appendix C, Page 30 f835 Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial / Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Li, Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costa Contingenca Costs Costs Costs Costs Cu. Feel Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt Lbs. Manhtours Manhours 3b.0 TOTAL PERIOD 3b COST 735 1.363 2 1 - 35 23,342 4,636 30,115 29,755 360 - 754 - 6,913 2 253,648 PERIOD 3 TOTALS 735 2.055 6 3 97 54,542 9,435 66,872 66,056 816 2,083 19.104 6 655,014 PERIOD 4a - Large Component Removal Perod 4a Direct Decommissioning Acvlities Nuclear Steam Supply System Removal 4a.1.1.1 Recirculation System Piping &Valves 16 70 14 13 127 151 86 477 477 499 499 115,643 2487 4a.1.1.2 Recirculation Pumps & Motors 6 28 11 26 321 95 488 488 1.188 132,880 1.125 4a.1.1.3 CRDM & Nis Removal 24 139 377 68 317 - 174 1,099 1,099 6.935 - - 126,494 3,972 -

4a. 11.4 Reactor Vessel Internals 60 1,876 3,729 727 4,679 142 4,912 16,126 16,126 2.181 1,377 344 - 361,669 17,025 813 4a.1.1.5 Vessel &Internals GTCC Disposal - - - 7.470 - 1,120 8,590 8,590 - - 508 89.497 - -

4a.1.1.6 Reaotor Vessel 4,972 813 351 3.006 142 5,544 14,826 14,828 14,106 * - 1,447,089 17,025 813 4a.1.1 Totals 106 7.085 4,945 1,185 127 15.944 283 11,932 41,608 41,608 499 24,908 1.377 344 508 2,273,272 41,634 1.626 Removal of Major Equipment 4a. 1.2 Main Turbine/Generator 167 845 372 6,376 -

• 1,138 8,898 8,898 61,604 2.772,179 4,438 4a.1.3 Main Condensers 708 588 259 4.439 940 6,932 6,932 42,889 1,930,000 19,519 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor 260 39 299 299 2.486 4a.1.4.2 Augmented Radwesto 25 4 28 28 235 4a.0143 Radwaste 43 7 50 50 359 4a.1.4.4 Turbine 285 43 326 328 4,419 4a. 1.4 Totals 613 92 705 705 7,498 Disposal of Plant Systems 4a.1.5.1 Augmented Ridwaste El 877 ArealA 203 28 28 432 166 857 657 2,055 172,205 5,668 4a.1.5.2 Augmented Radwaste E1903 ArealA 66 6 7 104 44 228 228 469 41,606 1,42 4a.1.5.3 Augmented Radwaste El 918 ArealA 52 10 9 139 50 260 260 765 55,345 1,432 4a.1.5.4 Augmented Radwastse 6929 ArewlA 21 4 5 - 73 25 127 127

• 324 29,038 579 4a.1.5.5 Augmented Radwaste 6i 929 AresI B 3 0 0 4 - 1 8 8 386 1,529 75 4a.1.5.6 DRYWELLArealA 457 65 84 - 1,289 458 2,373 2,373 5,726 513,627 12,634 40.1.5.7 DRYIOLL AreaIB 112 1 5 75 2 41 235 235 806 10 33,578 3,384 4a.1.5.6 Turbine El 932 ArelB 324 16 86 1,477 317 2,220 2,220 - 15,808 641,963 9,170 4a.1.5.9 Turbine El 932 Area2C 8 1 9 9 . 237 4a.1.5.10 Turbine El 932 Area3C 67 - - - 10 78 - 78 - - 2,083 4a.1.5.11 Yard ArealB S18 50 264 4,517 852 6,201 6.201 - 48,365 - 1,964,114 14,340 40.1.5 Totals 1,831 202 487 6,073 2,040 1,964 12,597 12,510 87 65,016 9,348 3,453.003 51,444 4a. 1.6 Scaffolding in support of decomniesioning 2,049 24 11 168 23 547 2,821 2,821 1,621 101 81,992 27,411 4a.1 Subtotal Period 4a ActivityCosts 100 12.451 6,604 2,314 17,183 18,007 283 16,614 73,561 73,474 87 171,628 34,358 1,377 344 508 10,510,450 151,944 1,626 Period 4a Collateral Costs 4a.3.1 Process liquid waste 38 - 14 76 86 53 268 268 301 18,078 59 4a0.32 Smatl tool allowance 87 13 101 91 10 4a.3 Subtotal Period 4a Collateral Coos 38 87 14 76 86 66 368 358 10 301 18.076 59 Period 4a Period-Depnent Costs 40.4.1 Deoon supplies 47 12 59 59 4a.42 Insurance 526 53 579 579 4a.4.3 Property loaes 4 0 5 4 0 4a.4.4 Health physics supplies 914 228 1,142 1,142 4a.4.5 Heavy equipment rental 1,899 285 2,183 2.183 TLG Servcees, Inc.

Cooper Nauclear Station Documenert NOI.1590-002, Rev,. I Deeomminioninebg Cost Analysis Appendix C, Page 31 of 35 Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sit LLKW NKC Spent fuel Site Processed Burial Voltumes Burial i Utility ana Decon Removal Packaging Transport Processing Disposal Other Total Total LIc. Term. Management Restoration Volume Closs A Class B Class C GTCC Processed Craft Contractor I J

m IActivity

[gDBX *UVIIV

• r [M[*ll Cost Cost Costs Costss cosCoost ts s s Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet WL, Lbs. Manhours Manhtum I n ex Perid 4a Period-Dependent Costs (contrmod) 4a.4.6 DisposalofDAW generated 25 14 395 103 537 537 8,501 77,973 26 946 142 1,087 1,087 4a.4.7 Plant energy budget 707 71 779 778 4a.4.8 NRC Fees 4a.4.9 Liquid Radwaste Processng Equipmnnt/Sevices 403 60 463 483 3,066 460 3,526 3,529 70.000 4a.4.10 Security Staff Cost 154,560 11,154 1,673 12,828 12,828 4a.4.11 DOC Staff Cost - - 280,000 15,348 2,302 17,650 17,850 4a.4.12 UltilityStaff Cost 77,973 26 504,560 25 14 395 32,154 5,390 40.837 40,837 0 - 8,501 4a.4 Subtotal Period 4a Period-Dependent Costs 47 2,812 22,070 114K767 114,669 97 171,628 43.159 1,377 344 508 10,906,5O0 152.029 506.186 4a.0 TOTALPERIOD 4a COST 191 15.351 6.643 2.404 17,183 18,488 32,437 PERIOD 4b- Site Decontamination Period 4b Direct Decommissioning Acdivities 4b.1.1 Remove spent fuel racks 262 33 79 88 1.348 498 2,308 2.308 5,989 537,141 1,004 Disposal of Plant Systems 4b.1.2.1 Controtl a 882 AMal1 280 39 674 178 1,178 1,178 - 7,213 292,908 7,797 25 195 195 5,155 4b. 1,22 Control al903 ArealC 170 It 10 76 76 2,100 4b.11.3 Controa El918 AmalC 22 3 28 26 702 4b. 1.2.4 Control Cl932 Areal C 101 15 118 116 - 3,136 4b.1.2.5 Intake 103.862 5,430 198 3 14 239 88 541 541

• 2,558 -

4b.1.2.6 MuS-Purpose Facility 398 75 62 949 353 1,836 1.836 5,097 377,917 10.930 4b.12.7 Radwase El 877 ArealA 9 7 613 44,992 1,189 4b.1.2.8 Radwasta a 877 Asa2A 43 113 41 213 213 79,983 1,969 4b.1.2.9 Radwaste C 877 Ama3A 71 18 13 201 72 372 372 1,158 110 9 10 153 68 351 351 684 61.153 3,015 4b,12.10 RadwastEa l 903 AralA 188 36 29 439 165 856 856 1,955 175,093 5,282 4b.1.2.11 Radwasts El 903 Ara2A 37 8 7 104 37 190 190 453 41,366 1,029 4b.1.2.12 Rdwaute El 903 Area3A 18 2 2 30 12 64 64 135 12.033 477 4b.1.2.13 Radwaste E 918 AralA 15,667 448 16 3 3 39 15 75 75 201 41.1.2.14 RawwasteB 918 Ama2A 185 23 22 338 136 705 705 1,690 134,827 5,045 4b.1.2.1 5 Radwast B StsAea3A 266 26 4 60 22 115 115 23,735 680 4b.1.2.16 Radwasts El 934 ArelA 98 11 12 177 72 370 370 808 70,665 2.663 4b.1.2.17 Radwaste C 934 Ama2A 7 9,381 305 12 2 24 9 47 47 105 4b.1.2.18 RadwastaEl 949 AealA 48,175 1,261 4b.1.2.19 Reactod al 1001 ArealA 5o 8 121 45 230 230 157 689 537 27,979 1,681 4b.1.2.20 Reactor El 1001 ArealB 62 4 64 26 157 246 - 1,091 97,874 2,024 4b.1.2.21 Reactor El 859 ArealA 71 15 16 83 430 430 269 1,771 1,771 10.641 432,136 12,411 4b.1.2.22 Reactor El 859/AealR 440 11 58 994 72 25 26 401 125 648 648 - 1.780 159.714 2,094 4b.1.2.23 Reactor al859 Area2A 69 1 8 131 38 247 247 1,406 57.093 1,954 4b.1.2.24 Reactor El 859 Area2B 9 -

S 608 47 9 137 48 251 251 54,543 1,321 4b.1.2.25 Reactor E 859 Area3A 33 0 2 42 15 93 93 453 - 18.381 951 4b.1.2.26 Reactor 8599Area3B - 520 50 9 8 117 44 227 227 46.668 1,374 4b.1.2.27 Reactds 859 Area4A 17 0 2 31 9 59 59 331 13,424 476 4b.1.2.28 Reactor El 859 Area4B 104.381 1,798 e3 16 17 282 85 443 443 1,163 4b'1.2.29 Reactor El 859 AreaSA 442 37 0 2 41 19 98 98 17,962 1,087 4b.12.30 Reactor El 859Area5B 4b.1.2.31 Reactor a 903 ArealA 401 56 42 651 275 1,424 1,424 - 2.892 259,190 10,497 451 6 32 550 201 1,240 1,240 5,890 239,197 12,496 4b.1.2.32 Reactor El 903 ArealB 4b.12.33 Reactsr El 903 Ara2A 4 0 0 6 3 14 14 - 29 2,372 120 69 2 11 190 48 320 320 2,039 - 82,815 1.915 4b.1.2.34 Reactor El 903 Area2B 32 10 11 167 52 272 272 -

S 741 66,516 929 4b.1.2.35 Reactds E 903 Arwea3A 21 3 52 14 90 90 553 22,464 6189 4b.1.2.36 Reactor Ei 903 Area3S 1 27 8 9 136 43 223 223 - 686 54,373 776 4b.12.37 Reactor El 903 Ares4A 21 1 52 14 90 90 559 22,692 597 4b.12.38 Reactor E.903 Area4B 4b.1-2.39 Reactor E931 ArealA 25 3 3 52 20 104 104 -

S 232 20,858 970 TLG Services, Inc.

Cooper NuclearStation Document N01-1590-002, Rev. 1 Decommiasioning Coast Analysis Appendixv C,Page 32 of 35 Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utilityand Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie.Term. Management Restoration Volume Class A Class B Clans C GTCC Processed Craft Contractor Index Acltn Oescritlo Coot Coot Costs Coats coste coste Coste Continenco Costs Costs Coots Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet WL Lbs. Manhoum Manhours Disposal of Plant Systems (continued) 4b.12.40 Reactor El 931 ArealB 300 8 40 692 186 1,227 1,227 7,412 301,017 8,410 2 2 35 14 74 74 154 13.824 544 4b.1.2.41 Reactor El 931 Area2A 20 1 0 1 3 3 9 0 371 53 4b.12,42 Reactor El 931 Area2B 2 0 0 77 23 22 - 2336 109 567 567 - 1,651 134.007 2,165 4b.1.2.43 Reactor El 931 Area3A 0 0 1 3 3 340 49 4b. 1 2.44 Reactor El 931 Area3B 2 4 28 28 767 4b.1.2.45 Reactor El 931 Area4C 24 28 1 8

• 213 4b.1.2.46 Reactor El 931 Avea5C 7 9 10 149 54 278 278 662 59,432 1,472 4b.12.47 Reactor El 958 ArealA 56 3 16 281 87 554 554 3,009 122,212 4,693 4b.1.2.48 Reactor El 958 ArealB 167 10 10 12 153 49 253 253 681 61,083 880 4b.12.49 Reactor El 958 Area2A 31 1 1 12 7 - 6 37 37 125 33 8,024 263 4b,1.2.50 Reactor El 958 Area2B 10 48 21 109 109 -. 214 19,185 898 4b.1.2.51 Reactor El 958 Area3A 33 4 3 1 1 10 6 7 39 39 109 29 7,011 410 4b.1.2.52 Reactor Ea 958 Area3B 14 11 1 1 16 7 36 36 72 6.482 298 4b.12.53 Reactor Ea 976 ArealA 183.615 3,931 4b.1.2.54 Reactor El 976 Areat B 147 5 25 422 104 703 703 4,521 1 1 13 5 26 26 -. 57 5,136 172 4b.12.55 Reactor El 976 Area2A 7 1 3 55 18 114 114 586 23,813 1,033 4b.12.56 Reactor El 976 A.rea2B 37 3 3

• 50 23 116 116 222 19,878 1.004 4b.1.2.57 Turbine El 882 ArealA 37 388 335 2.313 2,313 15,948 647,659 11,113 4b.1,2.58 Turbin El 882 ArmoIB 16 87 1,490 2 2 29 13 67 67 -. 129 11,556 504 4b.1,2.59 Turbine El 892 Area2A 21 209 4 22 374 112 721 721 4.006 162,678 5,781 4b.1,2.60 Turbine El 882 Area2B 9,017 451 16 2 1 - 23 10 52 52 -. 101 40.1.2.61 Turbine El 892 Area3A 27 145 2,478 548 3,805 3,805 26,533 1,077,531 17.302 4b.1.2.62 Turbine El 882 Area3B 607

- 9 1 1 - 15 6 32 32 -

S 68 9,127 232 4b.1.2.63 Turbine El 903 ArealA 974 46 241 4,133 904 6,299 6,299 44,251 1,797,054 27.674 4b.1.2.64 Turbine El 903 ArealB 3,729 142 5 1 1 9 4 20 20 42 4b.1.2.65 Turbine El 903 Area2A 55,851 4,040 144 1 7 128 56 337 337 1,375 4b.12.66 Turbine El 903 Area2B 0 2 35 6 47 47 376 15,251 97 4b.12.67 Turbine El 903 Area3B 3 16 124 - 124 - 3,412 4b.1.2.68 Turbine El 903 Area3C 108 12 0 2 28 7 49 49 299 12,139 367 40.1.2.69 Turbine El 903 Area4B - 5,770 197 30 227 - 227 -

4b.1.2.70 Yard ArealC 556 1,148 13,202 5,814 5,535 34,027 33,227 900 141,342 27.486 8,056,388 218,627 4b0.12 Totals 7.771 3.073 36 17 252 34 821 4,232 4,232 - 2,431 151 122,988 41,117 4b. 1.3 Scaffolding in support of decomnonnl g Decontamination of Site Buildings 40,1.4.1 Reactor 2,880 1.820 202 422 4.911 2,376 3.310 15.922 15,922 52.579 39.536 6,069,283 115.053 19 4 6 23 60 51 215 215 242 1,099 119.386 1,978 40b.14.2 Augmented Radwaste 52 62 363 1,777 1,777 8,129 452 372.774 12,956 4b,1,4.3 Miscelaneous Structures - Contaminated 368 167 is 42 759 68 55 6 12 115 89 90 437 437 1234 1,567 205.066 3,237 4b,1.4.4 Muffi-Purpose Faccity 310,769 5.883 159 50 9 14 38 161 141 572 572 404 2.953 4b.1A.5 Radaste 526 142 35 51 64 833 477 1,928 1,928 688 11,664 1,193,496 18,679 4b.1.4.6 Turbine 4.055 2,253 271 547 5,910 3,382 4,432 20,950 20,850 63,275 57,271 8,270,774 157,766 4b.tIA Totals 11,285 61,417 60.618 800 207.048 90,895 16,987,290 418,513 4b.1 Subtotal Period 4b Acivity Costs 4,318 13,131 942 1,800 19,364 10,578 Pened 4b Additional Costs 656 4 24 - 55 1,192 360 2,290 2290 - 1,050 162,629 17.515 2.560 4b.2.1 ISFSI Decontaminatioo 12,480 4b.22 Final Site Survey . . .. 1,205 362 1,567 1.567 722 3,857 1,567 2,290 1,050 162,629 17,515 15,040 4b.2 Subtotal Period 4b Addriional Costs 656 4 24 55 2,397 Penod 4b Collateml Costs 125 30 161 183 113 566 566 839 38,338 4b.3.1 Procens liquid waste 79 -

4b.32 Small tool allowance 230 . 35 265 265 130 973 973 6,000 373 303.507 88 4b.3.3 Decomnussioning Equipment Disposition 88 50 621 84 278 1,804 1,804 ,000 1.012 341,844 213 4b.3 Subtotal Period 40 Collateral Costs 79 230 118 210 621 267 TLG Services, Inc.

Cooper NuclearStation Document N01-1590-002, Rev. I DecommissioningCoast Analysis Appendix C, Page33 of 35 Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sits LLRW NRC Spent Fuel Sits Processed Burial Volumes Burial I Utitty and I Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Torm, Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor, ImActivity IJlU*X A*UVI[V* fIM[*ll Coast Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet C. Fet CF . Ft Cu. Fot WL, Lbs. Mahors Maours I n ex, Perod 41, Period-Dependent Costs 40.4.1 Decon supplies 1,252 - 313 1,565 1,565 4b.4.2 Insurance - 1,199 120 1.319 1,319 40.4.3 Property taes - 10 1 11 11 4b.4.4 Health physics supples 2,378 - 594 2,972 2,972 41.4.5 Heavy equipment rent0l 4,294 - -- 644 4,938 4,938 4b.4.6 Disposal of DAW gereroted 55 31 876 - 229 1,192 1,192 18,853 172,932 58 4b.4.7 Plant energy budget 1,701 255 1,956 1,956 40.4.8 NRC Fees 1,610 161 1.771 1,771 4b.4.9 Uquid Radwaste Processing Equipment/Senvices 918 138 1,055 1,055 4b.4.10 Security Staff Cost 6,984 1.148 8,032 8,032 159,464 4b.4.11 DOC Staff Cost 24,760 3,714 28,474 28,474 341,891 4b.4.12 UtilityStaff Cost 33,266 4.990 38,256 38,256 602,137 4b.4 Subtotal Period 4b Period-Oependent Costs 1.252 6,672 55 31 876 70.448 12,207 91,542 91,542 18.853 172,932 58 1,103,493 4b.0 TOTALPERIOD,4b COST 5,649 20,689 1.119 2,064 19,985 11.776 72.845 24,492 158,620 155,530 2,290 800 213,048 111,810 17,664,700 436,298 1,118,533 PERIOD 4e - License Termination Period 4e Direct Decommissioning Acbvtes 4e.1.1 ORISE confmlaatory surcey - . - - 147 44 191 191 4e.1.2 Terminate icnse a 4e.1 Subtotal Period 4e ActivityCosts 147 44 191 191 Period 4e AdditionalCosts 40.2.1 Final Site Surtey 5,998 1,799 7.797 7,797 148,435 6.240 4e.2 Subtotal Period 4e Additional Costs 5.998 1,799 7,797 7,797 148.435 6.240 Period 4e Collateral Costs 4e.3.1 DOC staff relocation expenses 912 137 1,049 1,049 4e.3 Subtotal Period 4e Collateral Costs 912 137 1,049 1.049 64 Period Perinod-DependentCosts 40.4.1 Insurance .. . .

48.4.2 Property taxes- 3 0 3 3 4e.4.3 Health physics supplies 735 - - 184 010 919 4e.4.4 Disposal of DAWgenarated 3 1 42 11 57 57 904 8,294 3 4e.4.5 Plant energy budget 139 21 160 160 4e.4.6 NRC Fees 530 53 583 583 4e.4.7 Security Staff Cost 1.009 151 1.160 1,160 18,789 4e.4.8 DOC Staff Cost 4,442 666 5,108 5,108 57.149 40.4.9 Utity Staf Cost - - - 4.678 702 5,379 5,379 - - - 74,371 40.4 SubtsotalPeriod 4e Period-Dependest Costs 735 3 1 42 10.800 1,788 13,369 13,369 904 8,294 3 150,309 4e.0 TOTALPERIOD 40 COST 735 3 1 42 17,857 3,768 22,407 22,407 - - 904 - - 8,94 148,438 156,549 PERIOD4 TOTALS 5,840 36,775 7,765 4,470 37,168 30,307 123.139 50,330 295,793 292,606 2,290 897 384.676 155,874 1,377 344 508 28,279,480 736.765 1,781,267 PERIOD 90 - Sits Restoration Peood 51 Direct Decomissioning Actvities Demoition of Remaining Site Buildings 5b.1.1.1 Reactor 1,491 224 1,715 1,715 14,601 5b.1.1.2 Augmetesd Radwasts 222 33 255 255 2,119 5b.1.1.3 Control 214 32 246 246 1,655 5b.1.1.4 Intake Structure 523 78 802 602 5,621 TLG Services, Inc.

Cooper Nuleear Station Document N0-1590.002,Rev. I Decommoissioning Cast Analdysis Appendix C, Page34 of 35 Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I UtUity and I Oemon Removal Packaging Transport Processing Disposal Other Total Total UC. Term, Management Restoration Volume Class A Class B Class C GTCC Pmcessed Craft Contractor I I

I Actil.ty I*nOX *C*I*

• nO[* n Cast Cost Costs Costs Costs Costs Costs Contlnoenrn Costs Costs Costs Costs Cu. Feet Cu. Fast Cu. Fast Cu. Fast Cu. Fast WRt.Lbs. Manhours Manhours I A at n 'o timacrim Cr Demolition of Remaining Site Buildings (continued) 5b.1.1.5 LLRW Storage Pad 145 22 167 167 1,227 5b.1.1.6 Miscellaneous Structures - Clean 1.198 179 1,375 1.375 11,837 5b.1.1.7 Misetlaneous Structures - Contaminated 27 4 30 30 572 5b.1.1.8 Muo-Purpose Faciity 123 18 141 141 1.982 5b.1.t9 OWC Gas Generator 18 3 20 20 283 tOfice 5b. 1..10 156 23 179 179 1.920 5b.1 1.11 Radwase 391 59 449 449 3,229 5b.1 112 Seal Wetl 17 3 20 20 166 4 1 5 5 53 5b.1 1.13 Sewage Treatment Area 5b 1.1.14 Transfomler Yard 20 3 24 24 172 389 2,985 2,985 40,503 5b.1.115 Turbine 2,596 5b.1.1.16 Turbine Pedestal 277 42 318 318 2,100 5b.1.1 Totals 7,418 1,113 8,531 8.531 88,040 Site Closeout Activities 5b.12 Remove Rubble 424 84 488 488 3,286 5b.1.3 Grade &ltadscape site 578 .- 87 665 - 665 1,578 51,.1.4 Finalrepon to NRC O15 23 179 179 1,560 5b. 1 Subtotal Period 5b Activity Costs 8.421 156 1,286 9,863 179 9,684 92,904 1.560 Period 5b Additional Costs 5b.2.1 ISFSI Demolition 487 44 80 811 811 4.336 160 499 76 582 582 3.045 -

5b.2.2 Concrete Crushing 5b.2.3 Collardsm 458 69 527 527 5,130 5b.2 Subtotal Period 5b AdditionalCosts 1.444 - 52 224 1,720 611 1,109 12,511 160 Period 5b Collateral Costs 5b.331 Smatl tool allowance 55 a 63 63 55 8 63 63 5b.3 Subtotal Period 5b Collateral Costs Period 5b Period-Dependent Costs 5b.4.1 Insurance 7 1 9 8 5b.4.2 Property laves 5b.4.3 Heavy equipment rental 4.233 635 4,869 4.869 5b.4.4 Plant energy budget 167 25 192 192 2.782 5b.4.5 Security Staff Cost 2,419 363 2,782 45,051 5b.4.8 DOC Staff Cost 10,212 1.532 11.744 11,744 127,649 5b.4.7 Uaty,Staff Cost 4,507 876 5,183 5.183 73,209 5b.4 Subtotal Period 5b Period-Dependent Costs 4,233 17,312 3,232 24,777 - 24,777 245,908 5b.0 TOTAL PERIOD 5b COST 14,153 17,520 4,751 36,424 179 611 35.634 105,415 247,628 PERIOD S TOTALS - 14,153 17,520 4,751 38,424 179 611 35,634 105.415 247,625 TOTALCOST TO DECOMMISSION 13,012 59,570 8,087 5,424 37.168 34,469 618,965 131,014 907,708 674,964 195,398 37,347 384.676 227,370 1,377 344 588 29,135.660 973.379 7,882,560 TLG Services, Inc.

CooperNuclear Station Document NO].1590.002, Rev. I Decommissioning Cost Analysis Appendix C, Page 35 of 35 Table C-3 Cooper Nuclear Station 2014 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Sit Processed Burial Volumos Burial I Utlibty and Decon Removal Packaging Transport Processing Disposal Other Total Total LIc. Tenm. Management Restoration Volumne Class A Class B Class C GTCC Processed Craft Contractor IActivity InOAY A£UV* *cnot* Cost Cost Costs Costs Costs Costs Costs Casts Costs Cu. Faot Cu. Feat Cu. Foot Cu. Feet Cu. Feet WL, Lbs. Manhours Manhours I n as ciiiiiii6w. t TOTALCOST TO DECOMMISSION WITH16.87% CONTINGENCY: $907,708 thousands of 2008 dollats TOTALNRC UCENSE TERMINATIONCOST IS 74.36% OR: $674,964 thousands of 2008 dollars SPENT FUEL MANAGEMENTCOST IS 21.63% OR: $195,398 thousands of 2008 dollars MON-NUCLEARDEMOLITIONCOST IS 4.11% OR: $37,347 thousands of 2008 dollats TOTAL LOW-LEVELRADIOACTIVEWASTE VOLUME BURIED(EXCLUDING GTCC): 229,092 cublc foot TOTALGREATER THAN CLASS C RADWASTE VOLUMEGENERATED: 608 cubic feet TOTALSCRAP METALREMOVED: 30,276 tons TOTALCRAFT LABOR REQUIREMENTS: 973,379 man-hours End Notes "ia - indicates that thisactivity not charged as decommissioning expense.

. - indicates that tlbs activity pertosned by decommnssioning staff.

0. Indicates that this value is less than 0.5 but is non-zero.

o call containing - - indicates a ze= value TLG Services, Inc.

CooperNuclearStation Document N01-1590-002, Rev. 1 Decommissioning CostAnalysis Appendix D, Page I of 35 APPENDIX D DETAILED COST ANALYSES 2034 CESSATION OF OPERATIONS T able D -1, D E C O N ............................................................................................... D -2 Table D -2, D elayed D ECON ............................................................................... D -13 Table D -3, SA FSTO R .......................................................................................... D -24 TLG Services, Inc.

Cooper NuclearStation Document NI01-1590.002, Rev. 1 DeoamnissioningCost Analysis Appendix D, Page 2 of 35 Table D-1 Cooper Nuclear Station 2034 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes BurlsI Utiity and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic.Teem. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contin ency Costs Costs Costs Costs Cu. Feet Co. Feet Cu. Feet Cu. Feet Co. Feet WI. Lbs. Manhours Manhours PERIODIa - Shutdown through Transition Period 10Direct Deconvmissioning Activities 18.1.1 Prepare preliminary decommissianing cost 130 20 150 150 1,300 la.I,2 Notifiation of Cessation of Operations 51 la.t13 Remove fuel & source material 10a.1.4 Notificationof Permanent Defueling a 1:.1.5 Deactivate plant systems & process waste 1 . 1.6 Prepare and submit PSDAR 200 30 230 230 24000 460 69 529 529 4,600 10.1.7 Review plant dwgs & specs.

1:.1.8 Perform detailed rad survey 100 1,000 1a.1.9 Eastiate by-product inventory 15 115 115 100 1,000 1a.1.10 End product description 15 115 115 130 20 150 150 1,300 1a,1.11 Detiailedby-product inventory 750 113 863 063 7,500 la.1.12 Define major work sequence 310 47 357 357 3.100 ta.1.13 Perform SER and EA 0.1.14 Perform Site-Specific Cost Study 500 75 575 575 5,000

- -- . - - 410 61 471 471 4,096 ta.1.15 Prepare/subrmt License Termination Ptan la.1.16 Receive NRC approval of termination plan a ActivitySpecitications 1:.1,17.1 Plant &temporary facitites 492 74 566 509 57 4.920 417 63 479 431 48 4,167 1a.1.17.2 Plant systems 500 1:.l.117.3 NSS6 Decontamination Flush 50 a 58 58 710 107 817 817 7.100 la .1.174 Reactor imternas 650 98 748 748 6.500 a.1.t17.5 Reactor vessel 50 8 58 58 500 1 .1.17.0 Sacrificil shield 100 15 115 115 1.000 la.1017.7 Maisture separators/reheaters 92 160 24 184 92 1,600 1 1.17.8 Reinforced concrete 209 31 240 240 2.088 1:.1.17.9 Man Turbine 2.088 10.1 t7.10 Main Cosdensers 209 31 240 240 200 30 230 230 2,000 10.1.17.11 Pressure suppression structure 1,600 10.1.17.12Drpywal 160 24 184 184 312 47 359 179 179 3.120 l:.1.17.13 Plant structures& buildings 460 69 529 529 4.600 10.1.17. 14 Waste management 90 14 104 52 52 900 1:.1.17.15 Facility &site doseout 4,268 640 4,909 4,481 428 42,683 1.1.17 Total Planning&Site Preparations 240 36 276 276 2,400 la.1.18 Prepare dismantling sequence 2.700 1:.1.19 Plant prep. &tem*. svces 405 3,105 3.105 140 21 161 161 1,400

1. 1.20 Design water dean-up system

,0.1.21 Rigging/Cord. Cntrl Envlps/toolingletc. 2,100 315 2,415 2,415 123 18 141 141 1,230 10.1.22 Procure caskailineem&containers 12,661 1,899 14,560 14,132 428 78,609 la.1 Subtotal Period la ActivityCosts Period Ia Colateral Costs la.3.1 Spent Fuel Capital and Transfer - -- - - - 2,721 400 3,129 3.129 10.3.2 Corporate Overheads - -- - - - 3,105 466 3,570 3.570 la.3 Subtotal Period 1a Codlateral Costs - -- - - - 5.825 874 6,699 3,570 3,129 Period 10 Period-Dependent Costs la.4.1 Insurance 1,600 160 1,760 1,760 ta.4.2 Property taxes 4 0 4 4 1a.4.3 Hlealth physic supplies 370 93 463 463 la.4A Heavy equipment rental 368 55 423 423 TLG Services, Inc.

0 Cooper Nuclear Station DocumentN01-1590-002, Rev. I Appendix D, Page 3 of"35 Deesasmiasstaing Coa, Analsuyis Table D-1 Cooper Nuclear Station 2034 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel site Processed Burial Volumes BurialI Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Torm. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Continies Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt. Lbs. Manhours Manhours Period 15 Period-Dependient Costs (cortnuel) 14,445 la.4.5 Disposal of DAWgeneratsd 3 - 73 19 100 100 1,575 1 .4.6 Plant energy budget 927 139 1,069 1,066 1a4.7 NRC Fees 706 71 776 770 ta.4.8 Emergency Planning Fees 1.185 118 1,303 - 1,303 laA.49 Spent Fuel Pool O&M 745 112 857 857 1a.4.10 ISFSI Operating Costs 85 13 98 - 98 5,483 822 6,306 6,306 157,471 t:.4.11 Security Staff Cost

• . 22.690 3,403 26,093 26.093 423,400 ta.4.t2 UildityStaff Cost 738 3 73 33.424 5.006 39,249 36.991 2,258 1,575 14,445 5 580,871 la.4 Subtotal Penod la Penod-Dependent Costs la.0 TOTAL PERIOD loCOST 738 3 73 51,910 7,779 60,508 54,693 5.387 428 1,575 14,445 5 659,480 PERIOD lb - Decommnissioning Preparations Period lb Direct Decommissioning Activities Detailed Work Procedures lb.1.1.1 Plant systems 473 71 544 490 54 - . 4,733 100 15 115 110 1,000 1b.1.1.2 NSSS Decontamination Flush - 4,000 lb.1.1.3 Reactor internals 400 60 460 460 20 155 39 116 1,350 lb.1.1.4 Remaining buildings 135 100 15 115 115 1,000 lb.1.1.5 CRD housings & Nis - . 1,000 lbt.1.6 Inmore instrumentaton 100 15 115 115 lb.1.1.7 Removal primary containment 200 30 230 230 2,000 363 54 417 417 3,630 tb*l.1.8 Reactor voesel 120 18 138 69 1.200 lb. 1.9 Facility closeout 120 18 138 138 1.200 lb 1.1.10 Sacrdcial shield "58 1,000 lb. 1111 Reinforred conorete 100 15 115 58 208 31 239 239 2,080 lb.1.1.12 Main Turbine 209 31 240 240 2Z088 1t.1.1.13 Main Condensers 2,000 lb.1.1.14 Moisture separators & reheaters 200 30 230 230 273 41 314 283 31 2.730 lb,1.1,15 Radwaste building 273 41 314 283 31 2,730 lb 1116 Reactor building 506 3,880 3.520 360 - 33,741 lb,1.1 Total 3,374 348 174 523 523 1,067 1b,1.2 Decon NSSS lb.1 Subtotal Period lb Activity Costs 348 3,374 680 4.403 4,043 1,067 33,741 Period lb Additional Costs lb.2.1 Spent Fuel Pool Isolation 9,407 1,411 10,818 10.818 1b.22 Site Characterization 5,395 1,919 7.014 7,014 773 I 65 265 1,662 1,662 10.333 134.329 10,002 1b.2.3 Asbestos insulation Disposal 773 1 65 009 14,802 3,295 19,493 19,493 10,333 134.329 10,002 15.2 Subtotal Period lb Additional Costs Period lb Collaterl Costs lb.3.1 Decon equipment 713 107 820 820 1b,3.2 DOCstaff reocauton expenses 912 137 1,049 1,049 46 249 1,80.90 525 2,690 2,690 427 543 85.905 189 i b.3.3 Process liquid waste 64 Ib.34 Small tool allowance "11 2 12 12 1b.3.5 Pipe cutting equipment 150 1,150 1,150 Ib.3.6 Decon rig 1,400 210 1,910 1,610 1b.3.7 Spent Fuel Capital and Transfer 1,880 282 2,162 - 2,162 Ib.3.8 Corporate O=mreeds - 1,554 233 1,787 1,787 1b.3 Subtotal Period 1b Collateral Costs 2,177 1,011 46 249 1.806 4,346 1,646 11,280 9.118 2,162 427 543 85,905 189 TLG Services, Inc.

Cooper Nuclear Station Document N01-1590-002,Rev. I DecommissioningCoast Analysij Appendix D, Page 4 of 35 Table D-1 Cooper Nuclear Station 2034 DECON Decommissioning Cost Estimate (thousands of 2008 dollars) off-Site LLRW NRC Spent Fual site Processed Burial Volumes Burial I Utilty and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Reetoration Volume Clans A Clans B Class C GTCC Processed Craft Contractor index Activity Descrlptlon cost cost costs Costs Costs Cooss Cools ConulnFene Coots cost Cools canto Ca. Feet Ca.u. Fee W. Lbs nhor Manhnour Period lb Period-Dependent Costs lb.4.l Decon supplies 22 4 5 27 27 lb.4.2 Insurance 244 24 269 269 lb.4.3 Property taxes 2 0 2 2 lb4.4 Health physics supplies

• 242 60 302 302 1bA.5 Heavy eqtuipment rental 183 - - 27 211 211 lb.4.6 Disposal of DAW generated 3 2 43 11 58 58 920 8.439 3 lb.4.7 Plant energy budget 924 139 1,063 1,063 lb.4.5 NRC Fees 352 35 387 387 lb.4.9 Emergency planning Fees 591 59 650 650 lb.4.10 Spent Fuel Pool O&M 372 56 427 427 lb.4.11 ISFSI Operating Costs 42 6 49 49 1b.4.12 Security Staff Cost Z,734 410 3,144 3,144 78,520 lb.4.13 DOC Staff Cast 4,759 714 5,473 5,473 63,440 lb.4.14 UtilityStaff Cost 11.380 1,707 13,086 13,086 212,160 lb.4 Subtotal Period lb Penod-Dependent Costs 22 425 3 2 43 21,400 3,255 25,149 24,023 1,126 - 920 8.439 3 354,120 lb.0 TOTAL PERIOD 1 COST 2,547 2,209 49 316 2,407 43.922 8,876 60,325 56,677 3.288 350 11,680 543 228,674 11,261 387,861 PERIOD I TOTALS 2,547 2,947 54 318 2.480 95.833 16,655 120.833 111.370 8.675 788 13,255 543 243,119 11,265 1,047,341 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nudear Steam Supply System Removal 2a.1.1.1 Recirculation System Piping &Valves 90 71 14 20 303 142 639 639 997 120,597 4.031 2a.1.1.2 Recirculation Pumps & Motor 33 28 11 29 321 109 532 532 1,188 132,880 1.683 2a.1.1.3 CRDMs &NIs Removal 133 139 377 92 317 232 1,291 1,291 6,935 - - 126,494 8,209 2a.1.1.4 Reactor Vessel Intertals 119 2,32 5,343 2,009 16,414 218 11,909 38,374 38,374 1,878 976 1,205 378,084 28,075 1,255 2a.1.1.5 Reactor Vessel 56 5,457 1,460 762 5.384 218 7.401 20,739 20.739 11,211 2,128 - 1,440,354 28.075 1.255 2a.I.1 Totals 431 8,05O 7,205 2,912 22.739 437 19.714 61,576 61,576 22,209 3.104 1,205 2.196,409 68,073 2.510 Removal of Major Equipment 2 .12 Main TurbinelGenerator 171 928 379 6.057 389 1,188 9,011 9,011 58,524 1,725 2,788,381 4,555 2a.1.3 Main Condensers 722 552 273 3.773 812 1,45 7,177 7.177 36,456 3,604 1,963,840 19,966 Cascading Costs hromClean Building Demolition 2a .1.4.1 Reactor 260 39 299 299 2,486 2a.1.4.2 Augmented Radwaste 25 4 28 28 235 20.1.4.3 Rodwaste 43 7 50 8o 359 20.1.4.4 Turbine 285 43 328 328 4.419 2a.1.4 Totals 613 92 705 705 7,498 Disposal of Plant Systems 2a.1.5.1 Augmented Radwaste El 877 AnealA 207 28 28 432 167 882 862 2,055 172,205 5,783 2a.1.5.2 Augmented Radwasle El 903 AtaIA 68 6 7 104 45 230 230 469 41,606 1,889 2a.1.5.3 Augmented Radwaste El 918 AjealA 53 10 9 139 50 261 261 765 55,345 1,451 2a.1.5.4 Augmented Raedaste El 929 AnalA 21 4 5 73 25 128 128 324 29.038 591 2a.1.5.5 Augmented Radwaohe El 929 ArealB 3 0 0 3 0 1 8 8 36 1 1.538 77 2u.1.5.8 DRYVWELL ArealA 534 85 84 - 1,289 477 2,470 2,470 5,726 513,627 15,069 20.1.5.7 DRYWELLAreatB 134 3 5 54 28 W0 274 274 577 126 34,718 4,142 20.1.5.8 Multi-Purpose Facility 202 6 15 201 47 95 566 566 2,148 214 105,982 5,547 20.1.5.9 Reactor El 903 ArealA 404 56 42 651 276 1,428 1,428 - 2,892 259.190 10,573 2a.1.5.10 Reactor El 903 ArealB 462 13 34 443 131 221 1,305 1,305 4,739 583 244,706 12,864 2a.t.5.11 Turbine El 932 ArealB 332 52 99 882 725 416 2,505 2,505 9,442 3,220 672,225 9,481 2a.1.5.12 Turbine El 932 Area2C 8 1 9 237 TLG Servicas, Inc.

Cooper Nuaclear Sioiuso D - 1 NTOJ.13OwdO2 Rer. J Decommissio~ning Cast Anslyais Appensdix D),Page 5 of.55 Table D-1 Cooper Nuclear Station 2034 DECON Decommissioning Cost Estimate (thousands of 2008 dollars) m Off-Site LLRW NRC Spent Fuel Sits Processed Burial Volumes Burial I Utility and Decon Removal Packaging Transport Processing Disposal Other Total Total sic.Tenm. Management Restoration Volume Clans A Class B Class C GTCC Processed Craft Custractor, I innnl civityn Acuv*

• nmmn COst Coot Cnsts Costs Costs Costs Costs Continnaenc Costs Costs Costa Costs Ca. Foot Cu. Fent Cu. Foet Cu. Feet Cu. Feet WL Lbs, Manhours Manhours I n ex .. u..v - --------- 11.ý t Costs Costs C'Osts Costs osts costs Cu. Feet Cu.Fnt Cu.Feet Cu.Feet - Cu.Fewt Wt. Lbs. Manhours - Manhcurs DiOsposalof Plant Systems (contnued) 2:.1.5.13 Turbine El 932 Ara3C 67 - 10 78 - 78 - - -- 2,083 2 .1.5.14 Yard Areal B 518 110 284 3.535 1.198 1,013 6,657 6,657 37,846 5.399 2,014,081 14.477 2a.1.5 Totals 3,013 374 612 5,117 4,817 2,847 16,780 16.693 87 54,788 21,774 4,144,259 84,262 2a.1.6 Scaffolding in suppot o1decommissioning 2,070 24 11 168 23 553 2,848 2.848 1,621 101 81,992 28,092 2a. 1 Subtotal Period 2a Activity Costs 431 14,647 8,983 4,186 15,116 28,780 437 25.519 98,097 98,010 87 151,388 49,413 3,184 1,205 11.174,880 212,445 2,510 Period 2a Collateral Costs 2.3.1 Process liquid waste 135 - 44 231 173 847 847 - - 921 55,244 180 -

2a.3.2 Small tool allowance 124 19 143 129 14 20.3.3 Spent Fuel Capital and Transfer 5,279 792 6,070 6,070 2a.3.4 Corporate Overheads - 3,202 480 3,682 3,682 2a.3 Subtotal Period 2a Collateral Costs 135 124 44 231 264 8,480 1,463 10,742 4,657 6.070 14 921 55,244 180 Period 2a Period-Dependent Costs 20.4.1 Decen supplies 61 - 15 76 76 20.4.2 Insurance 688 69 756 756 2a.4.3 Property taxes 6 1 6 6 2a.4.4 Health physics supplies 1,262 315 1.577 1,577 2a.4.5 Heavy equipment rental 2,480 - 372 2,852 2,852 2a.4,6 Disposal of DAWgenerated 34 19 537 140 730 730 11,545 105,898 35 20.4.7 Plant energy budget 1,235 185 1,420 1,420 20.4.8 NRC Fees 923 92 1,016 1,016 20.4.9 Emergency Planning Fees 1,183 116 1.301 1,301 20.4.10 Spent Fuel Pool O&M 1,046 157 1.203 1,203 20.4.11 ISFS1Operating Costs 119 18 137 137 20.4.12 Security Staff Cost 6,631 995 7,626 7,626 185,051 20.4.13 DOC Staff Cost 16.275 2,441 18,716 18,718 222,354 20.4.14 UtilityStaff Cost 22,962 3.444 26,407 26,407 413,989 20.4 Subtotal Period 2a Pedod-Depenadent Costs 61 3,741 34 19 537 51,067 8.363 63,822 61,182 2,640 1 - 11,545 105,898 35 821,394 20.0 TOTALPERIOD 2a COST 627 18,513 9.060 4,437 15,116 29,580 59,985 35,345 172,662 163,849 8,711 102 151,388 61,878 3,104 1,205 11,336,020 212,660 823,904 PERIOD 2b - Site Decontamination Period 2b Direct Decohmmssioning Activites Disposalof Plant Systems 2b.1.1.1 Control E 882 AmaolB

• 285 17 42 554 147 - 199 1,243 1,243 - 5.929 674 299,222 7,975 -

2b. 1.1.2 Control El 903 ArealC 170 - 25 195 - 195 - 5,155 25.1.1.3 Control El 918AreaC 66 10 76 76 2,100 2b.1.1.4 Control El 932 ArealC 22 3 26 26 702 25.1.1.5 Intake 101 15 116 - 116 - 3.136 2b.1.1.6 Radwaste El 877 ArealA 405 75 62 949 355 1.845 1,845 5,097 377,917 11,133 25.1.1.7 Radwaste El 877 Area2A 44 9 7 113 41 214 214 613 44,992 1,207 25.1.1.8 Radwaste El 877 Ara3A 84 16 13 201 75 308 308 1,156 79,963 2.349 2b.1.1.9 Radwast El 903 ArealA 113 9 10 153 69 355 355 684 61,153 3,102 2b.1.1.10 Radwaste El 903 Ama2A 192 36 29 439 166 861 861 1,955 175,093 5,412 2b.1.1.11 Radwaste El 903 Area3A 37 6 7 104 37 191 191 463 41.366 1,047 2b.1.1.12 Radwaste El 18 ArealA 21 2 2 30 13 68 68 135 12.033 572 2b.1.1.13 Radwaste Elt18 Area2A 17 3 3 39 15 76 76 201 15,667 455 25.1.1.14 Radwaste El 918 Area3A 189 23 22 338 137 710 710 1,690 134,827 5,152 2b.1.1.15 Radwaste 934 ArealA 26 3 4 60 22 115 115 266 23,735 692 2b.I.1.16 Radwaste El 934 Area2A 100 11 12 177 72 372 372 808 70,665 2,706 25.1.1.17 Radwaste El 949 ArealA 12 1 2 24 9 47 47 105 9,381 310 TLG Serviceo, Inc.

Cooper NuclearStation Document N01-15900)02,Rev. I DecommissioningCost Analysis Appendix D, Page 6 of"35 Table D-1 Cooper Nuclear Station 2034 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Silo LLRW NRC Spsnt Fuel site Processed Burial Volumes Burial I Utility and i IActivity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic, Trnm. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor iI tflnAf ACflV*

• flOfDN cost Cast Costs Costs costs costs Costs Conlineonsv Costs Costs Costs Costs Cu. Feet Cu. Fast Cu. Feet Cu. Feet Cu. Feet Wt. Lbs. Manhours Manhours I n ex C pt n Disposal of Plant Systems (continued) 2b.1.1.18 Reactor al859 ealiA 72 15 16 246 83 432 432 - 1,091 97,874 2,068 2b.1.1.19 Reacto El 859 AkealB 449 29 64 712 344 317 1,914 1,914 7,624 1,526 440,483 12.740 2b.1.1.20 Reactor a 859 Are2A 73 25 26 - 401 125 650 650 - 1,780 159,714 2,137 2b.1.1.21 Reactor El 859 Area2B 70 3 8 99 40 44 284 264 1,055 177 58,760 2,009 2b.1.1.22 Reoctor E 59 Area3A 48 9 9 137 49 252 252 - 608 54.543 1,356 2b.1.1.23 Reactor El 859 Area3B 34 2 3 23 23 18 103 103 249 103 19,362 975 2.1,.1.24 Reactor El 859 Area4A 51 9 8 117 44 229 229 - 520 48,666 1,416 2b.t.1'25 Reactor El 859 Area48 17 1 2 19 14 11 65 65 208 82 14,010 487 2b.1.1.26 Reactor El 859 Aret5A 64 16 17 252 86 445 445 1.163 -14,381 1,839 2b.1.1.27 Reactor El 859 Area5B 38 2 3 23 23 19 107 107 242 102 18,927 1,114 2b.1.1.28 Reactor El f83 Area2A 4 0 0 6 3 14 14 26 2,372 123 2b.1.1.29 Reactor El 903 Area2B 71 5 12 149 51 55 342 342 1.594 225 84.943 1,983 2b.1.1.30 Reactor EA903 Aroo3A 37 10 11 - 167 54 279 279 741 66.516 1,109 2b.1.1.31 Reactor EA9D3 Arwe3B 25 2 3 37 17 17 101 101 401 77 23,200 744 2b.1.1.32 Reactor Ef903 Area4A 31 8 9 136 44 229 229 666 54,373 928 2b.1.1.33 Reactor El 083 Area4B 24 1 3 38 17 17 101 101 411 75 23,408 717 2b.I.1.34 Reactor EI 931 AreslA 25 3 3 52 20 104 104 - 232 20,858 681 2b.1.1.35 Reactor El931 ArealB 307 22 45 483 256 222 1,334 1,334 5,169 1,137 311,878 8,640 2b.1.1.36 Reactor El931Area2A 31 2 2 - 35 17 87 87 154 13,824 881 2b.1.1.37 Reactor El 931 Area2B 3 0 0 1 0 1 5 5 7 1 380 91 2b.1.1.38 Reactor El 931 Area3A 123 23 22 336 120 625 625 1.651 134,007 3,509 2b.1.1.39 Reactor El 931 Are3B 3 0 0 1 0 1 4 4 7 0 345 85 2b51.1.40 Reactor El 931 Area4C 24 4 28 28 - 767 2b.1 .1.41 Reactor El 3l AreasC 7 I 8 - 8 S

- 213 2b.1.1.42 Reactor El S58 ArelA 57 9 10 149 54 279 279 - 662 59,432 1,492 2b.1.1.43 Reactor El 958 Areml8 171 8 18 209 88 100 594 594 2,238 392 126.002 4,814 2b.1.1.44 Reactor El 958 A8a2A 49 10 10 - 153 53 276 276 - 681 61,083 1.425 2b,51145 Reactor Els58 Are2B 15 1 1 6 14 8 46 46 66 63 8,331 430 2b.511.46 Reactor El8958Ae3A 38 4 3 - 48 22 116 116 - 214 19,185 1,070 2b.1.1.47 Reactor EA958 Area3B 17 1 1 6 12 8 45 45 60 54 7,250 491 2b51,1.48 Turbine El 882 ArelA 38 3 3 - 50 23 117 117 - 222 19,878 1,028 2b.1.1.49 Turbine El 882 ArealB 394 40 95 1.101 478 402 2,515 2,515 11,784 2.117 668,352 11,459 2b51.1.50 Turbine El 852 Area2A 22 2 2 - 29 13 68 68 - 129 11,556 597 2b.1.1.51 Turbine El 882 Area2B 213 10 23 301 89 125 762 762 3,227 405 166,542 5,929 2b1,

• 32 Turbine El 882 Area3A 17 2 1 - 23 10 53 53 - 101 9,017 461 2b.1.1.53 Turbine El 882 Area3 620 62 156 1,960 633 637 4,068 4,068 20,984 2,817 1,104,460 17,788 2b.1.1.54 Turbine El 903 ArealA 9 1 1 - 15 6 33 33 - 68 6,127 239 2b.1.1.55 Turbine FJ903 AesIB 995 134 271 2.728 1,717 1,141 6,983 8,993 29.100 7,631 1,868,932 28,509 2b51,156 Turbine El 903 Aea2A 5 1 1 - 8 4 20 20 - 42 3,729 145 2b51.1.57 Turbine El 03 Area2B 147 3 8 105 30 62 355 355 1,122 133 57,476 4,141 2511.58 Turbine El 903 Aa3B 3 0 2 33 2 7 48 48 357 9 15,340 97 2b.1.1.59 Turbine 003 Area3C 108 16 124 - 124 - 3,412 2b51.1.60 Turbin El 903 Area4B 12 0 2 26 3 8 50 50 276 11 12,251 397 2b51.1.61 YardAreaiC 197 30 227 - 227 ,770 2b.1.1 Totals 6,646 6893 1,087 8,811 8,996 5,365 31,398 30,598 8o0 92,185 41,662 7,327,776 189,487 2b. 1.2 Scaffolding in support of decommnrissioning 2,588 30 14 210 29 691 3,560 3,560 2,028 128 102,490 35.115 Decontamination of Site Budings 2b.1.3.1 Reactor 2.702 1,457 131 320 4,748 1.116 2,767 13.241 13,241 50,830 18.343 3,680,298 101,984 2b.1,3,2 Augmented Redwaste 55 32 7 10 23 119 71 316 316 242 2,189 228,383 2,299 2b.1.3.3 Mascelaneous Structures -Contamninated 377 174 is 43 759 74 372 1,815 1.815 8.129 679 395,527 13,327 2b.1.3.4 Mutj-Purposs Facility 72 73 11 19 115 172 118 579 579 1,234 3,087 356.985 3,680 2b.1.3.5 Radwaste 167 98 18 26 38 319 196 850 850 404 5,886 603,975 6,839 2b.1.3.6 Turbine 552 267 70 97 84 1,261 689 3,001 3,001 688 23,302 2,357,288 21,920 2b.1.3 Totals 3,924 2.088 252 515 5.747 3.061 4.214 19,801 19,801 61,526 51,485 7.622,455 150,050 TLG Services, Inc.

Cooper NuclearStation DocumentNI01-1590-002, Rev. I Appendix D, Page 7 of35 DecommissioningCost Analysis Table D-1 Cooper Nuclear Station 2034 DECON Decommissioning Cost Estimate (thousands of 2008 dollars) off-sita LLRW NRC SpentFuel Situ Processed BurialVolumes BurialI Utlty and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic.Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activio Description Cost Cost Costs Costs Costs Costs Costs Contin encv Costs Costs Costs Costs Cu. Feel Cu. Feet Cu. Feet Cu. Foot Cu. Feet Wt. Lbs. Manhours Manhours 3.924 11.322 975 1,616 14,567 12,086 - 10.269 54.759 53,960 880 155,741 93.273 - - 15,052.720 374,651 -

2b.1 Subtotal Period 2b Activity Costs Period 2b Collateral Costs 2b.3.1 Process liquid waste 184 - 54 283 323 211 1,035 1,035 1,126 67.588 220 2b.3.2 Small teWallowance - 195 29 225 225 -

2b.3.3 Spent Fuel Capital and Transfer 15,867 2.380 18,247 - 18,247 2b.3.4 Corporate Overteads . . . .. 5,754 863 6,618 6,618 -

323 21,621 3,483 26.124 7,877 18,247 1,126 67,588 220 2b.3 Subtotal Period 2b Collateral Costs 164 195 54 283 Period 2b Period-Dependeot Costs 2b.4.1 Decon supplies 1,318 - 330 1,648 1,648 2b.4.2 Insutrance - 1,273 127 1.400 1,400 2b.4.3 Property taxes - 10 1 11 11 -

2b.4.4 Health physics supplies 2,257 - 564 2,822 2,822 2b.4.5 Heavy equipment rental 4.559 - - - 684 5,243 5,243 55 835 218 1,135 1,135 17,954 164,691 2b.4.6 Disposal of DAWgenerated - 53 29 -

2b.4.7 Plant energy budget - 1,805 271 2.076 2,076 2h.4.8 NRC Fees 1,709 171 1,880 1.880 2b.4.9 Emergency Planning Fees 2,190 219 2,409 2,409 2b.4.10 Spent Fuel Pool O&M 1.936 290 2,227 - 2,227 2b.4.11 Liquid Radwaste Processing Equipment/Services 487 73 560 560 -

2b.4.12 ISFSI Operating Costs 220 33 254 - 254 2b.4.13 Security Staff Cost 12,279 1,842 14,120 14,120 - 342,634 29.008 4,351 33,359 33,359 395,491 2b.4.14 DOC Staff Cost 40,864 6,130 46,993 46,993 - 734,023 2b.4.15 Ulily Staff Cost 29 835 91.781 15,324 116,137 111,248 4,889 17.954 164.691 55 1.472,109 2b.4 Subtotal Period 2b Period-Dependent Costs 1,318 6,816 53 18.334 1,081 1,928 14,567 13,243 113,402 29,057 197,020 173.085 23.135 800 155,741 112,354 15,285.000 374,928 1,472.109 2b.0 TOTAL PERIOD 2b COST 5,407 PERIOD 2c - Decontamination Folosing Wet Fuel Storage Period 2c Direct Decommissioning Actovilaes 2c.1.1 Remove spent fuel racks 267 33 79 88 1,348 500 2,316 2,316 5,988 537,141 1,004 Disposal of Plant Systems 50 7 8 121 45 231 231 - 537 48,175 1,273 2c.1.2.1 Reactor El 1001 ArealA 64 1 4 54 13 28 164 164 578 57 28,513 1,737 2c.1.2.2 Reactor El 1001 Areal B 2c. 1.2.3 Reactor El 976 AreslA i1 1 1 16 7 36 36 - 72 6,482 324 Reactor El 976 Area lB 150 11 27 328 115 121 752 752 3,516 511 188,501 4,017 2c.1.2.4 7 1 1 - 13 5 26 26 - 57 5,136 174 2c.1.2.5 Reactor El 976 Aree2A 38 1 3 42 16 20 121 121 449 72 24,474 1,056 2c.1.2.6 Reactor El 976 Area2B 321 23 44 424 293 226 1,331 1.331 4,543 1,305 301,281 8,561 2c.1.2 Totals Decontamination of Site Buildings 2c.1.3.l Reactor (post fuel) 257 510 97 138 163 1,742 747 3,656 3,658 1,749 32,119 3,281,659 18,302 Totals 257 510 97 138 163 1.742 747 3.656 3,658 1,749 32,119 3.281,659 18,302 2c.1.3 2c 1.4 Scaffolding in support of decommsuioning 518 6 42 6 138 712 712 405 25 20,498 7,023 1,611 8,014 8.014 6.697 39,437 4,140.579 34,890 2c.1 Subtotal Period 2c Actiolty Costs 525 1,382 205 273 630 3,389 Period 2c Additional Costs 2c.2.1 Final Site Survey 1,205 362 1,567 1.567 - - 12,480 12,480 2c.2 Subtotal Period 2c Additional Costs 1,205 362 1,567 1,567 TLG Services, Inc.

Cooper NuclearStation Document N01.1590-002, Rev. I DecommissioningCost Analysis Appendix D, Page8 of 35 Table D-1 Cooper Nuclear Station 2034 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

.off-Sit LLRW NRC Spent Fuei Site Processed Burial Volumes Buriall Utility and Activy Decon Removal Packaging Transport Processing Disposal Other Total Total Lc. Terom Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor index Activity Description Cost Cost Costs Costs Cost. Costs Costs ContinIen Cost. Costs Costs Costs Cu. Feet Cu Feet Cu. Feet Cu Feet Cu Feet WI. Lbs. Manhours Manhours Period 2c Collateral Costs 2c.3. 1 Process liquid waste 101 33 175 200 130 639 639 696 41.756 136 2c.3 2 Small tool allowance - 22 3 25 25 2c.3.3 Deconmissionng Equtlment Disposition s8 50 621 84 130 973 973 6.000 373 303.507 88 2c.3.4 Spent Fuel Capital and Transfer - -1,949 292 2,242 - 2,242 2c.3 Subtotal Period 2c Collateral Costs 101 22 121 225 621 284 1,949 556 3,879 1,637 2,242 6.000 1,069 345.263 224 Period 2c Period-Dependent Costs 2c.4.1 Decon supplies 90 - 23 113 113 2c.4.2 Insurance 197 20 217 217 2c.4.3 Property taxes - 2 0 2 2 2c.4.4 Health physics supplies 256 64 320 320 2c.4.5 Heavy equipment rental 707 106 813 813 2c.4.6 Disposal of DAWgenerated - 12 6 184 - 46 250 250 3,949 36,227 12 2c.4.7 Plant energy budget - 149 22 172 172 2c.4.8 NRCFees 265 27 292 292 2c.4.9 Emergency Planning Fees 340 34 373 - 373 2C.4.10 Liquid Radwaste Processing EquipmentlServices 151 23 174 174 2C.4.11 ISFSI Operating Costs 34 5 39 39 2C.4.12 SecurityStaff Cost 1,159 174 1,333 1,333 27.930 2c.4.13 DOC Staff Cost 3,126 469 3,595 3,595 42,000 4,699 705 5.404 5,404 80,220 2C.4.14 Utlity Staff Cost 2c,4 Subtotal Period 2c Peaod-Dependent Costs 90 963 12 6 184 10,123 1,719 13,096 12,684 413 3,949 36,227 12 150,150 2c.0 TOTAL PERIOD 2c COST 716 2,367 337 504 1,251 3,856 13,277 4,248 26,556 23,902 2,654 12,697 44.455 4,522,069 35,126 162,630 PERIOD 2e - License Termination Period 2e Direct Decommissioning Activiats 2e.1.1 ORISE confirmatory survey 147 44 191 191 2e.1.2 Terninate license 2e. 1 Subtotal Period 2e Actuty Costs 147 44 191 191 Period 2e Additional Costs 2e.2.1 Final Site Survey 1,799 7,797 7,797 148.435 6,240 2e.2 Subtotal Period 2e Additional Costs 1,799 7,797 7,797 148,435 6.240

• 5.912 5718 Period 2e Collateral Costs 20.3.1 DOC staff relocation expenses - . - . . - 912 137 1,049 1,049 2e.3.2 Spent Fuel Capital and Transfer - . . - - - 571 80 656 - 656 2e.3 Subtotal Period 2e Collateral Costs * ~~ - - - - 1483

, 222 1,705 1,049 656 Period 2e Period-Dependent Costs 2e.4.1 Insurance 327 33 360 360 2e.4.2 Property taxes 3 0 3 3 2e.4.3 Health physics supplies 737 184 921 921 3 1 42 11 58 58 914 8,380 3 2e,4.4 Disposal of DAWgenerated 20.4.5 Plant energy budget 139 21 160 160 2e.4.6 NRC Fees 530 53 583 583 2e.4.7 Emergency Planning Fees 633 63 696 - 696 2.4.8 ISFS1Operatng Costs 64 10 73 73 2e.4.9 Security Staff Cost 2,125 319 2,444 2,444 50.886 2e.4.10 DOC Staff Cost 4,442 666 5,108 5,108 57,149 2e.4.11 UtifityStaff Cost 5,071 761 5,832 5,832 - 80,634 20.4 Subtotal Period 2e Period-Dependent Costs 737 3 1 42 13,334 2.121 16.238 15.468 769 914 8,380 3 188,669 2e.0 TOTAL PERIOD 2e COST 737 3 I 42 20,962 4.187 25,931 24,506 1,426 914 8,380 148.438 194.909 TMG Services,Inc.

Cooper NuclearStation Document N01.1590-002, Rev. I Appendix D, Page9 of 35 Decommissioning Cost Analysis Table D-1 Cooper Nuclear Station 2034 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sit. LLRW NRC Spent Fuel Site Processed Burial Volumes BurialI Utlity and Activiy Docon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Acvity Descriptlon Cost Cost Costs Costs Costs Costs Costs Continaenc Costs Costs Costs Costs Cu. Feet Cu. Feat Cu. Feet Cu. Feet Cu. Feet WL Lbs. Manhoure Manhours PERIOD 2 TOTALS 6,750 39,950 10,481 6,870 30,933 46,723 207,625 72,836 422,169 385,342 35,926 901 319,826 219,601 3,104 1,205 31,151,470 771,150 2.653,551 PERIOD3b - Sit Restoration Period31DirectDecommissioning Activities Demolition of Remaining Site Buishings 1,473 221 1,694 1.694 14,089 3b.1.1.1 Reactor 2,119 3b.1.1.2 Augmented Radwaste 222 33 255 255 32 246 246 1,655 3b.1.1.3 Control 214 523 78 602 602 5,621 3b.1.1.4 Intake Structure 145 22 167 167 1,227 31.1.1.5 LLRWStorage Pad 11,837 3b.1.1.6 Miscellaneous Structures - Clean 1,196 179 1,375 1,375 4 30 30 572 3b.1.1.7 Misceaneous Stnrutures - Contaminated 27 123 1i 141 141 1,982 3b.1.1.8 MuiS-Purpose Facilty 3 20 20 283 3b.1.1.8 OWC Gas Generator 18 156 23 179 179 1.920 3b.1.1.10 Office 391 59 449 449 3.229 3b.1.1.11 Radreste 3 20 20 166 3b51.1.12 SealWen 17 4 1 5 5 53 3b 1.1 13 Sewrage Treatment Area 3 24 24 172 3b.1.1.14 Transfonner Yard 20 2,596 389 2.985 2,985 40.503 3b.1.1.15 Turbine 2.100 3b.1.1.16 Turbine Pedestal 277 42 318 318

• 18 3 21 21 512 3b.1.1.17 Reactor (post fuel) 7,418 1,113 8.531 8,531 88,040 3b.1.1 Totals Site Closeout Ac'invies 3,288 3b.1 .2 Remove Rubble 424 64 488 488 578 - 87 6685 686 1,578 3b. 1.3 Grade & landscape site Final report to NRC 156 23 179 179 1.560 3b.1.4 8,421 156 1,286 0,863 179 9,684 92,904 1.560 3b. 1 Subtotal Peard 3b ActivityCosos Period 3b Additonal Costs 3b.2.1 Concrete Crushing 499 8 76 582 582 3,045 3b.2.2 Cofferdam 458 - 69 527 527 5,130 957 8 145 1.109 1,109 8,175 3b.2 Subtotal Period 3b Additional Costs Period 3b Collateral Costs 3b.3.1 Small tool alrowance 53 - 8 61 61 3b.3.2 Spent Fuel Capital and Transfer 758 114 872 872 -

53 758 122 932 872 61 3b.3 Subtotal Period 3b Collateral Costs Period 3b Period-Dependent Costs 3b54.1 Insurance 751 75 826 826 3b.4.* Property toxes 7 1 8 8 3 .4.3 Heavy equapment rental 4,053 608 4.661 4,661 160 24 184 184 3b.4.4 Plant energy budget 3b.4.5 NRC ISFSI Fees 437 44 481 481 3b.4.8 Emergency Planning Fees 1,453 145 1.598 1,598 3b.4.7 ISFSI Operating Costs 148 22 168 168 4,878 732 5,610 4,937 673 116,814 354.8 Security Staff Cost 9,777 1,467 11,244 - 11,244 122,206 31.4.9 DOC Staff Cost 5,903 885 6,789 0 1,697 5,091 97.944 3b.4.10 Utility Staff Cost 4,053 23,513 4.003 31.569 0 9.715 21,853 336,964 3b.4 Subtotal Period 3b Pedod-Oependent Costs 13,483 24,435 5,555 43,473 179 10,587 32,707 101,079 338,524 3b.0 TOTAL PERIOD 3b COST TLG Services, Inc.

DocumentNO.1-1590-002, Rev. I CooperNuclear Station Appendix D, Page 10 of"35 DecommissioningCost Analysis Table D-1 Cooper Nuclear Station 2034 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sits LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utilityand Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lis.Tero. Management Restoration Volume Class A Class B Class C GTCC Processed Crft Contractor Index Activ iDescription Cost Cost Costs Costs Costs Costs Costs Contlngency Costs Costs Costs Costs Cu. Feet Cu.Feet Cu. Feet Cu. Feet Cu. Feet WI. Lbs. Manhosre Manhours PERIOD 3c - Fuel Storage Operations/Shlpping Period 3c Collateral Costs 3c.3.1 Spent Fuel Capital and Transfer 9,855 1.478 11,334 11,334 3c.3 Subtolal Period 3c Collateral Costs 9,855 1,478 11,334 11,334 - -- -

Period 3c Period-Dependent Costs 3c.4.1 insurance 8.525 852 9,377 9,377 3c.42 Property taxes 78 Be 86 3c.4.3 Plant energy budget 3c.4.4 NRC ISFSI Fees 4,964 496 5,460 5,460 Emergency Planning Fees 16,486 1.649 18,135 18,135 3c.4.5 3c.4-6 ISFSI Operating Costs 1-660 249 1.909 1,909

• 1,101,291 3c.4.7 Security Staff Cost 48,727 7,309 56,036 56,036 16,889 2.533 10,422 19,422 275,323 3c.4.8 UtilityStaff Coat 3c.4 Subtotal Period 3c Pedrod-Dependent Costs 97,329 13,097 110,425 110,425 1,376,614 107.184 14,575 121,759 121,759 1,376,614 3c.0 TOTAL PERIOD 3c COST PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Acivities Nuclear Steam Supply System Removal 3d.1.1.1 Vessel &Intemat GTCC Disposal 660 7,470 S 1,186 9,316 9,316 508 89,497 660 1,186 0,310 9,316 508 89,497 3d,1.1 Totals S 7,470 660

• 7,470 1,186 9,316 9,316 508 89,497 3d. I Subtotal Period 3d Activty Costs Period 3d Collateral Costs 3d.3.1 Spent Fuel Capital and Transfer *- - - 76 11 87 07 -

3d.3 Subtotal Period 3d Collateral Costs -- -79 11 87 87--

Period 3d Period-Dependent Costs 3d.4.1 Insurance 17 2 18 18 3d.42 Property taxes 0 0 0 3d.4.3 Plant energy budget 3d.4.4 NRC ISFSI Fees a 1 8 8 3d.4,5 Emergency Planning Fees 32 3 36 364 3 0 4 4 3d.4.6 ISFSI Operating Costs -2160 3d.4.7 Security Staff Cost 96 14 110 110 33 5 38 38 540 3d.4.8 UtilityStaff Cost 189 25 214 214 2,700 3d.4 Subtotal Period 3d Period-Dependent Costs 302 508 89,497 2,700 3d.0 TOTAL PERIOD 3d COST 660 7,470 265 1.223 9,618 9,318 PERIOD 3e - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 3e Additional Costs 3e.2.1 ISFSI Decontamimation 1.012 9 24 60 1,250 460 2,811 2,811 1,175 165.113 26.509 2,560 1,012 6 24 60 1,250 460 2,811 2,811 1,175 165,113 26,509 2,560 3e.2 Subtotal Period 30 Additional Costs Period 3e Collateral Costs 2 16 16 3e.3.1 Small tool allowance 14 5 1 9 6 3e.3.2 Spent Fuel Capital and Transfer 14 5 3 22 22 3e.3 Subtotal Period 3e Cotateral Costs TLG Services, Inc.

Cooper NuclearStation Document NO1.1590-002,Rev. I Deco .un-ioning Cost Analysis Appendix D, Page 1 of"35 Table D-1 Cooper Nuclear Station 2034 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utilty and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Li. Term. Management Restoration Volume Ciss A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Casts Costs Costs Costs Contln en Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Faet Cu. Feet Cu. Feet WL, Lbs. Manhours Manhours Period 3e Period-Dependent Costs 3e.4.1 Insurance 145 14 159 109 3e.4.2 Property taxes - - 1 0 1 3e.4.3 Heavy equipment rental 232 35 267 267 3e.4.4 Plant energy budget 3e.4.5 Security Staff Cost 303 46 349 349 5,013 3e.4.6 UtflityStaff Cost 249 37 287 287 38803 3A.4 Subtotal Period 3e Peitod-Dependent Casts 232 699 132 1,063 1,063 6,816 3e.0 TOTAL PERIOD 30 COST 1,258 6 24 60 1,954 595 3,896 3,896 1,175 165,113 28,509 11,376 PERIOD 3f -ISFSI Site Restoration Period 3f Direct Decornrrissioning Activities Period 3f Additional Costs 3f.2.1 ISFSi Dernolition 672 - 44 107 824 824 - 5,898 160 3W.2 Subtotal Period 3WAdditional Costs 672 - 44 107 824 824 - 5,898 160 Period 3f Collateral Costs 31.3.1 Smealtool atowance - 3 * . - 0 4 4-

• 31.3 Subtotal Period 3f Collateral Costs

• 3 * - 0 4 4 Period 3f Pedod-Oepenvent Costs 314.1 Insurance 31.4.2 Propedy taxes 1 0 1 1 3f.4.3 Heavy equipment rental 79 12 91 91 3A.44 Plant energy budget 3X.4.5 Security Staff Cost 155 23 179 179 2,569 3WA.6 UtaityStaff Cost - 110 16 126 126 1,594 31.4 Subtatal Period 3WPeriod-Dependent Costs 79 266 52 396 396 4,163 31.0 TOTAL PERIOD 3f COST 754 310 160 1,224 1.224 5,898 4,323 PERIOD 3 TOTALS 15,495 666 24 - 7,530 134,148 22,108 179,970 9,495 137,768 32,707 - 1,175 - 508 254.610 133,486 1,733,537 TOTALCOST TO DECOMMISSION 9.296 58.392 11,201 7,212 30.933 56,732 437,605 111,599 722,972 506,207 182,368 34,396 319,826 234.031 3,647 1,205 508 31,649,200 915,901 5,434.429 TlG Services, Inc.

Coop-rNtudnaStation Document N0I.1590-002,Rev. 1 De~commissioning Coot Analysis Appendix D, Page 12 of"35 Table D-1 Cooper Nuclear Station 2034 DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and i DecO0 Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor ctviy Cost Cast Costs Casts Casts Costs Costs Contlaoonnon Casts Casts Casts Costs Cu. Fant Cu. Fent Cu. Fant Cu. Foot Cu. Fant Wit. Lbs. Manhoure Manhours I I I*ez A*UV* *rml*n B

ex cast Cast Costs Costs Costs costs Costs Contingency Costs costs Costs coati Cu. Fast Cu Feel Cu. Fast Cu. Feet . Fast Manhours Manhours TOTALCOST TO DECOMMISSIONWITH 18.25% CONTINGENCY: $722,972 thousands of 2008 dollars TOTALNRC UCENSE TERMINATIONCOST IS 70.02% OR: $506.207 thousands of 2008 dollars SPENTFUEL MANAGEMENTCOST IS 25.22% OR: $182.368 thousands of 2008 dollars NON-NUCLEARDEMOLITIONCOST iS 4.76% OR: 024,396 thousands of 2008 dollam TOTALLOW-LEVELRADIOACTIVEWASTE VOLUME BURIED (EXCLUDING GTCC): 238,883 cubic feet TOTALGREATER THANCLASS C RADWASTE VOLUMEGENERATED: 600 cubic feet TOTALSCRAP METAL REMOVED: 30.340 tons TOTALCRAFT LABOR REQUIREMENTS: 915,901 man-hours End Notes:

ra - Indicates that his acvity not charged as decommissioning expenrse a - indicates that this activity performed by decommissioning staff.

0 - indicates thra this value is less than 0.5 but is non-zem.

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

CooperNuclear Station Document N01-1590-002, Rev. 1 DecornmissioningCost Analysis Appendix D, Page 13 of 35 Table D-2 Cooper Nuclear Station 2034 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utilityand Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic.Term. Management Restoration Volume Class A Class B Close C GTCC Processed Craft Contractor eIndex Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet WI. Lbs. Manhours Mahours PERIODis - Shutdown through Transition Periodla DirectDecommissioning Activities le.1.1 SAFSTOR site characterization survey 346 104 450 450 lu 1l2 Prepare preliminary decommissioring cost 130 20 150 150 1,300 1a.1.3 Nctiticaton of Cessation of Operations a rda 10.14 Remove furl & source material

i. 1.5 Notificaton of Pernranent Defuelrng is. 1.6 Deactivate plant systems &process waste 200 30 230 230 2,000 ta.1.7 Prepare and submit PSDAR u.I .8 Review plant dwgs & specs. 130 20 150 150 1,300 10.1.9 Perform detailed red survey 100 15 10 115 1,000 ul.10 Estimate by-product inventory 100 15 115 115 1,0O00 1a.1.11 End product descrrption 1.500 10.I.12 Detailed by-product inventocy 150 23 173 173 1,000 1:.1.13 Def-oe major morksequence 100 15 115 115 I0. 1.14 Perform SER and EA 310 47 357 357 3,100 1a.1.15 Perform Site-Specific Cost Study 500 75 575 575 5,000 ActivitySpecifications 18.1.16.1 Prepare plalt and faciities for SAFSTOR 492 74 566 566 4,920 417 63 479 479 4,167 la.1.6.2 Plant systems 1a.1.15.3Plant structures and butilings 312 47 359 359 3.120 la.l,16.4 Waste management 200 30 230 230 2.000 10.1.16.5 Facility and site dormancy 200 30 230 230 2,000 1,621 243 1,864 1.864 16,207 1a.1.16 Total Detailed Work Procedures la.1.17.1 Plant systems 18 136 138 1,103 18 138 138 1,200 la.t.17.2 Facility closeout &dormancy - . . - . . 120 la.1.17 Total * . . - . - 238 36 274 274 2,383 lus1.18 Procure vacuum drying system 10 2 12 12 100 la.1.19 Drain/de-energie non-cort. systems a

la.1.20 Drain &dry NSSS la.1.21 Drain/de-energizecontaminated systems la-. 22 Decon/securecontaminated systems 3,930 642 4.577 4,077 35.890 la.1 Subtotal Period 10Activty Costs Penod Ia Collateral Costs la.3.1 Spent Fuel Capital and Transfer * -- - - - 2,721 408 3,129 3,129 - . .

1a,3.2 Corporate Overheads - . - -3,105 466 3,570 3,570 1l.3 Subtotal Period tu Collateral Costs * .. . . . 5,825 874 6,699 3,570 3,129 Peniod 10Period-Dependent Costa la.4.1 Insurance 1,600 160 1.760 1,760 1:.4.2 Property taxes 4 0 4 4 1.4.3 Health physics supplies 370 63 463 463 1:.4.4 Heavy equipment rental 368 - 55 423 423 1 a.4.5 Disposal of DAW generated 5 73 19 100 100 1,575 14,445 5 la.4.6 Plant energy budget 927 139 1.066 1,066 1a.4.7 NRC Fees 71 776 776 1:.4.6 Emergency Planning Fees 1,165 11i 1,303 1,303 1A.4.9 Spent Fuel Pool O&M 745 112 857 857 1a,4.10 ISFSI Operating Costs 85 13 68 - 98 6,021 903 6,924 6,924 157.471 1a,4.11 Security Staff Cost TLG Services, Inc.

Cooper NuclearStation Document N0-1590-002,Rev. 1 DecommissioningCoast Analysis Appendix D, Page 14 of 35 Table D-2 Cooper Nuclear Station 2034 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and I Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor IActivity ACBV*

• nD[*g Cost Cost Costs Costs Costs Costs Costs Continienon Costs Costa Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feat Cu. Feet Wt. Lts. Manors Manhours I II InnBx n ex ri n Period 1a Period-Dependent Costs (conifnued) la.4.12 Utility Staff Cost * - 23,690 3-403 26,093 26,093 - - 423,400 1..4 Subtotal Period la Penod-Dependent Costs 738 3 73 33,962 5,087 39,867 37,609 2,258 1,675 14,445 5 580,871 la.0 TOTAL PERIOD l a COST 738 3 73 43,723 6,603 51,144 45,757 5,387 1,575 14,445 5 616,761 PERIOD lb - SAFSTOR Limited DECONActivities Period lb Direct Decormissioning Actvities Decontamination of Site Buildings 1b 1.1.1 Reactor 2.929 1,465 4,394 4,394 68,438 lb. 1.1.2 Augmented Radwaste 52 26 78 78 1,562 lb.1.1.3 Misceltaneous Sb'uctures - Contaminated 376 188 565 565 6,542 1b.1.1.4 Muli-Purpose Facility 68 34 101 101 2,036 1b.1-.15 Radwaste 158 79 237 237 4,761 Ib.1.1.6 Turbine 520 260 780 780 15,667 lb.1.I Totals 4,103 2,052 6,155 6,155 101,060 Ib.1 Subtotal Period 1b Activity Costs 4,103 2,052 6,155 6,155 101,008 Period lbAdditiomal Costs lb.2.1 Spent Fuel Pool Isolation .- . 9,407 1,411 10,818 10,818 lb2.2 Asbestos Insulation Disposal 773 1 65 558 265 1,662 1,662 10,333 134.329 10,002 lb.2 Subtotal Period Ib Additional Costs 773 1 65 558 9,407 1,676 12,480 12,480 10,333 134,329 10.002 Period 1b Collateral Costs 1b.3*1 Decon equipment 713 - - - - 107 820 820 Ib.3.2 Process liquid waste 229

• 74 392 448 293 1,436 1,436 1,561 93,644 304 1b.3.3 Small tool allowance 70 - - 11 61 81 lb.3.4 Spent Fuel Capital and Transfer 930 130 1,069 - 1,009 lb.3.5 Corporate Overheads ..- - 766 115 880 880 lb.3 Subtotal Period lb Cotateral Costs 942 70 74 392 448 1,695 665 4,286 3,217 1,069 1,561 93,644 304 Period lb Period-Dependent Costs Wb4.1 Decon supplies 1,156 - - - 289 1,445 1,445 1h4.2 Insurance - -121 12 133 133

• - 1 0 1 1 1b.4.3 Property tavos 1b.4.4 Health physics supples 473 118 592 592 lb.4.5 Heavy equipment rental - 01 - - . - 14 104 104 1b.4.6 Disposal of DAWgenerated 5 3 81 - 21 110 110 1,741 15.98 5 lb.4.7 Plant energy budget 229 34 263 263 lb.4.6 NRC Fees 174 17 191 191 lb.4.9 Emergency Planning Fees 292 29 321 321 1.b4.10 Spent Fuel Pool O&M 184 28 211 211 1b.4.11 ISFS1Operating Costs 21 3 24 - 24 lb.4.12 Security Staff Cost 1,485 223 1,707 1,707 38,829 1b.4.13 Utiliy Staff Cost 5,595 839 6,434 6,434 - .104,400 lb.4 Subtotal Period 1 b Penod-Dependent Costs 1.156 564 5 3 81 8,101 1,628 11,538 10,981 557 1,741 15,968 5 143,229 lb.0 TOTAL PERIOD lb COST 6,201 1,407 so 460 1,087 19,203 6,020 34,458 32,833 1,626 13,635 243,942 111,318 143,229 TLG Servdveea Inc.

Cooper Nucekar Stai~on Document N01-1590-002, Rev. I DecomomissioninogCost Analysis Appendix D, Page 15 of"35 Table D-2 Cooper Nuclear Station 2034 Delayed DECON Decommnissioning Cost Estimnate (thousands of'2096 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utntyoad n

IActivity Oecon coot Removal Cost Packaging Coots Transport Coots Processing Costs Disposal Costs Other Costs Total Continoorco Total Costs LiO.Term.

Costs Management Cost.

Restoration Ceot.

Volume Cn. Foot Class A Cu. Foet Clans B Clans C Cu. Feet Cu. Foot GTCC Co. Foot Processed est. Ltt.

Craft Manhon,,

Contractor Masnhour.

I m Innnx A*VZ* *CMnZ*n n as A v c n Cost Cast costs Costs Costs costs Costs Cortina"" Costs Costs Costs Costs Cu Fast Cu I Cu Fast Cu. Feet Cu. Fast Wt Los Manhours PERIOD Ic - Preparations for SAFSTOR Dormancy Period lc Direct Decommlssionirg Activities lC.1.1 Prepare support equipmenrt for storage 387 58 445 445 3.0D0 it. 1.2 Install containment pressure equal. lines 31 36 700 5 36 Ic.1.3 Interim surpey prior to dormancy - 733 220 953 53 15,696 1c.1.4 Secure building accesses Ic.1.5 Prepare &submit ioterim report 58 0 67 67 - *583 IC.1 Subtotal Period Ic Activiy Costs 419 791 291 1,501 1,501 19.396 583 Period lc Collateral Costs lc.3.1 Process liquid waste 235 76 403 460 301 1,475 1,475 1,603 96,195 313 lc.32 Small tool aliowance 3 0 3 3 lc.3.3 Spent Fuer Capital and Transfer 940 141 1,081 - 1,081 lc.3.4 Corporate Overheads - 774 116 890 890 lc.3 Subtotal Period It Coltateral Costs 235 3 76 403 460 1,714 558 3,449 2.368 1,081 1,603 96,195 313 Period ic Period-Dependent Costs 1cA.1 Insurance 122 12 134 134 IcA4.2 Property loves 1 0 1 1 lc.4.3 Heath physics supplies 160 - 40 200 200 1C,4.4 Heavy eqaipment rental 92 - 14 105 105 1.4.5 Disposal of DAWgenerated 1 I s1 - 5 25 25 393 3,601 1 1c.4.6 Plant energy budget 231 35 266 266 1c.4.7 NRC Fees 176 18 194 194 lc.4.8 Emergency Planning Fees 295 30 325 325 lc,4.9 Spent Fuel Pool O&M 188 28 214 214 Itil 0 ISFSI Operating Costs 21 3 24 - 24 1c.4.11 Securdy Stafl Cost 1,501 225 1,726 1,726 39.260 lc.4.12 Utlity Staff Cost 5.657 849 6,505 6.505 - 105,560 1c.4 Subtotal Period Ic Penod-Oependent Costs 252 1 1 18 8,191 1,257 9,720 9,157 583 393 3,601 1 144,820 lc.0 TOTALPERIOD Ic COST 235 673 77 404 478 10.696 2,107 14.670 13,026 1,644 1.996 99,796 19,710 145.403 PERIOD 1 TOTALS 6,437 2.818 162 866 1.636 73.621 14.730 100,272 91,616 8.657 17,205 358,183 131.033 905.393 PERIOD 2a - SAFSTOR Dormancy with Wet Spent Fuel Storage Period 2a Direct Decommissioning Activities 2a.1.1 Quarterly Inspection 2a.1 .2 Semi-annuol environmental survey a 2a 1.3 Prepare reports 20.1.4 Bitominous roof replacement * - . - 63 9 73 72 2a. 1.5 Maintenance supplies * - .

• 553 126 629 629 20.1 Subtotal Period 2a ActivityCosts * -- -566 135 701 701 Pedod 2a Coliateral Costs 2a.3.1 Spent Fuel Capital and Transfer -- - - 21.155 3,173 24,329 - 24,329 2a.3.2 Corporate Overheads *. - - 4.139 621 4,759 4,759 2a.3 Subtotal Period 2a Collateral Costs 25.294 3,794 29,069 4,759 24,329 Penod 2a Period-Dependent Costs 2a.4.1 Insurance 1,962 196 2,158 2,158 2a,4.2 Property laces 16 2 18 18 2a.4.3 Health physics supplies 344 86 430 430 TLG Services, Inc.

0 Document N01.1590-002, Rev. I Cooper Nuclear Station Appendix D, Page 16 of 35 Decommissioning Cost Analysis Table D-2 Cooper Nuclear Station 2034 Delayed DECON Decommissioning Cost Estimate (thousonds of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and I Packaging Transport Processing Disposal Other Total Total Lc. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Decon Removal I Act.iity m n ex Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Faet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours I Period 2a Period-Dependent Costs (iconnued) 39,139 13 13 7 198 - 52 270 270 - 4,267 2a.4.4 Disposal of DAWgeeerated 2a.4.5 Plant energy budget 742 111 053 - 853 2a.4. NRC Fees 007 01 887 887 -

3,374 337 3.712 - 3,712 28.4.7 Emergency Planning Fees 2a.4.8 Spent Fuel Pool O&M 2.984 448 3.431 3,431 340 51 391 391 2a,4.9 ISFSI Operating Costs 444,561 2a.4.10 Security Staff Cost 17.728 2,659 20,387 20,387

- 21,639 329,769 2a.4.11 Ublity Staff Cost 188-816 2,822 21,639 344 13 7 198 46.768 6,845 54.176 1,587 52.588 4,267 39,139 13 774,330 28.4 Subtotal Period 2a Perod-Deeondent Costs 344 13 7 198 72.628 10.775 83,965 7T048 76,917 4,267 39.139 13 774.330 20.0 TOTALPERIOD 2a COST PERIOD 2b - SAFSTOR Dormancy with Dry Spent Fuel Storage Pedod 2b Direct Decommissioning ti Activities 2b.1.1 Quarterly Inspec on 21b.1.2 Semi-annual environmental survey a 2b.1.3 Prepare reports 2b.1.4 Bituminous roof replacement 354 53 407 407 2b.1.5 Maintenance supplies 2,825 706 3,531 3,531 2b 1 Subtotal Period 2b ActivityCosts 3.178 759 3,938 3,938 Penod 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 13,214 1,982 15,197 15,197 2b.3 Subtotal Period 2b Collateral Costs 13,214 1,982 15.197 15,197 Pedod 2b Period-Dependent Costs 2b.4.1 Insurance 9,796 980 10,775 10.775 90 9 99 -99" 21.4.2 Property taues 2b.4.3 Health physics supples 1,620 - 405 2,025 2,025

- 66 36 1,037 - 271 1,411 1,411 - 22,311 204,651 68 2b.4.4 Disposal of DAW generated 2b.4.5 Plant energy budget 2.083 312 2,395 - 2.395 2b.4.e NRC Fees 4.528 453 4,981 4,981 2b.4.7 Emergency Planning Fees 18.944 1,894 20,838 - 20,838 2b.4. ISFSI Operating Costs 1,908 286 2.194 2,194 57,312 8,597 65,909 65.909 1,265,451 2b.4.9 Security Staff Cost 2b.4.10 UtilityStaff Cost 41,970 6,295 48,265 48,265 749,897 1,620 66 36 1.037 136.630 19,503 158.892 8,416 150,476 22,311 204.651 68 2,015,349 2b.4 Subtotal Period 2b Period-Oepenrdent Costs 1.620 66 36 1.037 153,023 22,244 178,026 12,354 165,672 22.311 204,651 68 2.015.349 2b.0 TOTAL PERIOD 2b COST 78 43 1,236 225,651 33,019 261.991 19,402 242,589 26,578 243,790 681 2.789.679 PERIOD 2 TOTALS 1,964 PERIOD 3a - Reactivate Sits Following SAFSTOR Dormancy Period 3a Direct Decorrmmusioning Actnifies 3a.1.1 Prepare prelminadry decommissioning cost 130 20 150 150 1.300 3a.1.2 Review plant dwgs & specs. 460 69 529 529 4.600 3a.1.3 Perform detailed rod su*rey a 100 15 11. 115 1,000 3a.1.4 End product description 130 20 150 150 1,300 3a. 1.5 Detailed by-product inventory 3a. 1.6 Defires major work sequence 750 113 863 863 7,500 310 47 357 357 3,100 3a.1.7 Perform SER and EA 3a.1.8 Perform Sts-Speciflc Cost Study 500 75 575 575 5,000 3a. 1.9 Prepare/subrmit License Terninabotn Plan 410 61 471 471 4.096 3a. 1.10 Receliv NRC approval of termination plan a TLG Services, Inc.

DocumentN01.1590-002, Rev. 1 Cooper Nuvkar Station Appendix D, Page17 of 35 Dereoziiaaonig CostA-mlysis Table D-2 Cooper Nuclear Station 2034 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sita LLRW NRC Spent Fuel Sits Processed Burial Volumes Burial I Utilityand Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic.Tenm. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs CostsCosts Costs Costs Cu. Fent Co.Fee Cu. Feet Cu. Feet Cu. Feet WI. Lbs. Manhours Manhours ActivitySpecifications 737 111 848 763 7,370 3a.1.11.1 Re-activate plant &temporary focilities 417 63 479 431 4,167 3a.1.11.2 Plant systems 7.100 710 107 817 917 3a.1.11.3 Reactor internals 6.500 650 98 748 748 3a.1.11,4 Reactor vessel 500 50 8 58 58 3a.1.11-5 Sacriflcial shield 1,000 Moisture separators/rerheaters 100 15 115 115 3a.1.11.6 92 160 24 184 92 11.600 3a.1.11.7 Reinforced concrete 209 31 240 240 2,088 3a.1.11 .8 Main Turbine 209 31 240 240 2,088 30.1.11.9 Main Condensers 200 30 230 230 2,000 3a.1.11.10 Pressure suppression structure 160 24 184 184 1,6w0 3a.1.11.11 Drysell 312 47 359 179 3,120 3a.1.11.12 Plant structures &buildings 460 69 529 529 "52 4,600 3a. 1.11.13 Waste management 90 14 104 52 900 3a.1.11.14 Faciity &site closeout 456 4.463 669 5,133 4,677 44,633 3a.1.11 Total Planning & Sits Preparations 240 36 276 276 2.400 30.1.12 Prepare dismantling sequence 3a.1.13 Plant prep. &temp. svoes 2,700 405 3,105 3,105 140 21 161 161 1,400 3a.1.14 Design "ster clear.up system Rigging/Cont. Cotd Envlps/tooUngletc. 2,100 315 2,415 2,415 3a.1.15 1.230 3a.1.16 Procure casistliners &containers 123 10 141 141 12,556 1,883 14,439 13,983 456 77,559 30.1 Subtotal Period 3a ActivityCosts Period 3a Period-Dependent Costs 420 42 462 462 30.4.1 Insurance 3a.4.2 Property taxes 4 0 4 4 324 81 405 405 3a.4.3 Hea*th physics supplies 3a.4.4 Heavy equipment rental 368 55 423 423 2 62 16 84 84 1.329 12,190 4 3a.4.5 Disposal of DAWgenerated 027 130 1.066 1,096 3a.4.6 Plant energy budget 249 25 274 274 3a.4.7 NRC Fees 3a.4.8 Security Staff Cost 2,855 428 3,283 3,203 65,179 UtitilyStaff Cost - 14,190 2.128 16,318 16,318 - 258,629 3a.4.9 4 323,807 691 2 62 18.644 2,915 22,318 22.318 1.329 12.190 3a.4 Subtotal Period 3a Perlod-Depenoent Costs 691 62 31.200 4,799 36,758 36,302 456 1.329 12,190 4 401,366 3a.0 TOTAL PERIOD 3a COST PERIOD 3b - Decommissioning Preparations Perod 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 473 71 544 490 54 4,733 400 60 460 460 4,000 38.1.1.2 Reactor internals 135 20 155 39 116 1,350 3b.1.1.3 Remaining buildings 1,000 310.1.1.4 CRD housings &Nis 100 15 115 115 100 15 110 115 1.000 3b.1.1.5 Incore instrumentation 200 30 230 230 2,000 3b.1.1.6 Removal primary containment 363 54 417 417 3,630 3b.1.1.7 Reactor vessel 120 18 138 69 1,200 3b.1.1.8 Facility closeout 69 120 18 138 138 1,200 3b, 1.1.9 sacrifcial Shield 100 15 115 58 58 1,000 3b.1.1.10 Reionorced concrete 208 31 239 239 2,080 3b'1.1.11 Main Turbine 209 31 240 240 2.088 3b01 1.12 Main Condensers TLG Services, Inc.

Cooper Nuclear Sftaton DocumentN01-1590-002, Rev. I Decn reiasioning Cost Analoysis Appendix D, Page18 of 35 Table D-2 Cooper Nuclear Station 2034 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars) off-Site LLRW NRC Spent Fuel site Processed Burial Volumes Burial I Utility and Decon Removal Packaging Transport Processing Disposal Other Total Total Lie. Term. Management Restoration Volume Clans A Class B Clase C GTCC Processed Craft Contractor I Actity.

m InlAY ACHV* *CN* Cost Cost Costs Costs Costs Costs Costs Continnosno Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Fast Cu. Feet Cu. Feet Wt. Lbs. Manhours MachoursI n ex v c Detailed Work Procedures (continued) 3b*1.1.13 Moisture separalors & reheaters 200 30 230 230 2,000 3b1.1.14 Radwastebuilding 273 41 314 283 31 2,730 3b 1.1.15 Reactor building 273 41 314 283 31 2,730 3.274 491 3,765 3,405 360 32.741 3b.1.1 Total 3b,1 Subtotal Period 3b Actvity Costs 3,274 491 3,765 3,405 360 32,741 Period 3b Addtl~onal Costs 3b.2.1 Site Charactetization 5,395 1,619 7.014 7,014 3b.2 Subtotal Period 3b Additional Costs 5.395 1,619 7.014 7,014 Period 3b Collateral Costs 3b.3.1 Decon equipment 713 - 107 820 820 3b.3.2 DOC staff relocation expenses 912 137 1,049 1.049 3b.3.3 Pipe cutting equipment - 1,000 - 150 1,150 1.150 3b.3 Subtotal Period 3b Collateral Costs 713 1.000 912 394 3,019 3.019 Period 3k Period-Dependent Costs 3b.4.1 Decon supplies 22 5 27 27 3b.4.2 Insurance 246 25 270 270 3.4.3 Property taxes 2 0 2 2 3b.4,4 Health physics supplies 179 45 224 224 3b.4.5 Heavy equipment rental 184 28 212 212 3b.4.6 Disposal of DAWgenerated 35 9 48 48 754 6,913 2 3b.4.7 Rant energy budget 465 70 534 034 3b.4,8 NRC Fees 125 12 137 137 31.4.9 Security Staff Cost 1,431 215 1,646 1,646 32,679 3b.4.10 DOC Staff Cost 4,370 657 5,035 5,035 58,560 3b.4.11 UWllyStaff Cost - 7.114 1,067 8,181 8,151 - 129,669 3b.4 Subtotal Period 3b Period-Dependent Costs 22 363 35 13,761 2,133 16,317 16,317 754 6,913 2 220,907 31.0 TOTAL PERIOD 3b COST 735 1,303 35 23,342 4,636 30,115 29,755 360 754 6.913 2 253,648 2

PERIOD 3 TOTALS 735 2,055 6 97 54,542 9,435 668,72 66,056 816 2,083 19,104 6 655,014 PERIOD 4a - Large Component Removal Period 4a Direct Decommissioning Actvimies Nuclear Steam Supply System Removal 4a.1.1.1 Recirculation System Piping & Vatnes 16 70 14 14 25 272 101 512 512 100 897 119,606 2.487 -

4a.1.1.2 Recirculation Pumps &Motors 6 28 11 28 321 95 488 488 - 1,188 132,880 1,125 4a.1.1.3 CROMs &Nis Removal 24 139 377 68 317 - 174 1,099 1,099 6.935 - - 126,494 3,972 4a.1.1.4 Reactor Vessel Internals 86 1,959 3,871 912 5.607 155 5,535 18,124 18.124 1,878 1,252 470 - 359,044 18,900 888 4a. 1.1.5 Vessel & Internals GTCC Disposal 7,470 1,120 8.590 8.590 - - 508 89,497 4a.'1.1.6 Reactor Vessel 5,054 906 351 - 4,408 155 6.332 17,205 17,205 11,247 2,859 - - 1,447,089 18,900 888 4a. 1.1 Totals 132 7.250 5,179 1,371 25 18,395 309 13.357 46,018 46,018 100 22,145 4,111 470 508 2.274,610 45.384 1.776 Removal of Major Equipment 4a 1.2 Main TurbinelGenerator 167 845 372 6,376 1,138 8,898 8,898 61,604 2,772,179 4,438 4a 1.3 Main Condensers 706 588 259 4,439 940 6,932 6,932 42,889 1,930,000 19.519 Cascading Costs from Clean Building Demolation 4a.1.4.1 Reactor 260 - 39 299 299 2,486 4a.1.4.2 Augmented Radwaste 25 4 28 26 235 4a.1.4.3 Radwaste 43 7 50 50 359 TLG Ser-ices, Ins.

Cooper Nuclear Station DocumentNO-1590-002, Rev. I Appendix D, Page 19 of 35 Deeommissiaaoning Cosd Analvais Table D-2 Cooper Nuclear Station 2034 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars) off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and l Decon Removal Packaging Transport Processing Disposal Other Total Total Lc. Tens. Management Restoration Volume Class A class B Class C GTCC Processed Craft Contractor Actlnfty Cost Cost Costs Costs Costs Costs Costs Contlnoency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet W". Lbs. Manhours Mantrours I n ex ri In ActiVVl Cascading Costs from Clean BudildingDemolition (continued) 4a.1.4.4 Turbine 285 43 328 328 4,419 613 92 705 705 7,498 40.1.4 Totals Disposal of Plant Systems 4a.1.5.1 Augmented Radwasts E 877 ArealA 203 28 28 432 166 857 857 2,055 172.205 5,668 66 44 228 228 469 41,606 1,842 4a.1.5.2 Augmented Radwasta El 903 ArealA 6 7 104 52 10 9 139 50 260 260 765 55,345 1,432 4a.1.5.3 Augmented Rrdwasts El 918 ArealA 21 4 5 - 73 25 127 127 - 324 28,038 579 4a.1.5.4 Augmented Radmasta El 929 ArealA 3 0 0 4 1 8 8 38 1,529 75 4a.1.5.5 Augmented Radwaste El 929 Aeal B 457 1,289 458 2,373 2,373 5.726 513,627 12,634 40.1.5.6 DRYWELLArealA 85 84 112 1 5 75 2 41 235 235 806 10 33,576 3,304 4a.1.5.7 DRYWELLArealS 324 16 8s 1.477 317 2,220 2,220 - 15.808 641,963 9,170 4a.1.5.8 Turbine El 932 Areal B 1 9 *- 237 4a.1.5.9 Turbine El 932 Area2C 78 10 78 *78 - * - - 2,083 4a.1.5.10 Turbine El 932 Area3C 67 518 50 264 4,517 852 6,201 6,201 48.365 - 1,964,114 14,340 4a1.5.11 Yard ArealB 4a.1.5 Totals 1,831 202 487 6,073 2,040 1.964 12,597 12,510 87 65,016 9,348 3.453,003 51.444 4a.1.6 Scaffoldng in support of decommissioning - 2,049 24 11 168 23 547 2,921 2,121 1,821 101 81,992 27,411 Subtotal Period 4a ActivityCosts 132 12,616 6,838 2,500 17,081 20.457 309 18,039 77,972 77,885 87 171,229 31,594 4,111 470 508 10,511,780 155,694 1,776 4a.1 Period 4a Collateral Costs 69 - 24 125 143 91 451 451 - 498 - 29,865 97 4a.3.1 Process liquid waste 4a.3.2 Smail tool allowance 90 14 104 94 10

• 24 125 143 105 555 545 10 498 29,865 97 40.3 Subtotal Period 4a Collateral Costs 69 90 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 49 12 61 61 4a.4.2 Insurance 549 55 604 604 4a.4.3 Property taes 4 0 5 4 0 4a.4.4 Health physics supplies 944 236 1.180 1,180 4a.4.5 Heavy equipment rental 1,981 297 2.278 2,278 26 14 405 106 551 551 8,708 79,878 27 4a.4.6 Disposal of DAW generated -

4a.4.7 Flant energy budget 587 148 1,135 1,135 4a.4.8 NRC Fees 737 74 811 811 4a.4.9 Liquid Radwaste Processing EquipmenteSurvices 420 63 483 483 73,036 4a.4.10 Security Staff Cost 3,199 480 3.679 3,679 11,638 1,746 13.384 13,384 181,263 4a.4.11 DOC Staff Cost 16,014 2,402 18.416 18,416 292,143 4a.4.12 UtilityStaff Cost 4a.4 Subtotal Period 4a Penod-Dependent Costs 49 2,925 26 14 405 33.548 5,619 42,586 42,585 0 8.708 - 79,878 27 526,441 40.0 TOTALPERIOD 4a COST 250 15,631 6,887 2,640 17,081 21,005 33,858 23,762 121,113 121,016 98 171,229 40,800 4.111 470 508 10,621.530 155,818 528,217 PERIOD 4b -Site Decontamination Peded 4b Direct Decommissioning Activities 79 88 1,348 498 2,308 2,308 5,986 537,141 1,004 -

4b.1.1 Remove spent fuel racks 262 33 Disposal of Plant Systems 4b.1.2.1 Control El 882ArealB 280 178 1,178 1,178 - 7.213 292,908 7.797 7 39 674 5.155 4b.1.2.2 Control El03ArealC 170 25 195 195 -

4b.1.2.3 Control El 818ArnealC 66 10 76 76 - 2,100 22 3 28 26 702 4b.1.2.4 Control El 932 Areal C 4b.1.2.5 Intake 101 15 116 - 116 - 3,136 7 2,558 103,862 5,430 4b.1.2.6 Mua-Purpose Faciity 198 3 14 239 88 541 541 62 - 949 353 1.836 1,838 -

• 5,097 377,917 10.930 4b.1.2.7 Radwaste El 877 AvealA 398 75 TLG Service., Inc.

Cooper Nuclearo Station. Doaeamon,NOI.1590-002. Rev. I Decomissaionig CoastAnalysis Appenadix D, Page 20 of 35 Table D-2 Cooper Nuclear Station 2034 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sita LLRW NRC Spent Fuel Site Processed BurialVolumes BurialI Utilityand Activity Cecon Removal Packaging Transport Processing Disposal Other Total Total Lie.Tenn. Management , Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor lides Actviy Description Cost Cost Costs Costs Costs Costs Costs Contlo encv Costs Costs Costs Costs Cu. Feet- Cu. Fee Cu. Feet Cu. Feet Cu.Feet WI. Lbs. Manhours Manhours Disposal of Plant Systems (continued) 4b.1.2.8 Radwaste El 877 Area2A 43 9 7 113 41 213 213 613 44.992 1,189 18 13 201 72 372 372 1,156 79.983 1,969 4b.1.2.9 Radwaste El 877 A.ea3A 71 110 9 10 153 68 351 351 684 61.153 3,015 4b.1.2.10 Radaste El 903 AealA 175,093 5,282 188 36 29 439 165 856 856 1,955 4b.1.2.11 Radwaste El 903 Area2A 41,366 1.029 37 6 7 104 37 190 190 463 40b1.2.12 Radwast El 903 Area3A 12,033 477 18 2 2 30 12 64 64 135 4b.1.2.13 Radwaste E 918 AnnalA 15,667 448 16 3 3 39 15 75 75 201 4b.1.2.14 Radwaste El 918 Area2A 134,827 5,045 185 23 22 338 138 705 705 1,690 4b.1.2.15 Radwaste a] 918 Area3A 680 26 3 4 60 22 115 115 266 23,735 4b.1.2.16 Radwaste El 934 ArealA 98 11 12 177 72 370 370 8O8 70,665 Z663 4b.12.17 Radwaste El 934 Area2A 305 12 I 2 24 9 47 47 105 9,381 4b.1.2.18 Radwaste, E 949 ArealA 50 7 8 121 45 230 230 537 48,175 1,261 40.1.2.19 Reactor El 1001 ArealA 4 64 26 157 157 689 27.979 1,681 40t.1.2.20 Reactor E 1001 ArealB 62 1 15 16 248 83 430 430 - 1,091 97,874 2,024 4b.1.2.21 Reactor E[8595AealA 71 440 11 58 994 - 269 1,771 1,771 10,641 - 432,136 12,411 4b.1.2.22 Reactorl [ 859 ArealB 25 26 401 125 648 648 - 1,780 159,714 2,094 4b.1.2.23 Reactor El 859 Area2A 72 1 8 131 - 38 247 247 1.406 - 57,093 1,954 4b.1.2.24 Reactor [] 859 Area2B 69 9 - 137 48 251 251 S 9608 54,543 1,321 41b.1.2.25 Reactor El 859 Area3A 47 9 33 0 2 42 - 15 93 93 453 18,381 951 4b.1.2.26 Reactor El 859 Area3B 50 g 8 117 44 227 227 - 520 46,666 1,374 4b.12.27 Reactor Cl859 Area4A 13,424 476 17 0 2 31 - 9 59 59 331 -

4b.1.2.28 Reactor C 859 Area4B 1,798 16 17 262 85 443 443

• 1,163 104,381 4b.1.2.29 Reactor El 859 AreaSA 63 37 0 2 41 16 98 98 442 - 17.982 1,087 4b.1.2.30 Reactor C 859 AreaB5 259.190 10.497 401 56 42 651 275 1,424 1.424 - 2,892 4b.1.2.31 Reactor Ej903 ArealA 239.197 12,496 451 6 32 550 201 1,240 1,240 0.890 -

4b.1.2.32 Reactor"[ 903ArealB 4 0 0 - 6 3 14 14 26 2,372 120 4b.1.2.33 Reactor El 903Area2A 1,915 69 2 11 190 48 320 320 2,039 - 82,815 4b.1.2.34 Reactor El 903 Area2B 68,516 929 32 10 11 - 167 52 272 272 741 40.1,2,35 Reactor El 903 Area3A S21 1 3 52 14 90 90 553 22,464 618 4b.1.2.36 Reactor El 903 Area3B 27 8 9 136 43 223 223 606 54,373 776 4b.1.2.37 Reactor El 903 Area4A 597 21 t 3 52 - - 14 90 90 559 - 22,692 4b0.1.2.38 Reactor E 903 Area4B 670 3 3 2 52 20 104 104 232 20,858 40.1 2.39 Reactor E]031 ArealA 25 8 40 692 186 1,227 1,227 7,412 . 301,017 8,410 4b.12.40 Reactor El 931 Areal B 300 2 2 - 35 14 74 74 - 154 13,824 544 40.1.2.41 Reactor C 931 Area2A 20 0 0 1 0 1 3 3 9 0 371 53 4b.1.2.42 Reactor El 931 Area2B 2 77 23 22 338 109 567 567 1,651 134,007 2,165 40.1.2.43 Reactor CJ931 Area3A 49 0 0 1 3 3 8 340 4b.1.2.44 Reactor El 931 Area3B 2 4 28 767

,40.1.2.45 Reactor CJ931 Area4C 24 1 8 - 213 4b.1.2.46 Reactor El 931 Area5C 7 9 10 149 54 278 278 662 589,432 1,472 4b0.1.2.47 Reactor El 958ArealA 56 167 3 18 281 - 87 554 554 3,009 122,212 4,693 4b.1.2.48 Reactor El 958 Areal B 880 31 10 10

• 153 49 253 253 - 681 61.083 4b.1.2.49 Reactor EC958 Area2A 10 1 1 12 7 6 37 37 125 33 8,024 263 40.1.2.50 Reactor C 958 Area2B 898 4 3 48 21 109 109 - 214 19.185 4b.1.2.51 Reactor El 958 Area3A 33 14 10 6 7 39 39 109 29 7,011 410 4b.1-2.52 Reactor C 958 Area3B 1 1 11 1 1 16 7 36 36 72 6,482 298 4b.1.2.53 Reactor C 976 ArealA 147 5 25 422 104 703 703 4,521 183,615 3.931 4b.1.2.54 Reactor El 976 ArealB 7 1 1 13 5 26 29 57 5,138 172 40.1.2.55 Reactor EJ976 Area2A 23,813 1,033 37 1 3 55 18 114 114 586 4b.1.2.56 Reactor Cl976 Area2B 37 3 3 - 50 23 116 116 222 19,878 1,004 4b.1,2.57 Turbine El 882 ArealA 386 16 87 1,490 335 2,313 2,313 15,948 647,659 11,113 40.1.2.58 Turbine El 882 ArealB 584 21 2 2 29 13 67 67 - 129 11,556 4b.1.2.59 Turtbie El 882 Area2A 209 4 22 374 112 721 721 4,006 162,678 5,781

40. 1.2.60 Turbine C 882 Area2B 16 2 1 23 10 52 52 101 9,017 451 4b.1.2.61 Turbine C]882 Area3A 27 145 2,478 548 3,805 3,805 26,533 - 1,077.531 17,302 4b.1.2.62 Turbine El 882 Area38 607 9 1 1 - 15 6 32 32 68 6,127 232 4b.1,2.63 Turbine EC903 ArealA TLG Services, Inc.

Cooper Nuclear Station Document NOI-1590-002, Rev. I Decommissioning Cost Analysis Appendix D, Page 21 of 35 Table D-2 Cooper Nuclear Station 2034 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes BuriulI Utilityand Activity Decon Removal Packaging Transport Processing Disposal Other Total Total LIc.Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activtv Descrlptlon Cost Cost Costs Costs Costs Costst s sts Cootlnles CCosts Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt. Lbs. Manhours Manhours Disposal of Plant Systems (continued) 4b. 12.64 Turbine E4 03 AreaIS 974 46 241 4,133 - 904 6,299 6,299 44,251 1,797,054 27,674 4b, 1.2.65 Turbine El 903 Area2A 5 1 1 6 4 20 20 42 3.729 142 4b.1.2.66 Turbine El 903 Area2B 144 1 7 128 56 337 337 1,375 55,851 4.040 4b.1.2.67 Turbine El 903 Area3B 3 0 2 35 6 47 47 - 376 15,251 97 4b.1.2.68 Turbine El 903 Area3C 108 16 124 - 124 - - 3,412 4b.1.2.69 Turbine FA903 Aes4B 12 0 2 28 7 49 49 - 299 12,139 367 30 227 - 227 - 5,770 4b.1.2.70 Yard AealC 197 4b.1.2 Totals - 7.771 556 1.148 13.202 5,814 5,535 34,027 33,227 800 141.342 27,486 8,056,388 218,627 4b.1.3 Scaffolding in support of deconmnissioning 3,073 36 17 252 34 821 4,232 4,232 - 2,431 151 122,988 41,117 Decontamination of Site Buildings 4b.1.4.1 Reactor 2,880 1.820 202 422 4,911 2,376 3,310 15.922 15,922 52,579 39,536 6,069,283 115,053 45.1.42 Augmented Radwaste 52 19 4 6 23 60 51 215 215 242 1,099 119,326 1,978 4b.1.4.3 Miscelaneous Sruturms - Contaminated 368 167 15 42 759 62 363 1,777 1,777 8,129 452 372.774 12,956 4b,1 .4.4 MulU-Purp*se Facility 68 55 6 12 115 89 90 437 437 1,234 1,567 205,068 3,237 4b51.4.5 Radwaste 159 50 9 14 38 161 141 572 572 404 2,953 310,769 5,863 4b51.4.6 Turbine 526 142 35 51 64 633 477 1,928 1.628 688 11,664 1,193,496 18,679 4b5.1A Totals 4,055 2,253 271 547 5,910 3.362 4,432 20,850 20,850 63.275 57,271 8,270.774 157,769 4b.t Subtotal Period 40 Actvity Costs 4,318 13.131 942 , 1,800 19,364 10,578 11,285 61,417 60,618 800 207,048 90,895 16,987,290 419,513 Period 4b Additional Costs 4b.2.1 ISFSI Decontamination 1,012 6 24 60 1,250 460 2,811 - 2,811 1,175 165,113 26,509 2,560 4b.2.2 Final Ste Survey 1,205 362 1,567 1,567 12,460 4b.2 Subtotal Period 40 Additional Costs 1,012 6 24 60 2,455 821 4,378 1,567 2.811 1,175 165,113 26.509 15,040 Period 4b Coilateral Costs 4b.3.1 Process liquid vaste 143 - 49 262 299 190 944 944 1,042 62,521 203 4b.3.2 Small tooi allowance 235 35 270 270 4b.3.3 Decommissioning Equipment Disposition -6 50 621 84 130 973 973 6,000 373 303,507 68 45.3 Subtotal Period 45 Colluteral Costs 143 235 137 312 621 363 356 2,187 2,187 6,000 1,415 368,028 291 Period 4b Period-Dependert Costs 4b.4.1 Deconsupplies 1,252 313 1,564 1,564 4b.4.2 Insurance 1,192 119 1,312 1,312 45.4.3 Property tanes 10 1 11 11 4b.4.4 Health physics supplies 2,404 601 3,005 3,005 4b.4.5 Heavy equipment rental 4,270 641 4,911 4,911 4b.4.6 Disposal of DAW generated 55 31 876 229 1,191 1,191 18,832 172,741 58 4b.4.7 Plant energy budget 1,691 254 1,945 1,945 4b.4.8 NRC Fees 1,601 160 1,761 1,761 4b.4.9 LiquidRadwaste Processing Equipment/Servioes 913 137 1,049 1,049 4b.4.10 Security Staff Cost 6,945 1,042 7,987 7.987 158,571 4b.4.1I DOC StaflCost 24,622 3,693 28,315 28,315 339,977 45.4.12 Utiity Staff Cost 33,00 4,962 38,042 38,042 598,766 4b.4 Subtotal Period 4b Pedod-Dependent Costs 1,252 6.674 55 31 876 70,053 12,151 91,092 91,092 18,832 172,741 58 1,097,314 4b.0 TOTALPERIOD 4 COST 5,712 21,052 1,140 2,168 19,985 11.897 72,508 24,614 159,074 155,463 2,811 800 213,048 112.318 17,691,170 445,371 1,112.354 PERIOD 4a - License Termination PeFod 4e Direct Decommissioning Actvities

45. t.1 ORISE confirmatory survey 147 44 191 191 4e,1.2 Terminate license 48.1 Subtotal Period 4e ActivityCosts 147 44 191 191 TLG Services, Inc.

Cooper Nuclear Stations Document N01-1590-002, Rev. I Derooomia.ionaing Coast Anaolysi Appendix D, Page 22 of 35 Table D-2 Cooper Nuclear Station 2034 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars) 1o1.S110LLRW NRC Spo.lFuel Site Processed 50.i1,Volms Burial I Uility *sd Activity DOcon Removal Packaging Transport Processing Disposal Other Total Total Lin. Trom. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cast Costs Costs Costs Costs Costs Continaencs Costs Costs Costs Casts Cu. Feet Cu. Feet Cu. Feet Cu. Fast Cu. Fest Wt Lbs. Manhours Manhouos Perod 4a Additonal Costs 4e.2.1 Final Sits Survey 5.99S 1.799 7,797 7,797 148,435 6,240 5.998 1,799 7,797 7,797 148.435 6,240 4e.2 Subtotal Period 4e Additienal Costa Peiod 4e Collateral Costs 4e.3.1 DOC staff relocation expenses 912 137 1.049 1.049 48.3 Subtotal Period 4e Collateral Costs 912 137 1,049 1.049 Poed 4e Period-Dependent Costs 4e.4.1 Insurance 4e.4.2 Property tales 3 0 3 3 4e.4.3 Healthphysics supplies 736 184 920 920 4e.4.4 Disposalof DAWgenerated 1 42 - 11 57 57 907 8,324 3 4e.4.5 Plant energy budget 140 21 161 161 4e.4.6 NRC Fees 532 53 585 585 4e.4.7 Security Staff Cost 1,012 152 1,164 1,164 18,857 4e.4.8 DOC Staff Cost 4,458 669 5.126 5,126 57,357 4e.4.9 UtilityStaff Cost - - 4,695 704 5,399 5,399 - -

• 74,643 4e.4 Subtotal Period 4e Petiod-Dependent Costs 736 3 1 42 10,839 1,794 13,418 13,416 907 8,324 3 150,857 4e.0 TOTALPERIOD 4e COST 736 3 1 42 17,897 3,774 22,453 22,453 907 8,324 148.438 157,097 PERIOD 4 TOTALS 5,962 37.419 8.030 4,807 37,066 32.944 124,262 52,151 302,640 298,932 2,811 897 384,277 154.025 4.111 470 508 28,321.020 749,627 1,797.609 PERIOD Sb - Site Restaraton Period 5b Direct Decommissioning Activites Demolition of Remaining Site Buildings 5b.1.1.1 Reactor 1,491 224 1,715 1.715 14.601 55.1.1.2 Augmented Radwasta 222 33 255 255 2,119 5b.1,1.3 Control 214 32 246 246 1,655 523 78 602 6D2 5,621 5b.1..4 Intake Structue 5b.1.1.5 LLRWStorage Pad 145 22 167 167 1,227 5b.1.1.6 Miscellaneous Structures- Clen

• 1,199 179 1,375 1,375 11,837 5b.1.1.7 Misceltaneous Structues - Contaminated 27 4 30 30 572 5b.1.1.8 Mutb-Puroses Facility 123 18 141 141 1,982 5b.1.1.9 OWC Gas Generator 18 3 20 20 283 5b,1.1.10 Office 156 23 179 179 1.920 5b.1,1.11 Radwaste 391 59 449 449 3.229 5b51.1.12 Seal Well "17 3 20 20 166 5b.1.1.1 3 Sewage Treatment Area 4 1 5 5 53 5b.1.1.14 Transformer Yard 20 3 24 24 172 5b.51.115 Turbine 2,596 389 2,985 2,985 40,503 5.1.1.16 Tubine Pedestal 277 42 318 318 2,100 55.1.1 Totals 7,418 1,113 8.531 8,531 86,040 Site Closeout Activties 424 64 488 488 3,286 5b.1.2 Reovne Rubble 5b. 1.3 Grade & landscape site 578 87 665 - 665 1,578

55. 1.4 Final report to NRC 156 23 179 179 - 1.560 5,421 *- - - 158 1,286 9.863 179 9.684 92,904 1,560 5b.1 Subtotal Period 5b Acivity Costs Period SbAdditional Costs 5b.2.1 ISFSI Demolition 672 44 107 824 824 5,898 160 499 76 582 - 582 3,045 5b.2.2 Concrete Crushing 5b.2.3 Cofferdam 458 69 527 527 5,130 TLG Services, Inc.

CaaperA'odriw slolat- Documsent NO -1,590-002, Rev. I Deeomaisioneing CoadAnealysis Appensdix D, Page 23 of 55 Table D-2 Cooper Nuclear Station 2034 Delayed DECON Decommissioning Cost Estimate (thousands of 2008 dollars) m Decon Removal Packaging Transport aot-Ste Processing i Li.W Disposal Other* Total Total Ic.JcTrm.

Teom. MSpent guem Management siou Restoration Vrole Volume Ca A Class A urClas Class B Volumes Class CC C GTCC uril I Processed Craft UCilt anat CoratI IAdtivity I In*=v Artiw* *r*nt*n ACtIVITY Until tion Cost Cast cost. Costs Costs Costs Costs Contingency Costs Costs costs Costs CuFeet Cu Feet Cu Fast Cu Feet Cu Feet WL Lbs Manhoum 5b.2 Subtotal Period 5b Additional Costs 1,629 52 252 1.933 824 1.109- . 14,073 160 Period 5b Collatertl Costs 5b.3.1 Smal tool allowance 56 8 64 - 64 5b.3 Subtotal Period 5b Colateral Costs 56 8 64 - 64 -

Penod 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property tawas 7 1 8 8 5b.4.3 Heavy equipment rental 4.233 635- 4.869 - 4,869 - . -

5b.4.4 Plant energy budget 167 25 192

• 192 - . . -

5b.4.5 Security Staff Cost 2,419 363 2,782

• 2,7a2 . - . - 45,051 Sb4.6 DOC Staff Cost 10,212 1.532 11,744

• 11,744 - . - - 127,646 5b.4.7 Utlity Staff Cost 4,507 676 5,183 - 5,183. 73,209 5b.4 Subtotal Period 5b Pedod-Dependent Costs 4,233 17.312 3.232 24,777 24.777- - - - 245,906 5b.O TOTAL PERIOD 5b COST 14,339 17,520 4,779 36,638 179 824 235,634 - - - 106.977 247.626 PERIOD 6 TOTALS 14,339 17,520 4,779 36,638 179 824 35,634 106,977 247.626 TOTAL COST TO DECOMMISSION 13,133 58,595 8,276 5,720 37,066 35,914 495,597 114.112 768,414 476,185 254.881 37,348 384.277 199,891 4,111 470 508 28,942,100 987,724 6,395.380 TOTALCOST TO DECOMMISSION WITH17.44% CONTINGENCY: $768,414 thousands of 2008 dollars TOTALNRC LICENSE TERMINATIONCOST IS 61.97% OR: $476,185 thousands of 2008 do6am SPENT FUEL MANAGEMENTCOST IS 33.17% OR: $264,881 thousands of 2008 dollars NON-NUCLEARDEMOLITIONCOST IS 4.86% OR: $37,348 thousands of 2008 dolam TOTALLOW-LEVELRADIOACTIVEWASTE VOLUME BURIED (EXCLUDING GTCC): 204,472 cubic feet TOTALGREATER THAN CLASS C RADWASTE VOLUMEGENERATED: W08 cubic eset TOTALSCRAP METALREMOVED: 30.276 tons TOTALCRAFT LABOR REQUIREMENTS: 987,724 man-hours End Notes:

n/a - indicates that this actvity not charged as decommissioning expense.

a - indicates that this activity performed by decommissioning staff.

0 - indicates that this vatue is less than 0.5 but is ion-zeso.

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

CooperNuclear Station Docueanet NOI.1590.OOZ, Rev. I De-om.issioning Cost Analysia AppendixD, Page 24 of 35 Table D-3 Cooper Nuclear Station 2034 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

SOff-Site LLRW NRC Spent Fuel Site Processed BurialVolumes BurialI Utilityand Activity Decon Removal Packaging Transport Processing Disposal Other Total Total LIO.Term, Management Restoration Volume Clasw A Clans B Class C GTCC P acessed Croft Contractor Index ActivityDescription Cost Cost Costs Costs Costs Costs Costs Contanheac' Costs Costs Costa Costs Cu. Feet C.Ft Cu.'Feet C. .Feet Lbs. ManWouL Manhours PERIOD la - Shutdown through Transition Period 1a Direct Decommissioning Activities 1a.1.1 SAFSTOR site characterizotion survey 346 104 450 450 130 20 150 150 1,300 1a.1.2 Prepare preliminary decommissioning cost la.1.3 Ncotificationof Cessation of Operations a tria

.a.1.4 Remove fuel &source material la.1.5 Notifcation of Permanent Defueling 1.-1.6 Deactivate plant systems & process waste 200 30 230 230 2,000 18.1.7 Prepare and subirt PSDAR 130 20 150 150 1,300 Ia.1.,8 Re.ie plant dgs & specs.

10.1.9 Performrdetailed lad survey 100 15 115 115 1.000 1a.1.10 Estimate by-product inventory 1a.1,11 End product description 100 15 115 115 1.000 150 23 173 173 1,500 10.1.12 Detailed by-product inventory 100 15 115 115 1,000 10.1.13 Defre major work sectuence 10.1.14 Perform SER and EA 310 47 357 357 3,100 10.1.15 Perform Smie-SpecificCost Study 500 75 575 575 5,000 Activity Specrfications 492 74 566 566 4,920 1:.1.16.1 Prepare piant and tacilies for SAFSTOR 417 63 479 479 4,167 1a.1.18.2 Plant systems 312 47 359 359 3.120 la.1.16.3 Plant structures and buildngs 200 30 230 230 2,000 a.1.16,4 Wasts management 1a.1.16.5 Facilty and site dormancy 200 30 230 230 2.000 1a.1.16 Total 1.621 243 1 864 1.864 16,207 Detailed Work Procedures 118 18 136 136 1,183 10.1.17.1 Plant systems 120 18 138 138 1,200 1a.1.17.2 Facilitycloseout &dorrnancy 10.1.17 Total 238 36 274 274 2.383 1.1.16 Procure vacuum drying system 10 2 12 12 1a.1.18 Orairlde-energize non-cont. sypstes

.1.20 Drain &dry NSSS 0.1.21 Drainde-energize contaminated systems 1:.1.22 Deconlsecure contaminated system 10.1 Subtotal Period 1 a ActivityCosts 3,935 642 4,577 4,577 35,690 Period Ia Collateral Costs la.3.1 Spent Fuel Capital and Transfer - -- - - - 2,721 408 3,129 - 3,129 la.3.2 Corporate Overheads - -- - - - 3,105 468 3,570 3,570 10.3 Subtotal Period 10 Collateral Costs - -- - - - 5.825 874 6.699 3,570 3,129 Period 10 Period-Dependent Costs la.4.1 Insurance 1,600 160 1,760 1,760 la.4.2 Properly loves 4 0 4 4 1.4.3 Health physics supplies 370 93 463 463 1:.4.4 Heavy equipment rental 368 55 423 423 1 .4.5 Diaposal of DAW generated 5 73 - 15 100 100 1,575 14,445 5 10.4.6 Plant energy budget 927 139 1,066 1,060 1a.4.7 NRC Fees 706 71 778 776 tl.4.8 Emergency Planning Fees 1 1.85 110 1,303 1,303 10.49 Spent Fuel Pool O&M 745 112 857 857 1:.4.10 ISFSI Operating costs 85 13 98 - 98 0.4.11 Security Stafl Cost 6&021 903 6.924 6,924 157,471 TLG Services, Inc.

Cooper NuclearStation DocumentN01.1590-002, Rev. I DecommissioningCoast Analysis Appendix D, Page25 of 35 Table D-3 Cooper Nuclear Station 2034 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Sits LLRW NRC Spent Fuel Sits Processed Burial Volunses Burial Utilty and Activity escon Removal Packaging Transport Processing Disposal Other Total Total Lic. Teom. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contantor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Foat Cu. Feet Cu. Feet Cu. Feet W.L Lbs. Manhours Manhours Period ia Period-Dependent Costs (conornued) la.4.12 UtilityStaff Cost - 22,690 3.403 26,093 26,093 - - 423,400 738 73 33.962 5,087 39,867 37,609 2,258 1,575 14.445 5 580,871 la.4 Subtotal Period Ia Period-Dependent Costs 738 73 43,723 6,603 51,144 45,757 5.387 1,575 14,445 5 616,761 la.0 TOTAL PERIOD Io COST PERIOD lb - SAFSTOR Limited DECON Activities Period lb Direct Decommnssioning Activities Decontamination of Site Buildings lb.1.1.1 Reactor 2.929 1,465 4,394 4.394 68,438 52 26 78 78 1,562 lb.1.1.2 Augmrnted Radwasts lb.1.1.3 Mscellaneous Sructures . Contaminated 376 188 565 565 8,542 lb.1.1.4 Muot-Purpose FaCiitty 68 34 101 101 2.036 79 237 237 4,761 lb 1.1.5 Radwaste 158 1.1.6 Turbine 520 260 780 780 15,667 1I1 Totals 4,103 2,052 6,155 6,155 101,006 Subtotal Period I b Actvity Costs 4,103 2,052 6,155 6,155 101,006 lb.1 Period 1b Additional Costs lb.2.1 Spent Fuel Pool Isolation - - - 9.407 1,411 10,818 10,818 lb.2.2 Asbestos Insulation Disposal 773 1 65 558 265 1,662 1,662 10,333 134,329 10,002 lb.2 Subtotal Period l b Additional Costs 773 1 65 558 9.407 1,676 12,480 12.480 10.333 134,329 10,002 Period 1b Collateral Costs lb.3.1 Decor equlpment 713 - - - 107 820 820 Process lquid waste 229 - 74 392 448 293 1,436 1,436 1.561 93,644 304 lb.3.2 lb.3.3 Small tooi allowance - 70 11 81 81 lb.3.4 Spent Fuel Capital andTransfer 930 139 1,069 - 1,069 lb,3.5 Ccrportte Overheads . . ... 766 115 880 880 392 448 1,695 665 4,286 3,217 1,669 1.561 93,644 304 lb.3 Subtotal Period I b Collateral Costs 942 70 74 Period lb Period-Dependent Costs 1A4.1 Decon supplies 1,156 - 289 1,445 1,445 10.4.2 Insurance 121 12 133 133 lb.4.3 Property taxes - I 0 1 1 1b.4.4 Health physics supplies 473 118 592 592 1b.4.5 Heavy equipment rental 91 - - - 14 104 104 lb.4.6 Disposal of DAWgenerated 5 3 8151 21 110 110 1,741 15,968 5 S0.47 Plant energy budget 229 34 263 263 1b.4.8 NRC Fees 174 17 191 191 10'4.9 Emergency Planning Fees 292 29 321 - 321 1b.4.10 Spent Fuel POolO&M 184 28 211 211 1b.4.11 ISFSlOperaing Costs 21 3 24 - 24 lb.4.12 Security Staff Cost 1.485 223 1,707 1,707 38,829 lb.4.13 Uilty Staff Cost 5,595 839 6.434 6,434 -.104,400 Subtotal Period lb Period-Dependent Costs 1,156 564 5 3 81 8,101 1,628 11,538 10,981 557 2 1,741 15,.68 5 143,229 1b.4 6,020 34,458 32,833 1,626 13,635 243,942 111,318 143,229 lb.0 TOTAL PERIOD lb COST 6.201 1.407 80 460 1.087 19,203 TLG Serviese, Inc.

CooperNuolear Station Document N01-1590-002, Rev. I DecommissioningCost Analysis Appendix D, Page 26 of 35 Table D-3 Cooper Nuclear Station 2034 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

I Activity Decon Removal Packaging Transport off-Sita Processing LLRI Disposal Other Total Total Lic.NRC Ten. Spent Fuel Management site Restoration Processed Volume Class A Burial Class B Volumes Class C GTCC Burial I Processed Craft Utility and Contractor I Icnde Activity Description Cast Cost Costs Casts Costs Costa costs nsts Costs Costs Costa Cu. Feet Cu. Feet Cu. Feat Cu. Feet Cu. Feet Wt,. Lbs. Manhours Manhours I PERIOD Ic - Preparations for SAFSTOR Dormancy Period i Direct Decommissioning Actvities 1C.1.1 Prepare support equipment for storage 387 85 445 445 3,000 Ic.1.2 Install containment pressure equal. lines 31 - 5 36 36 700 Ic.1.3 Interim survey prior to dormancy 733 220 953 953 15,696 lc.1.4 Secure building accesses ic. 1.5 Prepare &submit interim report 58 9 67 67 - 0583 419 791 291 1,501 1,601 19,396 583 1C.1 Subtotal Period ic Activity Costs Period Ic Collateral Costs lc.3.1 Process iquid waste 235 76 403 460 301 1,475 1,475 1,603 96,195 313 -

1c.3.2 Small tool allowance 3 0 3 3 -

lc.3.3 Spent Fuel Capital and Transfer 940 141 1,081 - 1,081 lc.3.4 Corporate Over-eads . . . .. 774 116 890 890 lc.3 Subtotal Period lc Collateral Costs 235 3 76 403 460 1,714 558 3,449 2,368 1.081 1,603 96,195 313 Period 1cPeriod-Dependent Costs lc.4.1 Insurance 122 12 134 134 lc.4.2 Propertytaxs 1 0 1 1 1c.4.3 Health physics supplies 160 - 40 200 200 ic,4.4 Heavy equipment rental 92 - - 14 105 105

• -1 1 18 - 5 25 25 393 3,601 1 lc.4.5 Disposal of DAW generated 1c.4.6 Plant energy budget 231 35 266 266 1c.4.7 NRC Fees 176 18 194 194 ic.4.8 Emergency Planning Fees 295 30 325 - 325 1c.4.9 Spent Fuel Pool O&M 186 28 214 214 Ic.4,l0 ISFSI Operating Costs 21 3 24 - 24 lc.4.11 Security Staff Cost 1,501 225 1.726 1,726 - 39,260 1c.4.12 UtilityStaff Cost 5 057 849 6.505 6,505 105,560 lc.4 Subtotal Period ic Period-Dependent Costs 252 1 1 18 80,191 1,257 6,720 90157 563 393 3,601 1 144,820 lc.0 TOTALPERIOD ic COST 235 673 77 404 478 10.696 2,107 14,670 13,026 1.644 1.996 99,796 19,710 145,403 PERIOD I TOTALS 6,437 2.818 162 866 1,638 73.621 14,730 100,272 91,616 8.657 17,205 358,183 131,033 905,393 PERIOD 2a - SAFSTOR Dormancy with Wet Spent Fuel Storage Period 2a Direct Decommissionlng Acivitles 2a.i.1 Quarterly Inspection 2a.1.2 Semi-annual environmental survey a

2. 1.3 Prepare reports 2a.1.4 Bituminous roof replacement 63 9 72 72 2a.1.5 Maintenance supplies 503 126 629 629 20.1 Subtotal Period 2a ActivityCosts 566 135 701 701 Perod 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 21.155 3.173 24,329 - 24,329 2a.3.2 Corporate Ocerheads 4.139 621 4,759 4,759 2a.3 Subtotal Period 2a Collateral Costs 25.294 3,794 29,088 4.759 24,329 Period 2a Period-Dependent Costs 2a.4.1 Insurance 1,962 196 2.158 1,848 310 -- - -

16 20.4.2 Property taces 2 18 18 2a.4.3 Health physics supples 344 88 430 430 TLo Serices, Ine.

CooperNuclear Station Document N01-1590-002, Rev. I Appendix D, Page 27 of 35 Deom.missioning Cost Analysis Table D-3 Cooper Nuclear Station 2034 SAFSTOR Decommnissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Total LIc. Term. Management Restoration Volume Clas A Class 8 Clans C GTCC Processed Craft Contractor I IlActivity-I Ind*v ArH*

Ci6u.ý

• r*nf*n Decon cost, Removal t'

Packaging Costs Transport costs Processing costs Disposal costs Other Costs Total Continmenca Costs Costs Costs Costs Cu. Feet Cu. FPst Cu. Feet Cu. Feet Cu. Feat Wt. Lbs. Manhours ManhoursI Period 2a Period-Dependent Costs (continued) 2a.4.4 Disposal of DAWgenerated 13 7 198 - 52 270 270 - 4,267 39,139 13 2a.4.5 Plant energy budget - 742 111 853 427 427 2a.4.6 NRC Fees 807 81 887 887 -

2a.4.7 Emergency Planning Fees 3,374 337 3,712 - 3,712 2a.4.8 Spent Fuel Pool O&M - ,984 448 3,431 3,431 2a.4.9 ISFSI Operating Costs 340 51 391 - 391 2a.4.10 Security Staff Cost 17,728 2,659 20,387 7,788 12.599 444,561 18-816 2,822 21,639 4,426 17,213 -- - 329.769 2a.4.11 Utiity Staff Cost 344 13 7 198 46,768 6,845 54,176 16,092 382.63 4.267 39,139 13 774,330 2a.4 Subtotal Period 2a Periad-Dependent Costs 344 13 7 198 72,628 10,775 83.965 21,553 62,412 4.267 39,139 13 774,330 2a.0 TOTALPERIOD 2a COST PERIOD 2b - SAFSTOR Dormancy with Dry Spent Fuel Storage Period 2b Direct Decommitssioning Activities 2b.1-1 Quad"y Inspection 2b. 1.2 Semi-ennual environmental survey 2b.1.3 Prepare reports 2b. 1A Bituminous roof replacement 354 53 407 407 21.1.5 Maintenance supplies -2, 52 706 3,531 3,531 2b. 1 Subtotal Period 2b ActivityCosts 3,178 759 3,938 3,938 Period 2b Coulateral Costs 2b.3.1 Spent Fuel Capital and Transfer 13,214 1,982 15,197 16,197 2b.3 Subtotal Period 2b Collateral Costs 13214 1,982 15.197 15,197 Period 2b Period-Dependent Costs 2b.4.1 Insurance 9,796 980 10.775 10,373 402 2b.4.2 Property taxes 90 9 99 99 -

2b.4.3 Health physics supplies 1.620 - 405 2,025 2,025 66 36 1.037 - 271 1,411 1.411 22,311 204.651 68 2h.4A Disposal of DAWgenerated 2b.4.5 Plant energy budget - 2.083 312 2.390 2,395 2b.4.6 NRC Fees 4.528 453 4,981 4,981 -

2b.4.7 Emergency Planning Fees 18,944 1,894 20,838 - 20,838 2b.4.8 ISFSI Operating Costs 1,908 266 2,194 - 2.194 2b.4.9 Security Stuff Cost 67,312 8,597 65,909 43,719 22.190 1.265,451 2b.4.10 UtilityStaff Cost 41,970 6,295 48,265 24,845 23,420 749,897 2b.4 Subtotal Period 2b Period-Dependent Costs 1,620 66 36 1,037 136.630 19.503 156,892 89,847 69,045 22,311 204.651 68 2,015,349 20.0 TOTAL PERIOD 2b COST 1,620 66 36 1,037 153,023 22,244 178,026 93,785 84,241 22,311 204.651 68 2,015,349 PERIOD 2oc- SAFSTOR Dormancy wvithout Spent Fuel Storage Penod 2c Direct Decommissioning Activities 2c. 1.1 Quarterly Inspection a 2c. 1.2 Semi-annud envronnmental survey 20c1.3 Prepare reports 2c.1.4 Bituminous roof replacement 414 62 476 476 2c.1.5 Maintenance supplies 3,306 82e 4,132 4,132 2c.1 Subtotal Period 2c ActivityCosts 3,720 889 4,608 4,608 Period 2c Period-Dependent Costs 2C04.1 Insurance 11,037 1,104 12,140 12,140 2C.4.2 Property taxes - 105 11 116 110 2C.4.3 Health physics supplies 1.783 - - - 446 2,229 2,229 2c.4.4 Dispoe atof DAWgenerated - 75 42 1,186 310 1,613 1,613 25,518 234,065 78 TLG Services, Inc.

Cooper Nuclear Station Document N01-1590-002, Rev. I Decommissioning Cast Analysis Appendix D, Page 28 of35 Table D1-3 Cooper Nuclear Station 2034 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial Utlity 0and I Ac t io y Decon Removal Packaging Transport Processing Disposal Other Total Total Lit. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Conetrsrta Cost Cost Costs Costs Costs Costs Costs Continsency Costs Costs Costs Costs Cu. Feet Cu. FePt Cu. Fast Cu. Feet Cu. Fast WLt.Lbs. Manhours Manbosra I n ex -- l-Period 2c Peaiod-Dependunt Costs (contnued) 2c.4.5 Flant energy budget 2.437 366 2,803 2,803 2c.4.6 NRC Fees 4,799 480 5,279 5,279 2c.4.7 Security Staff Cost 44,492 6,674 51,165 51,165 822,771 2c.4.8 UtilityStff Cost - 25,284 3,793 29,076 29,076 - - 479,950 2c.d Subtotal Period 2c Period-Dependent Costs 1,783 75 42 1,186 88,153 13,182 104,422 104,422 25.51 - 234,065 78 1,302.721 2c.0 TOTALPERIOD 2c COST 1,783 75 42 1,186 91,873 14,071 109,030 109,030 25,518 234,065 78 1,302,721 PERIOD 2 TOTALS 3,748 153 85 2,422 317,524 47,090 371,021 224.368 146,654 52,095 477,855 160 4,092.400 PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy Period 3a Direot DecommissioningActivities 3s.1.1 Prepare prelimonary decovnossiorrng cost 130 20 150 150 1,300 3a. 12 Review piant dwgs &specs. 460 69 529 529 4.600 3a. 1.3 Perform detailed rod survey 3a. 1.4 End product description 100 15 115 115 1,000 3a.1.5 Detaiste by-product inventory 130 20 150 10 1,300 3,a.16 Defrae major work sequence 750 113 863 863 7.500 3a. 1.7 Perform SER and EA 310 47 357 357 3,100 3a.1,8 Perform Site-Specific Cost Stuly 500 75 575 575 5.000 3a.1. Preparepsoubit Lcense Teorination Plan 410 61 471 471 4.096 3a.1.10 Receive NRC approval of termination plan a Activity Specifications 3a.1.11.1 Re-actvate plant &temporary facilities 737 111 848 763 85 7,370 3a.1.11.2 Plant systema 417 63 479 431 468 4,167 3a1.11.3 Reactor internans 710 107 817 817 7,100 3a.1.11.4 Reactor vessel 65O 98 748 748 6,500 3a1.11.5 Sacritfcial shaid 50 6 58 58 500 3a.1.11.6 Moisture Separ atorstrheatars 100 15 115 115 - .000 3a.I.1.7 Reinforced concreta 160 24 184 92 692 1,600 3a.1,11.8 Main Turbine 209 31 240 240 2.088 3a01.11.9 Main Condensers 209 31 240 240 2,088 3a.1.11.10 Pressure suppression structure 200 30 230 230 2.000 3a.1.11.11 Drywel 160 24 184 184 1,600 3a.1.11.12 Plant structures &buildings 312 47 359 179 179 3,120 3a.1.11,.13 Waste management 460 69 529 529 4,600 3a.1.11.14 Facility & sits closeout 90 14 104 52 52 900 3a.1.11 Total 4,463 669 5,133 4,677 456 44,633 Planning & Site Preparations 30.1.12 Prepare disaotnrrng sequence 240 36 276 276 2,400 3a.1.13 Plant prep. & itmp. svcs 2,700 405 3,105 3.105 3a01.14 Design wtar clsaa-up system 140 21 161 161 1,400 3a01.15 Rigging/Coat, Cntt Eovlpsitoolingletc, 2,100 315 2,415 2,415 3a. 1.16 Procure csktliners & containers 123 16 141 141 1,230 3a.1 Subtotal Period 3a Activity Costs 12,556 1,883 14,439 13,983 456 - 77,559 Period 3a Period-Dependent Costs 3a04.1 ilasurone 420 42 462 462 3a.4.2 Property taxes 4 0 4 4 30.43 Healit phrysics suppies 324 81 405 405 3a.4.4 Heavy equipment rental 368 55 423 423 3a.4.5 Disposal of DAWgenerated 62 16 84 84 1,329 12,190 TLG Services, Inc.

0 Cooper NuclearStation Document N01.1590-002,Rev. 1 DecommissioningCoast Analysis Appendix D, Page29 of"35 Table Dl-3 Cooper Nuclear Station 2034 SAFSTOR Decommissioning Cost Estimate (thouesansds of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and I Decon Removal Packaging Transport Processing Disposal Other Total Total LIc. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor IActsity Cont Cost Cosnt costs Costs Costs Cat Cuntinnenev Costs Cnsts Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt. Lbs. Manhours Manhoursre n ex Q6ail.iiiu v n -

Period 3a Period-Dependent Costs (coninued) 3a.4.6 Plant energy budget 927 139 1,066 1,066 3a.4.7 NRC Fees 249 25 274 274

- 2,800 428 3,283 3,283 65,179 3a.4.8 Security Staff Cost 3a.4,9 UtilityStaff Cost - 14,190 2,128 16,318 16,318 - - 258,629 3a.4 Subtotal Period 30 Period-Dependent Costs 691 4 2 62 18,644 2,915 22.318 22,318 1,329 12,190 4 323,807 691 4 2 62 31,200 4,799 36,758 36,302 1,329 12,190 4 401,366 3a.0 TOTAL PERIOD 3a COST PERIOD 3b - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 473 71 544 490 54 4.733 400 60 460 460 4,000 3b.1.1.2 Reactor internals 135 20 155 39 1186 1,350 3b.1.1.3 Remaining buildings 100 15 115 115 1,000 3b,.1.1.4 CRD housings & Nis 3b.1.1.5 Incore instrumentation 100 15 115 115 1,000 3b.I.1.6 Removal primaty containment 200 30 230 230 2,000 363 54 417 417 3,630 3b.1.1.7 Reactor vessel 120 18 138 89 69 1,200 3b 1.1.8 Facliity closeout 120 18 138 139 1,200 3b.1.1.9 Sacrificial shield 3b.11.10 Reinforced concrete 100 15 115 58 58 1,000 208 31 239 239 2,080 3b. 11 .1 Maji Turbine 209 31 240 240 2,088 3b0.1.1.12 Muin Condensers 200 30 230 230 2,000 3b.1.113 Moisture seperators &reheaters X01.1.14 Radwaste building 273 41 314 283 31 2,730 3b01.115 Reactor building 273 41 314 283 31 2,730 301.1 Total 3.274 491 3.765 3,405 360 32,741 3b.1 Subtotal Period 3b Activity Costs 3,274 491 3,765 3,4058 360 32,741 Period 3b Additional Costs 31,2.1 Site Characterzation - - - - 5.395 1,819 7,014 7,014 3b.2 Subtotal Period 3b Additional Costs *- - - 5,395 1,618 7,014 7,014 Penod 3b Coliateral Costs 3b.1 Decon equipment 713 - 107 820 820 303.2 DOC staff relocaion0 expenses 912 137 1,049 1,049 3b.3.3 Pipe cutting equipment 1,000 - 150 1,150 1,150 30.3 Subtotal Period 3b Collateral Costs 713 1,000 912 394 3,019 3,019 Perod 3b Period-Dependent Costs 3b.4.1 Decon supplies 22 5 27 27 3b.4.2 Insurance 246 25 270 270 3b0.4.3 Property taues 2 0 2 2 3b.4.4 Hoalth physics supplies 179 45 224 224 3b.4..5 Heavy equipment rental 184 28 212 212 3b.4.6 Disposal of DAW generated 35 - 9 48 48 754 6,913 2 2

3b.4.7 Plant energy budget 465 70 534 534 3b.4.8 NRC Fees 125 12 137 137 3b.4.9 Security Staff Cost 1,431 215 1,646 1,848 32,678 3b.4.10 DOC Staff Cost 4,378 657 5,035 5,035 58,560 3b.4.11 UtilityStaff Cost - 7,114 1,067 8.181 8,181 - 129,669 30.4 Subtotal Period 3b Period-DependentCosts 22 363 35 13,761 2,133 16,317 16,317 754 8,913 2 220.907 2

TLG Services, Inc.

Cooper Nuclear Statione DocumentNOI-1590-002, Rev. I Decoo~rmissioreirg CoastAmalyais Appendix:D, Page30 of 35 Table D-3 Cooper Nuclear Station 2034 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial/ Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic.Tenm. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activit Description Cost Cost Costs Costs Costs Costs Costs Continuenev Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet WI. Lbs. Manhours Manhours 3b.0 TOTALPERIOD 3b COST 735 1,363 2 1 35 23.342 4,636 30,115 29,755 360 754 6,913 2 253,646 PERIOD 3 TOTALS 735 2,055 6 3 97 54,542 9,435 66,872 66.056 616 2,083 19.104 6 655,014 PERIOD 4a - Large Component Removal Period 4a D~rectDecommnissioningActivities Nuclear Steam Supply System Removan 4a.1.1.1 Recirculation System Piping &Valves 16 70 14 13 127 151 86 477 477 499 499 1,188 115,643 2,487 4a.1.1.2 Recirculation Pumps & Motors 6 28 11 26 - 321 95 488 498 132,880 1,125 4a.1.1.3 CRDMs &Nis Remonal 24 139 377 68 317 174 1 099 1,099 6,935 - 126,494 3,972 4a. 1.1.4 Reactor Vessel Internals 86 1,959 3,871 912 5,169 155 5,314 17,462 17,462 1,878 1,252 470 359,044 18,900 888 4a.1.1.5 Vessel & Internals GTCC Disposal - - - 7,470 - 1,120 8,590 8,590 508 89,497 4a.1.1.6 Reactor Vessel 5.054 906 351 3,006 155 5.631 15,103 15,103 14,106 1,447.089 18,900 888 4a.1.1 Totals 132 7,250 5,179 1,370 127 16,431 309 12,420 43,219 43,219 499 24,605 1,252 470 508 2,270.647 45,384 1,776 Removal of MajorEquipment 4a. 1.2 Main Turbine/Generator 167 945 372 6,376 1,138 8,898 8,898 61,604 2,772,179 4,438 709 588 259 4,439 940 6,932 6,932 42,889 1,930,000 19,519 4a.1.3 Main Condensers Cascading Costs from Clean Building Demolition 4a. 1.4.1 Reactor 260 39 299 299 - 2,486 4a.1.4.2 Augmented Radwaste 25 4 28 28 235 43 7 50 50 359 4a.1.4.3 Radwaste 40.1.4.4 Turbine 285 43 328 328 4,419

40. 1.4 Totals 613 92 705 705 7,498 Disposal of Plant Systems 166 857 857 2,055 172,205 5,688 4a.1.5.1 Augmented Radwaste El 877 AreslA 203 28 23 432 44 228 228 469 41,606 1.842 4a.1.5.2 Augmented Radwaste EA903 ArealA 66 6 7 104 4a.1.5.3 Augmented Radwuast El 918 ArealA 52 10 9 139 50 260 260 765 55,345 1,432 4a. 1.5.4 Augmented Radtasts El 929 ArealA 21 4 5 - 73 25 127 127 * - 324 29,038 579 4a.1.5.5 Augmented Radwaste El 929 Areal B 3 0 0 4 - 1 a 8 "38 -32 1,529 75 4a.1.5.6 DRYWELLArealA 457 85 84 - 1,289 458 2,373 2.373 5,726 513,627 12,634 4a.1.5.7 DRYVWELL ArealB 112 1 5 75 2 41 235 235 806 10 33,576 3,384 324 16 86 1,477 317 2,220 2,220 " 15.808 641,963 9,170 4a.1.0.8 Turbine El 932 AnealB 4a.1.5.9 Turbine El 932 Area2C 8 1 9

• 9 237 4a.1.5.10 Turbine El 932 Area3C 67 - - - 10 78 - 78 - 2,083 4a.1.5.11 YardAuealB 518 50 264 4,517 852 6,201 6,201 76 48,365 1,964,114 14,340 4a.1.5 Totals 1,831 202 487 6,073 2.040 1.964 12,597 12,510 "87 65,016 9,348 3,453.003 51.444 4a. 1.6 Scaffolding in support of decommissioning 2,049 24 11 168 23 047 2,821 2,821 1,921 101 81,992 27.411 4a. I Subtotal Period 4a Acivity Costs 132 12,616 6,838 2,499 17,183 18,493 309 17,102 75,172 75,085 87 171.628 34,065 1,252 470 5068 10.507.820 155,694 1.776 Period 4a Collateral Costs 4a.3.1 Process liquie masne 36 - 14 76 87 54 270 270 "10 304 - 18,226 59 40a3.2 Small tool allowance 90 14 104 94 10 -

4a.3 Subtotal Period 4ACotlateral Costs 38 90 14 76 87 67 374 363 - 0 304 - 18,226 59 Period 4a Period-Dependent Costs 4a.4.1 Decon sewpiLes 47 12 59 59 4a.4.2 Insurance 529 53 579 579 4a.4.3 Property taxes 4 0 5 4 0 4a.4.4 Health physics supplies 927 232 1,159 1,159 4a.4.5 Heavy equipnent rental 1,899 285 2,183 2,183 TLG Services, Inc.

Cooper Nuclear Station. Document NO0-1590-002, Rev. 1 Decuonami-laonitig Coot Analysis AppendiarD,Page 31 of 35 Table D-3 Cooper Nuclear Station 2034 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial I Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic.Tens. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activit Descrilption Cost Cost Costs Costs Costs Costs Costs Contlingenc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu.Feet Cu. Feet Cu. Feel W.LLbs. Manhours Manhours Period 40 Period-Dependent Costs (continued) 25 14 401 - 105 546 548 8,638 79,217 28 4a.4.6 Disposal of DAWgemerated 4a.4.7 Plant energy budget 946 142 1.087 1,087 4a.4.8 NRC Fees 707 71 778 778 4a.4.9 Liquid Radwaste Processing EquipnrentlServices 403 60 463 463 4a.4.10 Security Staff Cost 3,066 460 3,526 3,528 70,000 11,154 1,073 12,828 12,828 154,560 4a.4.11 DOC Staff Cost UtilityStaff Cost 15,348 2,302 17,650 17,650 280,000 4a.4.12 4a.4 Subtotal Peniod4a Period-Dependent Costs 47 2.825 25 14 401 32.154 5,394 40.882 40.861 0 8,636 79,217 28 504,560 6,878 2,590 17,183 18,982 32.463 22,564 116,408 116,310 98 171,628 42.995 1,252 470 508 10,605,260 155,780 506.336 4a.0 TOTAL PERIOD 4a COST 217 15.531 PERIOD4b - Site Decontamination Period 4b Direct Decommissioning Activitias 4b.1.1 Reerove spent Wuel racks 262 33 79 88 498 2,308 2,308 5,986 537,141 1,004 Disposal of Plant System 4b.1.2.1 Contro El 882 ArealB 280 39 674 178 1,178 1,178 7,213 292.908 7.797 4b.1.2.2 Controd El 903 A*a1C 170 25 195 - 5,155 4b.1.2.3 Control E 918 Area1C 66 10 76 78 2,100 4b.1.2.4 Control El 932 AreslC 22 3 26 20 702 4b. .2.5 Intake 101 15 116 118 - 3,136 4b.1.2.6 Multi-Purpose Facility 198 3 14 239 - 88 541 541 2,558 103,862 5,430 398 75 62 949 353 1,836 1.836 - 5,097 377,917 10,930 4b.1.2.7 Radwaste El 877 ArealA 40.11.8 Radwaste El 877 Area2A 43 9 7 113 41 213 213 613 44,992 1,189 4b.1.2.9 Redwaste El 877 Area3A 71 16 13 201 72 372 372 1,156 79,963 1,969 110 9 10 153 68 351 351 684 61,153 3,015 4b.1.2.10 Radwasta El 903 AreslA 4b,1.2.11 Radwaste El 903 Ara2A 188 36 29 439 165 858 856 1.955 175,093 5,282 37 6 7 104 37 190 190 463 41,366 1,029 4b.1.2.12 Radwaste El 903 Area3A 4b.1.2.13 Radwaste El 918 ArealA 18 2 2 30 12 64 64 135 12,033 477 4b.1.2.14 Radwaste El 918 Area2A 16 3 3 39 15 75 75 201 15,667 448 4b.1.2.15 Radwaste El 918 Arne3A 185 23 22 338 136 705 705 1,690 134,827 5,045 26 3 4 60 22 115 115 268 23,735 680 4b.1.2.16 Radwasta El 934 ArealA 4b.1.2.17 Radwaste El 934 Area2A 98 11 12 177 72 370 370 808 70,605 2.663 4b.1.2.18 Radwaste El 949 ArealA 12 2 24 9 47 47 105 9,381 305 1

4b.1.2.19 Reactor al 1001 ArealA 50 7 8 121 45 230 230 537 48,175 27,979 1,261 1,681 4b.1.2.20 Reactor El 1001 Areal* 62 1 4 64 26 157 157 689 4b.1.2.21 Reactor El 859 ArealA 71 is 16 246 83 430 430 - 1,091 97,874 2,024 4b.1.2.22 Reactor E 859 ArealB 440 11 58 994 - 289 1,771 1,771 10,641 432,136 12,411 4b.1.2.23 Reactor aJ 859 Area2A 72 25 26 - 401 125 648 648 1,780 159,714 2,094 4b.1.2.24 Reactor 8l 859 Ares2B 69 1 0 131 - 38 247 247 1,406 57,093 1.954 4b.1.2.25 Reactor 8l859 Area3A 47 9 9 137 48 251 251 - 608 54,543 1,321 4b. 1.2.26 Reactor El 859Area3B 33 0 2 42 15 93 93 453 18,381 951 4b.1,2.27 Reactor El g59 Are4A 50 9 8 117 44 227 227 520 46,666 1,374 40.,1.2,20 Reactor E[]588Area4B 17 0 2 31 9 59 59 331 13.424 476 4b0.1.2.29 Reactor El 5' AreasA 1,163 104,381 1,798 63 16 17 282 85 443 443 4b.1.2.30 Reactor 81855A8es5 442 17,962 1,087 37 0 2 41 - 16 98 98 4 Reactor s.1.2.31El 9OAreslA - 2,892 259.190 10,497 401 56 42 651 275 1,424 1,424 40.1.2.32 Reaor [903 AeslB 239,197 12,496 451 6 32 550 - 201 1,240 1.240 5,890 4b.1.2.33 Reactor El903 ArealA 4 2,372 120 0 0 0 3 14 14 26 401.12.34 Reactor El 903 Area2B 69 82,815 1,915 2 11 190 48 320 320 2,039 4b1.2.35 Reactor El 903 Area3A - 741 66,516 929 32 10 II - 167 52 272 272 4b.1.2.35 Reactor El Qb.1.236 Reactor El 903 Area3 903 .*ea3B 21 3 52 - 14 90 90 553 , 22,464 618 4b. 1.2.37 Reactor El 903 Ares4A 27 8 9 136 43 223 223 606 54,373 776 4b.1.2.38 Reactor El 903 Area4B 21 3 52 14 90 s0 559 22,692 597 4b.1 .2.39 Reactor El 931 AreaIA 25 3 52 20 104 104 - 232 20,858 670 TLG Services, Inc.

Cooper' Nuclerar Stationa Document N01-1590-002, Rec. I Dneo-aaairrrirag Coat Anaalysis Appendix D, Page 32 of 35 Table D-3 Cooper Nuclear Station 2034 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars) off-Site LLRW NRC Spent Fuel Sits Processed BurialVolumes Burial I Utilityand ActUvty Decon Removal Packaging Transport Processing Disposal Other Total Total Lc. Tenm. Management Restoration Volume ClasnA Class B Class C GTCC Processed Craft Contractor Index Activit Description Cast Coast Costs Costs Costs Costs. Costs Contn enc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet WL9Lbs. Manhours Manhours Disposal of Plant Systems (continued) 4b.1.2.40 Reactor El 931 ArealB 300 8 40 692 186 1,227 1,227 7.412 301,017 8,410 4b.1.2.41 Reactor El 931 Area2A 20 2 2 - 35 14 74 74 - -154 13,824 544 41.1.2.42 Reactor El 931 Area2B 2 0 0 1 0 1 3 3 9 0 371 53 4b.1.2.43 Reactor El 931 Area3A 77 23 22 - 336 109 567 567 - 1,651 134,007 2,165 4b.1,2.44 Reactor Ea 931 Area3B 2 0 0 1 3 3 8 340 49 4b.1 .2.45 Reactor El 931 Area4C 24 4 28 28 767 4b.1.2.46 Reactor El 931 Anea5C 7 1 a - - 213 56 9 10 149 54 278 278 662 59,432 1,472 4b.1.2.47 Reactor El 9589 ealA 3,009 .

4b.1.2.48 Reactor El 958 Aeal B 167 3 19 281 87 554 554 122,212 4,693 31 10 10 153 49 253 253 681 61,083 880 4b. 1.2.49 Reactor El 958 Area2A 4b9.12.50 Reactor El 958 Area2B 10 1 1 12 7 a 37 37 125 33 8,024 263 4b).1.2.51 Reactor El 958 Area3A 33 4 3 48 21 109 109 S- 214 19,185 898 4b.1.2.52 Reactor El 958 Area3B 14 1 1 10 6 7 39 39 109 29 7,011 410 4b.1.2.53 Reactor Ea e76 AealA 11 1 1 - 16 7 39 36 S- 72 6.482 298 4b.1.2.54 Reactor El 976 AeaIB 147 5 25 422 - 104 703 703 4.521 183,615 3,931 4b. 1 2.55 Reactor E9 976 Area2A 7 1 1 13 5 26 26 - -57 5,136 172 4b.1.2.56 Reactor El 976 Area2B 37 1 3 51 18 114 114 23,813 1,033 4b.21.57 Turbine El 882 krMIA 37 3 3 - 50 23 116 116 .- 222 19,878 1,004 4b.1.2.58 Turbine El 882 ArealB 386 16 87 1,490 335 2.313 2,313 15,948 647,659 11.113 4b.12.59 Turbine El 882 Area2A 21 2 2 29 13 67 67 . - 129 11,556 584 209 4 22 374 112 721 721 4,006 162,678 5,78t 4b.1.2.60 Turbine El 882 Area2B 4b.1.2.61 Turbine El 882 Area3A 16 2 1 - 23 10 52 52 - - 101 9,017 451 4b.1.2.62 Turbine E9882 Aee3B 607 27 145 2,478 548 3,605 3,805 26,533 1,077,531 17.302

- 9 1 1 - 15 6 32 32 - .68 6,127 232 4b.1.2.63 Turbine El 903 ArealA 4b.1.2.64 Turbine E9903 ArealB 974 46 241 4,133 904 6.299 6,299 44,251 1,797.054 27.674 4b91.2.65 Trmbine E 903 Area2A 5 1 1 9 4 20 20 42 3,729 142

-128 56 337 337 1,375 55,851 4,040 4b.1.2966 Turbim El903 Area2B 1144 1 7 4b.1.2.67 Turbine El 903 Area3B - 3 0 2 35 6 47 47 376 15,251 97 4b.1.2.68 Turbine El 903 Area3C - 1012 16 124 - 124 - 3,412 4b.1.2.69 Turbine E9903 Area4B 12 O 28 7 49 49 299 12,139 367 4b.1.2.70 Yard ArealC 197 30 227 - 227 - 5,770 4b.1.2 Totals 7.771 556 1,148 13,202 5.814 5,535 34,027 33,227 &0 141,342 27,486 8,056,388 218,627 4b.1.3 Scaffolding In support decomeissoning 3.073 36 17 252 34 821 4,232 4,232 2,431 151 122,968 41,117 Decontaminaton of Site Buildings 4b.1.4.1 Reactor 2.880 1,820 202 422 4,911 2,376 3,310 15.922 15,922 52,579 39,536 6,069,283 115,053 4b.1.4.2 Augmented Radwaste 52 19 4 6 23 60 51 215 215 242 1,099 119.386 1.978 4b.1.4.3 Miscellaneous Stuctures -Contaminated 368 167 15 42 759 62 363 1,777 1,777 8,t29 452 372.774 12,956 4b.1.A.4 MuS-Pulpose Facility 68 55 6 12 115 89 90 437 437 1,234 1,567 205.066 3,237 4b.1.4.5 Radwaste 159 50 9 14 38 161 141 572 572 404 2,953 310,769 5.863 4b.1.4.6 Turbine 526 142 35 51 64 633 477 1.928 1 ,98 688 11,664 1,193,496 18,679 4b.1.4 Totals 4.055 2,253 27t 547 5,910 3.382 4,432 20,850 20,850 63,275 57,271 8,270,774 157,766 4b91 Subtotal Period 4b Activity Costs 4,318 13,131 942 1,800 19,364 10,578 11,285 61,417 60.618 8o0o 207,048 90,895 16,987,290 418,513 Period 4b AdditionalCosts 4b.2.1 ISFSI Decontamination 1.012 6 24 so 1,250 460 2,811 - 2,811 1,175 165.113 26,509 2,560 4b.2.2 Final Site Survey . . .. 1,205 362 1,567 1,597 12,480 4b.2 Subtotal Period 4b Additional Costs 1,012 6 24 s0 2.455 921 4,378 1,567 2,811 1,175 165.113 26.509 15.040 Period 4b Collateral Costs 4b.3.1 Process liquid waste 79 - 30 161 183 113 566 566 639 38,338 125 4b.3.2 Smua tool allowance 235 35 270 270 4b.3.3 Decommissioning Equipment Disposition 88 50 621 84 130 973 973 6,000 373 303,507 88 4b.3 Subtotal Period 4b Coltaterol Costs 79 235 118 210 621 267 278 1,810 1,810 6,000 1.012 341,844 213 TLG Service&, Inc.

Coope, Nucka-Statio.n DoeumentN01-1590-002, Rev. I Appendix D, Page 33 of 35 DecomoaniaaioningCost Analysis Table D-3 Cooper Nuclear Station 2034 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars) 2034 SAFSTOR Cooper (thousands Nuclear Decommissioning Table D-3Station of 2008 Cost Estimate Spent Fuel dollars) Sits Processed Burial Volumes Burial I Uility and I Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lin.Term. Management Restoration Volume Class A Class 8 Class C GTCC Processed Craft Contractor I Index Activity Description Cost Cost Costs Costa Off*'-Site Costs LIL Costa Costs Contlnoency Costs NRC.

Costs Costa Costs Cu. Feet Cua Feet Cu. Feet Cu. Feet Cu. Feet WI. Lbs. Manhouro Manhours I Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 1.252 - 313 1.565 1,565 4b.4.2 Insurance 1,199 120 1,319 1,319 4b.4.3 Property taxes - 10 1 1-t 11 4b.4.4 Healtl physics supples 2.409 - 602 3.011 3.011 4b.4.5 Heavy equipment rental 4,294 - - 6 644 4,938 4.938 876 - 229 1,192 1,192 18,853 172.932 58 4b.4.8 Disposal of DAWgenerated 55 31 4b.4.7 Plantenergy budget 1,751 255 1.950 1,958 4b.4.8 NRC Fees 1.610 161 1.771 1,771 45.4.9 Liquid Radwaste Processing Equipment/Services 918 138 1,055 1.055 6,984 1.048 8,032 8,032 159,464 4b.4.10 Security Staff Cost 4b.4.11 DOC Staff Cost 24,760 3,714 28,474 28.474 341,891 4b.4.12 Utiity Staff Cost 33,266 4,990 38,256 38,256 602,137 1,252 6,703 55 31 876 70.448 12,215 91,580 91,580 18,853 172,932 58 1,103,493 4b.4 Subtotal Period 4b Period-Dependent Costs 24,600 159,185 155,574 2,811 800 213.048 111,935 17,667,180 445,292 1,119,533 4b.0 TOTAL PERIOD 4b COST 5,649 21,081 1,121 2,065 19,985 11.782 72,902 PERIOD 4o - License Termination Period 4e Direct Decommissioning Activities 48.1.1 ORISE confrmatory survey - - 147 44 191 191 4e.1.2 Terminate license a 4e.1 Subtotal Period 4e Actvity Costs 147 44 191 191 Period 4e Additonal Costs 4e.2.1 Final Site Survey 5,998 1,799 7.797 7,797 148.435 6.240 5.998 1,799 7.797 7,797 148,435 6,240 4e.2 Subtotal Period 4e Addritonal Costs Period 4e Collateral Costs 4e.3.1 DOC staff relocaton expenses 912 137 1,049 1,049 4e.3 Subtotal Period 4e Collateral Coals 912 137 1,049 1.049 Period 4e Period-Dependent Costs 4 0.4.1 Insurance -.-

4e.4.2 Properytayes-h 3 0 3 3 4e.4.3 Health physics supplies 735 - - - 184 919 919 3 1 42 11 57 57 904 8,294 3 4e.4.4 Dlsposal of DAW generated 4e.4.5 Plant energy budget 139 21 160 160 48.4.6 NRC Fees 530 53 583 583 4e.4.7 Security Staff Cost 1.009 151 1.160 1,160 18,789 44.4.0 DOC StaffCost 4,442 666 5,108 5,108 57,149

- . - - 74,371 4e.4.9 Ul1ityStaff Cost - - - 4,678 702 5,379 5,379 735 3 1 42 10,800 1,788 13,369 13,369 904 8,294 3 150,309 48.4 Subtotal Period 4e Period-Dependent Costs 22,407 - 904 8,294 148,438 156,549 4e.0 TOTALPERIOD 4e COST 735 3 1 42 17,857 3,768 22,407 PERIOD 4 TOTALS 5,8a8 37,348 8,001 4,658 37.168 30,806 123,223 50,932 297,999 294,291 2,811 897 384,676 155,834 1,252 470 508 29,280,740 749,510 1,781,417 PERIOD 8b - Site Restoration Period 5b Direct Decommissioning Acbvites Demoliton of Remainig Site Buildings 5b.1.1.1 Reactor 1.491 - - 224 1,715 1,715 - - - - - 14.601 5b.1.1.2 Augmented Radwaste 222 33 255 255 2,119 5b.11.3 Control 214 32 246 248 1.655 5b81 1.4 Intake Structore 523 78 602 602 5,621 TLG Services, Inc.

Cooper Nuclear Station Document N01.1590.002, Rev. I DecommissioniogCost Analysis Appendix D, Page 34 of 35 Table D-3 Cooper Nuclear Station 2034 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars) m Off-Sit. LLRW NRC Spent Fuel Sits Processed Burial Volumes Burial I Ulity and IActiy Decon Removal Packaging Transport Processing Disposal Other Total Total UC. Term. Management Restoration Volume Class A Class 8 Class C GTCC Processed Craft Contractor I H [*BX A*UV*V* CrlU[* Cost Cost Costs Costs Costs Costs Costs ontinenc Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt. Lbs. Manhours Manhour I n ex - 1-Demo5l5oeof Remaining Site Buildings (continued) 5b.1.1.5 LLRWStorage Pad 145 22 167 167 1.227 5b.1.1.6 Miscellaneous Siructures - Clean 1,196 179 1,375 1,375 11,837 5b.1.1.7 Miscellaneous Structures - Contarminated 27 4 30 30 572 S1t 10.8 MulS-Purpose Facility 123 18 141 141 1,982 3 20 20 283 5b 1.1-9 OVWCGas Generator 158 1,920 5b.1.1.10 Office - 156 23 179 179 Sb.1.I.11 Radwasle 391 59 449 449 3,229 17 3 20 20 166 5b.1.1.12 Seal Well St.1.1,13 Sewage TreatmentArea 4 1 5 5 53 5b.1.1.14 Transornier Yard 20 3 24 24 172 St..1.,15 Turbine 2,596 389 2.985 2,985 40,503 5b.1.t.16 Turbine Pedestal 277 42 310 318 2.100 5b.1.t Totals 7,418 1,113 8,531 8,531 88.040 Site Closeout Activities 5b.1- Remove Rubble 424 64 488 488 3,286 5b, 1.3 Grade &landscape site 578 - 807 665 665 1,578 5b. 1.4 Final report to NRC 156 23 179 179 S- 1,560 5b. I Subtotal Period 5b Activity Costs 8,421 156 1,286 9.063 179 9.684 92.904 1,560 Peniod5b Additional Costs 5b.2.1 ISFSI Demolition 672 44 107 824 824 5,8980 16 5b2.2 Cocrete Crushing 499 8 76 582 582 3.045 W0.2.3 Cofferdam 458 - 69 527 527 5.130 5b.2 Subtotal Period SbAdditional Costs 1,629 52 252 1.933 824 1,100 14.073 160 Period 5b Collateral Costs 5b.3.1 Small tool allowance 560. a 64 64 8 64 64 5b.3 Subtotal Period 5b Cotateral Costs 560-Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property tanes 7 1 8 5b.4.3 Heavy equipment rental 4,233 635 4.869 4,869 5b.4.4 Plant energy budget

• 167 25 192 192 50,4.5 Security Staff Cost 2,419 363 2,782 2,782 45,051 5b.4.6 DOC Staff Cost 10.212 1,532 11,744 11,744 127.64" 5b.4.7 U lity Staff Cost 4,507 676 5.183 73,209 104 Subtotal Period So Period-Dependent Costs 4,233 17,312 3.232 24.777 24,7877 245.906 5b.0 TOTAL PERIOD SbCOST 14,339 17,520 4,779 36,638 179 824 35,634 106.977 247,626 824 35.634 PERIOD 5 TOTALS - 14,339 17,520 4,779 36,638 179 106.977 247,626 TOTALCOST TO DECOMMISSION 13,038 60,307 8,323 5.611 37,168 34,963 580.430 126,964 872.803 676.510 158,945 37,348 384.676 227,217 1.252 470 508 29,135,880 987.685 7,681.850 TLG Services, Inc.

CooperNuarka, Statio~n DocumentN01-1590-002, Rev. I Decovaajarnsionirg Cost Anaalysis Appendix D, Page 35 of35 Table D-3 Cooper Nuclear Station 2034 SAFSTOR Decommissioning Cost Estimate (thousands of 2008 dollars)

Off-Site I.RW NRC Spent Fuel Site Processed Burial Volumes BurialI Utility and Activity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Continefc Casts Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt. Lbs. Manhours Manhours TOTALCOST TO DECOMMISSION WITH17.02% CONTINGENCY: $872,803 thousands of 2008 dollars TOTALNRC LICENSE TERMINATIONCOST IS 77.51% OR: $676,510 thousands of 2008 dollars SPENT FUEL MANAGEMENTCOST IS 18.21% OR: $158,945 thousands of 2008 dollars NON-NUCLEARDEMOLITIONCOST IS 4.28% OR: $37.348 thousands of 2008 dtolars TOTALLOW-LEVELRADIOACTIVEWASTE VOLUME BURIED (EXCLUDING GTCC): 228.939 cubic feet TOTALGREATER THAN CLASS C RADWASTE VOLUME GENERATED: 008 cubic feet TOTALSCRAP METALREMOVED: 30,276 tons TOTALCRAFT LABOR REQUIREMENTS: 987,686 man-hours End Notes:

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

a - indicates that this activity performed by decommissioning staff.

0 - indicates that this value is less than 0.5 but is nos-zero.

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

Cooper Nuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Appendix E, Page 1 of 8 APPENDIX E WORK DIFFICULTY ADJUSTMENT FACTORS TLG Services, Inc.

CooperNuclear Station Document N01-1590.002, Rev. 1 DecommissioningCost Analysis Appendix E, Page 2 of 8 APPENDIX E WORK DIFFICULTY ADJUSTMENT FACTORS TLG has historically applied work difficulty adjustment factors in determining Unit Cost Factors to account for working in a radiological controlled environment. In performing an area-by-area decommissioning cost/schedule estimate the work difficulty factors are to be applied on an "area" basis, based on the nominal area conditions. Where practical, areas are established based on similar working conditions.

The intent of the use of these factors is to provide the estimator an appropriate means to achieve an additional element of consistency within the estimate.

Access Factor:

ControllingVariables:

• Height of the component above the working floor

• Difficulty in working around the component (restricted access)

Source of Variable Information:

• Estimators observation or judgment

• Plant drawings Range of Access FactorAdjustments:

0% Components are accessible and located near a working level floor or platform 10% Scaffolding (component less than <12 feet above floor) is required to access the majority of the components or the area around the components is congested.

20% Scaffolding (component less than <12 feet above floor) is required to access the majority of the components and the area around the components is congested.

30% Scaffolding (component between 12 - 20 feet above floor) is required to access the majority of the components or the areas around the components are extremely congested.

TLG Services, Inc.

CooperNuclearStation Document NO1-1590-002, Rev. 1 Decommissioning Cost Analysis Appendix E, Page 3 of 8 40% Scaffolding (component between 20 - 45 feet above floor) is required to access the majority of the components).

50% Scaffolding (component greater than 45 feet above floor) is required to access the majority of the components).

Respiratory Protection Factor:

Controlling Variables:

" Component surface contamination levels (internal or external)

• Type of work (potential to create an airborne problem)

• General area surface contamination levels

• Site-specific requirements for maintaining respirator qualifications (initial qualification, requalification, etc.)

• Personal air sampler requirements Sources of Variable Information:

• Radiation Work Permit Requirements

• Area Survey Maps

• Site Radiation Protection Program Manual Range of Respiratory Pr-otectionFactorAdjustments:

0% Respiratory protection is not required (clean system or loose surface contamination has been removed).

25% Respiratory protection is only required during limited segments of the work (i.e. physical cutting).

50% Respiratory protection is continuously required while working on the component.

Radiation/ALARA Factor:

Controlling Variables:

• Component contact dose rate

• General area dose rate TLG Services, Inc.

CooperNuclear Station Document NO1-1590-002, Rev. 1 DecommissioningCost Analysis Appendix E, Page 4 of 8 o Site-specific requirements for maintaining radiation worker qualification (initial qualification, requalification, etc.)

• Dosimetry requirements I

Sources of VariableInformation:

• Area Survey Maps

• Site Radiation Protection Program Manual

• Radiation Work Permit Requirements Range of Radiation/ALARA FactorAdjustments:

(Note surface contamination levels are principally accounted for in protective clothing requirements and respiratory protection requirements) 0% Component is clean and is not located in a radiological controlled area.

10% Component is located in a radiological controlled area (General Area Radiation field < 2.5 mrem/hr).

20% Component is located in a radiological controlled area (General Area Radiation field between 2. 5 to 15 mrem/hr).

40% Component is located in a radiological controlled area (General Area Radiation field between 16 and 99 mrem/hr).

100% Component is located in a radiological controlled area (General Area Radiation field > 100 mrem/hr).

Protective Clothing Factor:

Controlling Variables:

• Component surface contamination levels (internal or external)

" General area surface contamination levels

• Type of activity (wet/dry work, potential to create a surface contamination problem)

• Site specific work schedule arrangements TLG Services, Inc.

CooperNuclear Station Document N01-1590-002,Rev. 1 DecommissioningCost Analysis Appendix E, Page 5 of 8 Sources of VariableInformation:

" Radiation Work Permit Requirements

" Area Survey Maps

• Site Radiation Protection Program Manual Range of Protective Clothing Factor Adjustments (alternate site-specific schedules may dictate alternateadjustments):

0% Component is clean and is not located in a radiological controlled area.

30% Component is clean or contaminated and is located in a surface contamination controlled area. Work is to be completed in accordance with the requirements of an RWP, which specifies a single or double set of "PC's", or "PC's" with plastics.

50% Components is located in a surface contamination controlled area. Work is to be completed in accordance with the requirements of an RWP, which specifies "plastics" in addition to double PC's for protective clothing.

100% Component is located in a surface contamination controlled area. Work is to be completed in accordance with the requirements of an RWP, which specifies double "PC's" and double "plastics" (extremely wet or humid working environment).

Work Break Factor:

Controlling Variables:

• Site specific work schedule arrangements Sources of VariableInformation:

• Typical site work schedule Range of Work Break FactorAdjustments:

8.33% Workday schedule outlined in AIF/NESP-036 (alternate site-specific schedules may dictate alternate adjustments).

TLG Services, Inc.

Cooper NuclearStation DocumentN01-1590-002, Rev. 1 DecommissioningCost Analysis Appendix E, Page 6 of 8 TABLE E-1 WORK DIFFICULTY ADJUSTMENT FACTORS Work Difficulty Factors Area Identification Area Description Access Respirator ALARA Clothing Reactor El 1001 Area 1 Refuel floor 14% 25% 14% 30%

Reactor El 859 Area 1 Torus 14% 25% 14% 30%

HPCI Room, B&D RHR Reactor El 859 Area 2 Room 14% 25% 14% 30%

Reactor El 859 Area 3 B Core Spray Pump Room 14% 25% 14% 30%

Reactor El 859 Area 4 RCIC Pump Room 14% 25% 14% 30%

Reactor El 859 Area 5 A&C RHR Pump Room 14% 25% 14% 30%

CRD Hyd Control Units, Reactor El 903 Area 1 TIP Room 14% 25% 14% 30%

Reactor El 903 Area 2 Steam Tunnel 14% 25% 14% 30%

Reactor El 903 Area 3 A RHR Room 22% 25% 40% 30%

Reactor El 903 Area 4 B RHR Room 22% 25% 40% 30%

RBCCW pumps & heat Reactor El 931 Area 1 exchangers 14% 25% 14% 30%

Reactor El 931 Area 2 RWCU Recirc pump room 10% 25% 100% 30%

Reactor El 931 Area 3 RWCU heat exchangers 10% 25% 100% 30%

Reactor El 931 Area 4 4 KV Switchgear 16% 0% 0% 0%

Reactor El 931 Area 5 Roof Area 16% 0% 0% 0%

Reactor El 958 Area 1 General Area 14% 25% 14% 30%

Reactor El 958 Area 2 Fuel Pool Cooling room 10% 25% 100% 30%

Reactor El 958 Area 3 RWCU piping 22% 25% 40% 30%

Reactor El 976 Area 1 Rx Recirc MG Sets 14% 25% 14% 30%

TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 DecommissioningCost Analysis Appendix E, Page 7 of 8 TABLE E-1 (continued)

WORK DIFFICULTY ADJUSTMENT FACTORS Work Difficulty Factors Area Identification Area Description Access Respirator ALARA Clothing Reactor El 976 Area 2 Standby Liquid Control 14% 25% 14% 30%

DRYWELL Drywell 22% 25% 40% 30%

Emergency CST's, RHR Control El 882 Area 1 service water pumps 14% 25% 14% 30%

Control El 903 Area 1 Switchgear 16% 0% 0% 0%

Control El 918 Area 1 Battery Rooms 16% 0% 0% 0%

Control Room, Computer Control El 932 Area 1 Room 14% 0% 0% 0%

Turbine El 882 Area 1 Condenser 14% 25% 14% 30%

Turbine El 882 Area 2 Diesel / Boiler Room roof 14% 25% 14% 30%

Condensate & FW Pumps Turbine El 882 Area 3 SJAE Room 14% 25% 14% 30%

Turbine El 903 Area 1 FW heaters, condenser 14% 25% 14% 30%

Turbine El 903 Area 2 Generator Bus Duct 14% 25% 14% 30%

Diesels/Boilers/Water Turbine El 903 Area 3 Treatment 10% 0% 0% 0%

Turbine El 903 Area 4 Machine Shop 16% 0% 0% 0%

Turbine El 932 Area 1 Turbine operating floor 14% 25% 14% 30%

Maintenance Office I Turbine El 932 Area 2 Storage Area 10% 0% 0% 0%

Turbine El 932 Area 3 Switchgear room 10% 0% 0% 0%

Augmented Radwaste El 877 Area 1 Waste Concentrator 14% 25% 14% 30%

Augmented Radwaste El 903 Area 1 Cask Shipping 14% 25% 14% 30%

Augmented Radwaste Concentrator heat El 918 Area 1 exchangers 14% 25% 14% 30%

Augmented Radwaste El 929 Area 1 Roof above charcoal tanks 14% 25% 14% 30%

TLG Services, Inc.

CooperNuclear Station Document N01-1590-002, Rev. 1 Decommissioning Cost Analysis Appendix E, Page 8 of 8 TABLE E-1 (continued)

WORK DIFFICULTY ADJUSTMENT FACTORS Work Difficulty Factors Area Identification Area Description Access Respirator ALARA Clothing Radwaste El 877 Area 1 General Basement area 14% 25% 14% 30%

Spent Resin & Backwash Radwaste El 877 Area 2 Separator Tanks 14% 25% 14% 30%

Sludge & Phase Separator Radwaste El 877 Area 3 Tanks 22% 25% 40% 30%

Drum Capping Handling Radwaste El 903 Area 1 Area 14% 25% 14% 30%

Resin Loading Station &

Radwaste El 903 Area 2 Control Room 14% 25% 14% 30%

Radwaste El 903 Area 3 Corridor 14% 25% 14% 30%

Radwaste El 918 Area 1 Resin Hoppers 22% 25% 40% 30%

Condensate Filter Radwaste El 918 Area 2 Demineralizer 14% 25% 14% 30%

Offices, Rad Chem Lab, Radwaste El 918 Area 3 Drum loading area 14% 25% 14% 30%

Radwaste El 934 Area 1 Resin Centrifuges 14% 25% 14% 30%

Demin removal area, Radwaste El 934 Area 2 Laundry, filter units 14% 25% 14% 30%

Radwaste El 949 Area 1 Radwaste Roof 14% 25% 14% 30%

Multi-Purpose Facility Multi-Purpose Facility 14% 25% 14% 30%

Intake Intake 10% 0% 0% 0%

Elevated release point, Yard Area 1 tanks 10% 0% 0% 0%

TLG Services, Inc.

CooperNuclear Station Document N01-1590-O02,Rev. 1 DecommissioningCost Analysis Appendix F, Page 1 of 14 APPENDIX F AREA MAPS

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Cooper Nuclear Station Document N01.1590-002, Rev. I DecommissioningCost Analysis Appendix F, Page9 of 14 CONTROL AND TURBINE BUILDINGS

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