Decommissioning Cost Analysis for the Catawba Nuclear Station

Document D03-1671-001, Rev. 0

DECOMMISSIONING COST ANALYSIS

for the

CATAWBA NUCLEAR STATION

prepared for

Duke Energy Corporation

prepared by

TLG Services, Inc. Bridgewater, Connecticut

December 2013

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APPROVALS Project Manager William A. Cloutier, Jr. Date Project Engineer Thomas J. Garrett Date Technical Manager Francis W. Seymore Date

Project ManagerDate

Project EngineerDate

Technical ManagerDate

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TABLE OF CONTENTS

SECTION PAGE EXECUTIVE SUMMARY ................................................................................... vii-xix 1. INTRODUCTION ..................................................................................................... 1-1 1.1 Objectives of Study ........................................................................................... 1-1 1.2 Site Description ................................................................................................. 1-2 1.3 Regulatory Guidance ........................................................................................ 1-3 1.3.1 Nuclear Waste Policy Act ...................................................................... 1-5 1.3.2 Low-Level Radioactive Waste Acts ...................................................... 1-7 1.3.3 Radiological Criteria for License Termination .................................... 1-8 2. DECOMMISSIONING ALTERNATIVES .............................................................. 2-1 2.1 DECON .............................................................................................................. 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 .......................................................................................................... 2-9 2.2.1 Period 1 - Preparations ......................................................................... 2-9 2.2.2 Period 2 - Dormancy ............................................................................ 2-10 2.2.3 Periods 3 and 4 - Delayed Decommissioning ..................................... 2-11 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 ........................................................................................... 3-3 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 Retired Components ............................................................................ 3-11 3.4.6 Transportation Methods ..................................................................... 3-11

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TABLE OF CONTENTS (continued)

SECTION PAGE 3.4.7 Low-Level Radioactive Waste Disposal ............................................. 3-12 3.4.8 Site Conditions Following Decommissioning .................................... 3-13 3.5 Assumptions .................................................................................................... 3-14 3.5.1 Estimating Basis ................................................................................. 3-15

3.5.2 Labor Costs .......................................................................................... 3-15 3.5.3 Design Conditions................................................................................ 3-16

3.5.4 General ................................................................................................. 3-16 3.6 Cost Estimate Summary ............................................................................... 3-18 4. SCHEDULE ESTIMATE ........................................................................................ 4-1 4.1 Schedule Estimate Assumptions ..................................................................... 4-1 4.2 Project Schedule ................................................................................................ 4-2 5. RADIOACTIVE WASTES ........................................................................................ 5-1 6. RESULTS ................................................................................................................. 6-1 7. REFERENCES .......................................................................................................... 7-1

TABLES DECON Cost Summary, Decommissioning Cost Elements ......................... xviii SAFSTOR Cost Summary, Decommissioning Cost Elements ....................... xix 3.1 Spent Fuel Management Schedule ................................................................ 3-20 3.2 DECON Alternative, Unit 1, Total Annual Expenditures ........................... 3-22 3.2a DECON Alternative, Unit 1, License Termination Expenditures ............... 3-23 3.2b DECON Alternative, Unit 1, Spent Fuel Management Expenditures ........ 3-24 3.2c DECON Alternative, Unit 1, Site Restoration Expenditures ...................... 3-25 3.3 DECON Alternative, Unit 2, Total Annual Expenditures ........................... 3-26 3.3a DECON Alternative, Unit 2, License Termination Expenditures ............... 3-27 3.3b DECON Alternative, Unit 2, Spent Fuel Management Expenditures ........ 3-28 3.3c DECON Alternative, Unit 2, Site Restoration Expenditures ...................... 3-29 3.4 SAFSTOR Alternative, Unit 1, Total Annual Expenditures ........................ 3-30 3.4a SAFSTOR Alternative, Unit 1, License Termination Expenditures ........... 3-32 3.4b SAFSTOR Alternative, Unit 1, Spent Fuel Management Expenditures ..... 3-34 3.4c SAFSTOR Alternative, Unit 1, Site Restoration Expenditures ................... 3-35

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TABLE OF CONTENTS (continued)

SECTION PAGE

TABLES (continued) 3.5 SAFSTOR Alternative, Unit 2, Total Annual Expenditures ........................ 3-36 3.5a SAFSTOR Alternative, Unit 2, License Termination Expenditures ........... 3-38 3.5b SAFSTOR Alternative, Unit 2, Spent Fuel Management Expenditures ..... 3-40 3.5c SAFSTOR Alternative, Unit 2, Site Restoration Expenditures ................... 3-41 5.1 DECON Alternative, Decommissioning Waste Summary ............................. 5-5 5.2 SAFSTOR Alternative, Decommissioning Waste Summary .......................... 5-6 6.1 DECON Alternative, Decommissioning Cost Elements ................................. 6-4 6.2 SAFSTOR Alternative, Decommissioning Cost Elements ............................. 6-5

FIGURES 4.1 Activity Schedule .............................................................................................. 4-3 4.2 Decommissioning Timeline, DECON .............................................................. 4-4 4.3 Decommissioning Timeline, SAFSTOR .......................................................... 4-5 5.1 Radioactive Waste Disposition ........................................................................ 5-3 5.2 Decommissioning Waste Destinations, Radiological ...................................... 5-4

APPENDICES A. Unit Cost Factor Development ............................................................................. A-1 B. Unit Cost Factor Listing ...................................................................................... B-1 C. Detailed Cost Analysis, DECON .......................................................................... C-1 D. Detailed Cost Analysis, SAFSTOR ...................................................................... D-1 E. ISFSI Decommissioning Cost Summary ............................................................. E-1

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REVISION LOG

No. Date Item Revised Reason for Revision

0

12-09-2013

Original Issue

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EXECUTIVE SUMMARY This report presents estimates of the cost to decommission the Catawba Nuclear Station (Catawba) for the selected decommissioning scenarios following the scheduled cessation of plant operations. The estimates are designed to provide Duke Energy Corporation, (Duke Energy) with sufficient information to assess the plant owners’ financial obligations, as they pertain to the eventual decommissioning of the nuclear station. The analysis relies upon site-specific, technical information from an evaluation prepared in 2008,[1] updated to reflect current assumptions pertaining to the disposition of the nuclear plant and relevant industry experience in undertaking such projects. The costs are based on several key assumptions in areas of regulation, component characterization, high-level radioactive waste management, low-level radioactive waste disposal, performance uncertainties (contingency) and site restoration requirements. The analysis is not a detailed engineering evaluation, but estimates prepared in advance of the detailed engineering required to carry out the decommissioning of the nuclear station. It may also not reflect the actual plan to decommission Catawba; the plan may differ from the assumptions made in this analysis based on facts that exist at the time of decommissioning. The plant inventory, the basis for the decontamination and dismantling requirements and cost, and the decommissioning waste streams, was reviewed for this analysis. The plant confirmed that there were no substantive changes over the five year period to the configuration of the plant or site facilities (that would significantly impact decommissioning). However, some minor plant additions were identified and included in the current study. The costs to decommission Catawba for the scenarios evaluated are tabulated at the end of this section. Costs are reported in 2013 dollars and include monies anticipated to be spent for radiological remediation and operating license termination, spent fuel management, and site restoration activities. A complete discussion of the assumptions relied upon in this analysis is provided in Section 3, along with schedules of annual expenditures for each scenario. A sequence of significant project activities is provided in Section 4 with a timeline for each

1 “Decommissioning Cost Analysis for the Catawba Nuclear Station,” Document D03-1594-002, Rev.

0, TLG Services, Inc., December 2008

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scenario. Detailed cost reports used to generate the summary tables contained within this document are provided in Appendices C and D. Consistent with the 2008 analysis, the current cost estimates assume that the shutdown of the nuclear station is a scheduled and pre-planned event (e.g., there is no delay in transitioning the plant and workforce from operations or in obtaining regulatory relief from operating requirements, etc.). The estimates include the continued operation of the fuel handling buildings as interim wet fuel storage facilities for ten years after operations cease. During this time period, it is assumed that the spent fuel residing in the pools will be transferred to the Department of Energy (DOE). Once the pools are emptied, the spent fuel stored at the independent spent fuel storage installation (ISFSI) will be transferred to the DOE. The ISFSI, consisting of transportable storage canisters to house the spent fuel assemblies, and steel-lined vertical concrete casks, will remain operational until the DOE is able to complete the transfer of the fuel to a federal facility (e.g., a monitored retrievable storage facility).[2] DOE officials have stated that DOE does not have an obligation to accept already-canistered fuel without an amendment to DOE’s contracts with plant licensees to remove the fuel (the “Standard Contract”), but DOE has not explained what any such amendment would involve. For purposes of this analysis, it is assumed that DOE will accept already-canistered fuel. Alternatives and Regulations The Nuclear Regulatory Commission (NRC) provided general decommissioning requirements in a rule adopted on June 27, 1988. [3] In this rule, the NRC set forth technical and financial criteria for decommissioning licensed nuclear facilities. The regulations addressed planning needs, timing, funding methods, and environmental review requirements for decommissioning. The rule also defined three 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

2 Projected expenditures for spent fuel management identified in the cost analyses do not consider

the outcome of the litigation with the DOE with regard to the delays incurred by the owners in the timely removal of spent fuel from the site.

3 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

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property to be released for unrestricted use shortly after cessation of operations."[4]

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."[5]

Decommissioning is required to be completed within 60 years, although longer time periods will be considered when necessary to protect public health and safety. 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."[6] 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.[7] The amendments allow for greater public participation and better define 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 staff for implementing the requirements of the 1996 revised rule that relate to the

4 Ibid. Page FR24022, Column 3

5 Ibid.

6 Ibid. Page FR24023, Column 2

7 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

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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. The format and content of the estimates is also consistent with the recommendations of Regulatory Guide 1.202, issued February 2005.[8]

Decommissioning Scenarios Two decommissioning scenarios were evaluated for Catawba. The scenarios selected are representative of alternatives available to the owners and are defined as follows: 1. The first scenario assumes that the station would be promptly decommissioned

(DECON alternative) upon the expiration of the current operating licenses, i.e., in 2043. The spent fuel in the plant’s spent fuel storage pools is transferred to the DOE within the first ten years. The equipment, structures, and portions of the plant containing radioactive contaminants are removed or decontaminated to a level that permits the facility to be released for unrestricted use. Site structures are then demolished. Spent fuel storage operations continue at the site until the transfer of the fuel to the DOE is complete, assumed to be in the year 2066.

2. In the second scenario, the nuclear station is placed into safe-storage (SAFSTOR

alternative) at the end of its current operating license. The spent fuel in the plant’s spent fuel storage pools is transferred to the DOE and the plant reconfigured for long-term storage. Spent fuel storage operations continue at the site until the transfer of the fuel to the DOE is complete, assumed to be in the year 2066. Decommissioning operations commence in 2098, with the decontamination and dismantling of Catawba completed in 2103, sixty years after the cessation of operations. Site structures are then demolished.

Methodology The methodology used to develop the estimates follows the basic approach originally presented in the cost estimating guidelines[9] 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.

8 “Standard Format and Content of Decommissioning Cost Estimates for Nuclear Power Reactors,”

Regulatory Guide 1.202, Nuclear Regulatory Commission, February 2005

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

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An activity duration critical path is used to determine the total decommissioning program schedule. This is required for calculating the carrying costs, which include program management, administration, field engineering, equipment rental, quality assurance, and security. This systematic approach for assembling decommissioning estimates ensures a high degree of confidence in the reliability of the resulting costs. The estimates also reflect lessons learned from previously completed decommissioning projects, including TLG’s involvement in the Shippingport Station decommissioning, completed in 1989, and 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 technical challenges of decommissioning commercial nuclear units. Contingency Consistent with 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.”[10] 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 generally 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

10 Project and Cost Engineers’ Handbook, Second Edition, American Association of Cost Engineers,

Marcel Dekker, Inc., New York, New York, p. 239.

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Amendments of 1985, [11] the states became ultimately responsible for the disposition of low-level radioactive waste generated within their own borders. South Carolina is a member of the three-state Atlantic Interstate Low-Level Radioactive Waste Management Compact, formed after South Carolina formally joined the Northeast Regional Compact. As such, the owners will continue to have access to the currently operating disposal facility in Barnwell, South Carolina. Disposition of the various waste streams produced by the decommissioning process considered all options and services currently available to Duke Energy. The majority of the low-level radioactive waste designated for direct disposal (Class A[12]) can be sent to EnergySolutions’ facility in Clive, Utah. The rate schedule for the Barnwell facility is used to generate disposal costs for the large components and the higher activity waste forms waste (Class B and C material[13]). It is also assumed that Duke Energy can access other disposal sites, should it prove cost-effective. Low activity waste forms (concrete debris, dry-active waste) and metallic waste suspected of being contaminated are routed to a Tennessee-based radioactive waste processor for decontamination, volume reduction and/or disposal. The dismantling of the components residing closest to the reactor core generates radioactive waste that may be 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. For purposes of this analysis, the GTCC radioactive waste is assumed to be packaged and disposed of in a similar manner as high-level waste and at a cost equivalent to that envisioned for the spent fuel. The GTCC is packaged in canisters compatible with the spent fuel dry storage system and either stored on site or shipped directly to a federal facility as it is generated (depending upon the timing of the decommissioning and whether the spent fuel has been removed from the site prior to the start of decommissioning). 11 “Low-Level Radioactive Waste Policy Amendments Act of 1985,” Public Law 99-240, January 15,

1986

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

13 U.S. Code of Federal Regulations, Title 10, Part 61, “Licensing Requirements for Land Disposal of Radioactive Waste”

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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 reflect the savings from waste recovery/volume reduction. High-Level Radioactive Waste Management Congress passed the “Nuclear Waste Policy Act” (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 DOE was to begin accepting spent fuel by January 31, 1998; however, to date no progress in the removal of spent fuel from commercial generating sites has been made. Today, the country is at an impasse on high-level waste disposal, even with the License Application for a geologic repository submitted by the DOE to the NRC in 2008. The current administration has cut the budget for the repository program while promising to “conduct a comprehensive review of policies for managing the back end of the nuclear fuel cycle … and make recommendations for a new plan.”[14] Towards this goal, the administration appointed a Blue Ribbon Commission on America’s Nuclear Future (Blue Ribbon Commission) to make recommendations for a new plan for nuclear waste disposal. The Blue Ribbon Commission’s charter includes a requirement that it consider “[o]ptions for safe storage of used nuclear fuel while final disposition pathways are selected and deployed.”[15] On January 26, 2012, the Blue Ribbon Commission issued its “Report to the Secretary of Energy” containing a number of recommendations on nuclear waste disposal. Two of the recommendations that may impact decommissioning planning are:

“[T]he United States [should] establish a program that leads to the timely development of one or more consolidated storage facilities”[16]

14 Blue Ribbon Commission on America’s Nuclear Future’s Charter,

http://cybercemetery.unt.edu/archive/brc/20120620215336/http://brc.gov/index.php?q=page/charter

15 Ibid.

16 “Blue Ribbon Commission on America’s Nuclear Future, Report to the Secretary of Energy,” http://www.brc.gov/sites/default/files/documents/brc_finalreport_jan2012.pdf, p. 32, January

2012

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“[T]he United States should undertake an integrated nuclear waste management program that leads to the timely development of one or more permanent deep geological facilities for the safe disposal of spent fuel and high-level nuclear waste.”[17]

In January 2013, the DOE issued the “Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste,” in response to the recommendations made by the Blue Ribbon Commission and as “a framework for moving toward a sustainable program to deploy an integrated system capable of transporting, storing, and disposing of used nuclear fuel...”[18] “With the appropriate authorizations from Congress, the Administration currently plans to implement a program over the next 10 years that:

Sites, designs and licenses, constructs and begins operations of a pilot interim storage facility by 2021 with an initial focus on accepting used nuclear fuel from shut-down reactor sites;

Advances toward the siting and licensing of a larger interim storage facility to be available by 2025 that will have sufficient capacity to provide flexibility in the waste management system and allows for acceptance of enough used nuclear fuel to reduce expected government liabilities; and

Makes demonstrable progress on the siting and characterization of repository sites to facilitate the availability of a geologic repository by 2048.”[19]

Completion of the decommissioning process is dependent upon the DOE’s ability to remove spent fuel from the site in a timely manner. DOE’s repository program had assumed that spent fuel allocations would be accepted for disposal from the nation’s commercial nuclear plants, with limited exceptions, in the order (the “queue”) in which it was discharged from the reactor.[20] Duke Energy’s current spent fuel management plan for the Catawba spent fuel is based in general upon: 1) a 2025

17 Ibid., p.27

18 “Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste,” U.S. DOE, January 11, 2013

19 Ibid., p.2

20 U.S. Code of Federal Regulations, Title 10, Part 961.11, Article IV – Responsibilities of the Parties, B. DOE Responsibilities, 5.(a) … DOE shall issue an annual acceptance priority ranking for receipt of SNF and/or HLW at the DOE repository. This priority ranking shall be based on the age of SNF and/or HLW as calculated from the date of discharge of such materials from the civilian nuclear power reactor. The oldest fuel or waste will have the highest priority for acceptance …”

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start date for DOE initiating transfer of commercial spent fuel to a federal facility (based upon the proposed timeline for the availability of the larger interim storage facility), 2) expectations for spent fuel receipt by the DOE for the McGuire fuel, and 3) reassignment of allocations between the Oconee, McGuire and Catawba units in the Duke Energy fleet so as to minimize on-site storage costs. The DOE’s generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. Assuming a maximum rate of transfer of 3,000 metric tons of uranium (MTU)/year, [21] the spent fuel from Catawba is completely removed from the site by 2066 if the units cease operating in 2043. The NRC requires that licensees establish a program to manage and provide funding for the caretaking of all irradiated fuel at the reactor site until title of the fuel is transferred to the DOE. [22] Interim storage of the fuel, until the DOE has completed the transfer, will be in the fuel handling buildings’ storage pool as well as at an on-site ISFSI. An ISFSI, operated under a Part 50 General License (in accordance with 10 CFR 72, Subpart K [23]), has been constructed to support continued plant operations. Spent fuel stored at the ISFSI will be transferred to the DOE once the spent fuel assemblies in the storage pool have been removed. Once the storage pool is emptied, the fuel handling buildings can be either decontaminated and dismantled or prepared for long-term storage. Duke Energy’s position is that the DOE has a contractual obligation to accept the spent 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. Site Restoration The efficient removal of the contaminated materials at the site may result in damage to many of the site structures. Blasting, coring, drilling, and the other decontamination activities can substantially damage power block structures, potentially weakening the footings and structural supports. It is 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

21 “Acceptance Priority Ranking & Annual Capacity Report,” DOE/RW-0567, July 2004

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

23 U.S. Code of Federal Regulations, Title 10, Part 72, Subpart K, “General License for Storage of Spent Fuel at Power Reactor Sites.”

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work force already mobilized is more efficient and less costly than if the process is deferred. Consequently, this study assumes that site structures addressed by this analysis are removed to a nominal depth of three feet below the local grade level wherever possible. The site is then graded and stabilized. The cost for the site restoration of decontaminated and/or non-contaminated structures has been calculated and is separately presented as "Site Restoration” expenditures in this report. Summary The estimates to decommission Catawba assume the removal of all contaminated and activated plant components and structural materials such that the owners 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 facility can also be decommissioned. The alternatives evaluated in this analysis are described in Section 2. The assumptions are presented in Section 3, along with 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 for the DECON and SAFSTOR alternatives are assigned to one of three subcategories: NRC License Termination (radiological remediation), Spent Fuel Management, and Site Restoration. The subcategory “NRC License Termination” is used to accumulate costs that are consistent with “decommissioning” as defined by the NRC in its financial assurance regulations (i.e., 10 CFR §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 License Termination cost subcategory also includes costs to decommission the ISFSI (as required by 10 CFR §72.30). Section 3.4.1 provides the basis for the ISFSI decommissioning cost. The “Spent Fuel Management” subcategory contains costs associated with the containerization and transfer of spent fuel from the wet storage pools to the DOE, as well as the eventual transfer of the spent fuel in storage at the ISFSI to the

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DOE. Costs are included for the operation of the storage pools and the management of the ISFSI until such time that the transfer is complete. It does not include any spent fuel management expenses incurred prior to the cessation of plant operations, nor does it include any costs related to the final disposal of the spent fuel. “Site Restoration” is used to capture costs associated with the dismantling and demolition of buildings and facilities demonstrated to be free from contamination. This includes structures never 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 2013 dollars. As such, the estimates do not reflect the escalation of costs (due to inflationary and market forces) over the remaining operating life of the plant or during the decommissioning period.

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DECON COST SUMMARY DECOMMISSIONING COST ELEMENTS

(thousands of 2013 dollars)

Cost Element Unit 1 Unit 2 Total Decontamination 14,962 15,689 30,651 Removal 100,495 147,281 247,776 Packaging 29,027 27,033 56,060 Transportation 11,840 11,379 23,218 Waste Disposal 70,123 66,172 136,295 Off-site Waste Processing 29,882 30,991 60,873 Program Management [1] 204,914 215,764 420,677 Site Security 32,518 58,282 90,801 Corporate A&G 19,251 20,282 39,534 Site O&M 1,895 1,933 3,829 Spent Fuel Pool Isolation 12,145 8,096 20,241 Spent Fuel (Direct Expenditures) [2] 41,811 63,133 104,943 Insurance and Regulatory Fees 15,591 20,455 36,047 Energy 5,672 5,718 11,390 Characterization and Licensing Surveys 21,116 22,072 43,188 Property Taxes 32,292 32,884 65,176 Miscellaneous Equipment 6,566 6,604 13,170 Miscellaneous Site Services 0 7,025 7,025 Total [3] 650,100 760,793 1,410,893

Cost Element License Termination 564,728 571,010 1,135,738 Spent Fuel Management 46,133 110,736 156,869 Site Restoration 39,238 79,047 118,285 Total [3] 650,100 760,793 1,410,893

[1] Includes engineering costs

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

[3] Columns may not add due to rounding

Catawba Nuclear Station Document D03-1671-001, Rev. 0 Decommissioning Cost Analysis Page xix of xix

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SAFSTOR COST SUMMARY DECOMMISSIONING COST ELEMENTS

(thousands of 2013 dollars)

Cost Element Unit 1 Unit 2 Total Decontamination 12,441 12,943 25,384 Removal 94,722 141,170 235,892 Packaging 21,817 19,823 41,640 Transportation 7,890 7,310 15,201 Waste Disposal 55,435 51,117 106,552 Off-site Waste Processing 32,695 34,018 66,713 Program Management [1] 236,442 237,093 473,535 Site Security 69,210 70,138 139,348 Corporate A&G 22,620 22,684 45,303 Site O&M 3,925 3,950 7,875 Spent Fuel Pool Isolation 12,145 8,096 20,241 Spent Fuel (Direct Expenditures) [2] 48,694 51,655 100,349 Insurance and Regulatory Fees 55,132 54,315 109,447 Energy 9,999 9,941 19,940 Characterization and Licensing Surveys 20,176 21,130 41,306 Property Taxes 33,630 33,651 67,281 Miscellaneous Equipment 19,015 23,946 42,960 Miscellaneous Site Services 7,025 7,025 Total [3] 755,987 810,007 1,565,994

Cost Element License Termination 582,758 594,452 1,177,210 Spent Fuel Management 133,957 136,917 270,874 Site Restoration 39,272 78,638 117,910 Total [3] 755,987 810,007 1,565,994




Catawba Nuclear Station Document D03-1671-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 1 of 9

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1. INTRODUCTION This report presents estimates of the cost to decommission the Catawba Nuclear Station (Catawba) for the selected decommissioning scenarios following the scheduled cessation of plant operations. The estimates are designed to provide Duke Energy Corporation (Duke Energy) with sufficient information to assess the plant owners’ financial obligations, as they pertain to the eventual decommissioning of the nuclear station. The analysis relies upon site-specific, technical information from an earlier evaluation prepared in 2008,[1]* updated to reflect current assumptions pertaining to the disposition of the nuclear plant and relevant industry experience in undertaking such projects. The costs are based on several key assumptions in areas of regulation, component characterization, high-level radioactive waste management, low-level radioactive waste disposal, performance uncertainties (contingency) and site restoration requirements. The analysis is not a detailed engineering evaluation, but rather estimates prepared in advance of the detailed engineering required to carry out the decommissioning of the nuclear station. It may also not reflect the actual plan to decommission Catawba; the plan may differ from the assumptions made in this analysis based on facts that exist at the time of decommissioning. The plant inventory, the basis for the decontamination and dismantling requirements and cost, and the decommissioning waste streams, were reviewed for this analysis. The plant confirmed that there were no substantive changes over the five-year period to the configuration of the plant or site facilities (that would significantly impact decommissioning). However, some minor plant additions were identified and included in the current study. 1.1 OBJECTIVES OF STUDY

The objectives of this study are to prepare comprehensive estimates of the costs to decommission Catawba, to provide a sequence or schedule for the associated activities, and to develop waste stream projections from the decontamination and dismantling activities. For the purposes of this study, the shutdown date for the station is assumed to be December 5, 2043, based upon the current operating licenses.

* References provided in Section 7 of the document


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1.2 SITE DESCRIPTION Catawba is located in York County, South Carolina, approximately 17 miles southwest of Charlotte, North Carolina and 6 miles north-northwest of Rock Hill, South Carolina on the shore of Lake Wylie. The station is comprised of two nuclear units that are essentially identical except for certain auxiliary systems. The Nuclear Steam Supply System (NSSS) consists of a pressurized water reactor and four-loop reactor coolant system. Each generating unit has a reference core design of 3,411 megawatts (thermal) with a corresponding net electrical rating of 1,129 megawatts (electric), with the reactor at rated power. The reactor coolant system is comprised of the reactor vessel and four heat transfer loops, each containing a vertical U-tube type steam generator, and a single speed centrifugal reactor coolant pump. In addition, the system includes an electrically heated pressurizer, a pressurizer relief tank, and interconnected piping. The system is housed within a containment vessel, a free-standing cylindrical steel structure enclosed by a separate reinforced concrete reactor building. The reactor building houses the containment vessel and is designed to provide biological shielding as well as missile protection for the steel containment vessel. A six-foot annulus space is provided between the containment vessel and reactor building for control of containment external temperatures and pressures and also provides a controlled air volume for filtering and access to penetrations for testing and inspection. The containment shell is anchored to the reactor building foundation with a steel liner plate encased in concrete forming the base of the containment. Heat produced in the reactor is converted to electrical energy by the steam and power conversion system. A turbine-generator system converts the thermal energy of steam produced in the steam generators into mechanical shaft power and then into electrical energy. The turbine generators consist of a tandem (single shaft) arrangement of a double-flow high-pressure turbine and three identical double-flow, low-pressure turbines driving a direct-coupled generator at 1800 rpm. The turbines are operated in a closed feedwater cycle, which condenses the steam. The heated feedwater is returned to the steam generators. The condenser circulating water system removes heat rejected in the main condensers. The heat is dissipated to the ambient surroundings in a closed-cycle system using three round, mechanical draft, cross-flow Marley cooling towers per unit. During normal operation, makeup cooling water for the


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nuclear service water and low pressure service water systems is pumped from the Beaver Dam Creek arm of Lake Wylie and returned to Big Allison Creek.

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.[2] 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,”[3] which provided additional guidance to the licensees of nuclear facilities on the financial methods acceptable to the NRC staff for complying with the requirements of the rule. The regulatory guide addressed the funding requirements and provided guidance on the content and form of the financial assurance mechanisms indicated in the rule. 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, while the SAFSTOR and ENTOMB alternatives defer the process. The rule also placed limits on the time allowed to complete the decommissioning process. For all alternatives, the process is restricted in overall duration to 60 years, unless it can be shown that a longer duration is necessary to protect public health and safety. At the conclusion of a 60-year dormancy period (or longer if the NRC approves such a case), the site would still require significant remediation to meet the unrestricted release limits for 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,[4] the NRC did re-evaluate the alternative. The resulting feasibility study, based upon an assessment by Pacific Northwest National Laboratory, concluded that the method did have conditional merit for some, if not most reactors. The staff also found that


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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.[5] However, the NRC’s staff has subsequently 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 staff’s recommendation. In 1996, the NRC published revisions to the general requirements for decommissioning nuclear power plants.[6] 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 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, along with related changes to Technical Specifications, 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 includes a license termination plan (LTP).


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1.3.1 Nuclear Waste Policy Act

Congress passed the “Nuclear Waste Policy Act” (NWPA) in 1982,[7] 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 Amendments Act of 1987[8] designated Yucca Mountain as the sole site to be considered for a permanent geologic repository. The DOE was to begin accepting spent fuel by January 31, 1998; however, to date no progress in the removal of spent fuel from commercial generating sites has been made. Today, the country is at an impasse on high-level waste disposal, even with the License Application for a geologic repository submitted by the DOE to the NRC in 2008. The current administration has cut the budget for the repository program while promising to “conduct a comprehensive review of policies for managing the back end of the nuclear fuel cycle … and make recommendations for a new plan.” Towards this goal, the administration appointed a Blue Ribbon Commission on America’s Nuclear Future (Blue Ribbon Commission) to make recommendations for a new plan for nuclear waste disposal. On January 26, 2012, the Blue Ribbon Commission issued its “Report to the Secretary of Energy”[9] containing a number of recommendations on nuclear waste disposal. Two of the recommendations that may impact decommissioning planning are: “[T]he United States [should] establish a program that leads to

the timely development of one or more consolidated storage facilities”

“[T]he United States should undertake an integrated nuclear waste management program that leads to the timely development of one or more permanent deep geological facilities for the safe disposal of spent fuel and high-level nuclear waste.”

In January 2013, the DOE issued the “Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste,” in response to the recommendations made by the Blue Ribbon Commission and as “a framework for moving toward a sustainable program to deploy an integrated system capable of transporting, storing, and disposing of used nuclear fuel...”[10] “With the appropriate authorizations from Congress, the Administration currently plans to implement a program over the next 10 years that:


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Sites, designs and licenses, constructs and begins operations of a pilot interim storage facility by 2021 with an initial focus on accepting used nuclear fuel from shut-down reactor sites;

Advances toward the siting and licensing of a larger interim storage facility to be available by 2025 that will have sufficient capacity to provide flexibility in the waste management system and allows for acceptance of enough used nuclear fuel to reduce expected government liabilities; and

Makes demonstrable progress on the siting and characterization of repository sites to facilitate the availability of a geologic repository by 2048.”

Completion of the decommissioning process is dependent upon the DOE’s ability to remove spent fuel from the site in a timely manner. DOE’s repository program had assumed that spent fuel allocations would be accepted for disposal from the nation’s commercial nuclear plants, with limited exceptions, in the order (the “queue”) in which it was discharged from the reactor.[11] Duke Energy’s current spent fuel management plan for the Catawba spent fuel is based in general upon: 1) a 2025 start date for DOE initiating transfer of commercial spent fuel to a federal facility (based upon the proposed timeline for the availability of the larger interim storage facility), 2) expectations for spent fuel receipt by the DOE for the Catawba fuel, and 3) reassignment of allocations between the Oconee, McGuire and Catawba units in the Duke Energy fleet so as to minimize on-site storage costs. The DOE’s generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. Assuming a maximum rate of transfer of 3,000 metric tons of uranium (MTU)/year,[12] the spent fuel from Catawba is completely removed from the site by 2066 if the units ceases operating in 2043. The NRC requires that licensees establish a program to manage and provide funding for the caretaking of all irradiated fuel at the reactor site until title of the fuel is transferred to the DOE.[13] Interim storage of the fuel, until the DOE has completed the transfer, will be in the fuel handling buildings’ storage pool as well as at an on-site ISFSI. An ISFSI, operated under a Part 50 General License (in accordance with 10 CFR 72, Subpart K [14]), has been constructed to support continued plant operations. Spent fuel stored at the ISFSI will be transferred to the DOE once the spent fuel assemblies in the storage pool have been


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removed. Once the storage pools are emptied, the fuel handling buildings can be either decontaminated and dismantled or prepared for long-term storage. Duke Energy’s position is that the DOE has a contractual obligation to accept the spent 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.

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,[15] and its Amendments of 1985,[16] the states became ultimately responsible for the disposition of low-level radioactive waste generated within their own borders. South Carolina is a member of the three-state Atlantic Interstate Low-Level Radioactive Waste Management Compact, formed after South Carolina formally joined the Northeast Regional Compact. As such, the owners will continue to have access to the currently operating disposal facility in Barnwell, South Carolina. Disposition of the various waste streams produced by the decommissioning process considered all options and services currently available to Duke Energy. The majority of the low-level radioactive waste designated for direct disposal (Class A[17]) can be sent to EnergySolutions’ facility in Clive, Utah. The rate schedule for the Barnwell facility is used to generate disposal costs for the large components and the higher activity waste forms waste (Class B and C material). It is also assumed that Duke Energy can access other disposal sites, should it prove cost-effective. Low activity waste forms (concrete debris, dry-active waste) and metallic waste suspected of being contaminated are routed to a Tennessee-based radioactive waste processor for decontamination, volume reduction and/or disposal. The dismantling of the components residing closest to the reactor core generates radioactive waste that may be considered unsuitable for shallow-land disposal (i.e., low-level radioactive waste with concentrations of radionuclides that exceed the limits established by the


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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. For purposes of this analysis, the GTCC radioactive waste is assumed to be packaged and disposed of in a similar manner as high-level waste and at a cost equivalent to that envisioned for the spent fuel. The GTCC is packaged in canisters compatible with the spent fuel dry storage system and either stored on site or shipped directly to a federal facility as it is generated (depending upon the timing of the decommissioning and whether the spent fuel has been removed from the site prior to the start of decommissioning). A significant portion of the waste material generated during 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 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,”[18] 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 Catawba site will be remediated to a residual level consistent with the NRC-prescribed level.


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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 Response, Compensation, and Liability Act (CERCLA or Superfund).[19] An additional and separate limit of 4 millirem per year, as defined in 40 CFR §141.16, is applied to drinking water.[20]

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)[21] 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.


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2. DECOMMISSIONING ALTERNATIVES Detailed cost estimates were developed to decommission Catawba based upon the NRC-approved decommissioning alternatives DECON and SAFSTOR. Although the alternatives differ with respect to technique, process, cost, and schedule, they attain the same result: the ultimate release of the site for unrestricted use. Two decommissioning scenarios were evaluated for the Catawba Nuclear Station. The scenarios selected are representative of alternatives available to the owners and are defined as follows: 1. The first scenario assumes that the station would be promptly decommissioned

(DECON alternative) upon the expiration of the current operating licenses, i.e., in 2043. The spent fuel in the plant’s spent fuel storage pools is transferred to the DOE within the first ten years. The equipment, structures, and portions of the plant containing radioactive contaminants are removed or decontaminated to a level that permits the facility to be released for unrestricted use. Site structures are then demolished. Spent fuel storage operations continue at the site (ISFSI) until the transfer of the fuel to the DOE is complete, assumed to be in the year 2066.

2. In the second scenario, the nuclear station is placed into safe-storage (SAFSTOR

alternative) at the end of its current operating license. The spent fuel in the plant’s spent fuel storage pools is transferred to the DOE and the plant reconfigured for long-term storage. Spent fuel storage operations continue at the site until the transfer of the fuel to the DOE is complete, assumed to be in the year 2066. Decommissioning operations commence in 2098, with the decontamination and dismantling of Catawba completed in 2103, sixty years after the cessation of operations. Site structures are then demolished.

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


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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 Catawba 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 characterization of the facility and major components, and the development of the PSDAR. Engineering and Planning The PSDAR, required prior to or within two years of permanent cessation of 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.


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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 coolant 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 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:


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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 biologic shield cores.

Isolation of the spent fuel storage pools and fuel handling systems, such that decommissioning operations can commence on the balance of the plant. The pools will remain operational for ten years following the cessation of operations before the inventory resident at shutdown can be transferred to the DOE.

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 release of the site from the 10 CFR §50 operating license, exclusive of the ISFSI. Significant decommissioning activities in this phase include: Construction of temporary facilities and/or modification of existing

facilities to support dismantling activities. For example, this will include a centralized processing area to facilitate equipment removal and component preparations for off-site disposal.

Reconfiguration and modification of site structures and facilities as needed to support decommissioning operations. This will include the upgrading of roads (on- and off-site) to facilitate hauling and transport. Modifications will be required to the containment structure to facilitate access of large/heavy equipment. Modifications will also be required to the refueling area of the Reactor Building to support the segmentation of the reactor vessel internals and component extraction.

Transfer of the spent fuel from the storage pools to the DOE.


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

Procurement (lease or purchase) of shipping casks, cask liners, and industrial packages.

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.

Removal of control rod drive housings and the head service structure from reactor vessel head. Segmentation of the vessel closure head.

Removal and segmentation of the upper internals assemblies. Segmentation will maximize the loading of the shielded transport casks, i.e., by weight and activity. The operations are conducted under water using remotely operated tooling and contamination controls.

Disassembly and segmentation of the remaining reactor internals, including the core former and lower core support assembly. Some material is expected to exceed Class C disposal requirements. As such, the segments will be packaged in modified fuel storage canisters for geologic disposal.

Segmentation of the reactor vessel. A shielded platform is installed for segmentation as cutting operations are performed in-air using remotely operated equipment within a contamination control envelope. The water level is maintained just below the cut to minimize the working area dose rates. Segments are transferred in-air to containers that are stored under water, for example, in an isolated area of the refueling canal.

Removal of the activated portions of the concrete biological shield and accessible contaminated concrete surfaces. If dictated by the steam generator and pressurizer removal scenarios, those portions of the associated cubicles necessary for access and component extraction are removed.

Removal of the steam generators and pressurizer for material recovery and controlled disposal. These components can serve as their own burial containers provided that all penetrations are properly sealed and the internal contaminants are stabilized, e.g., with grout. Steel shielding will be added, as necessary, to those


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external areas of the package to meet transportation limits and regulations.

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 refueling canal, disposing of the activated and contaminated sections as radioactive waste. Removal of any activated/ contaminated concrete.

Surveys of the decontaminated areas of the containment structure.

Remediation and removal of the contaminated equipment and material from the auxiliary and fuel buildings and any other contaminated facility. Radiation and contamination controls will be utilized until residual levels indicate that the structures and equipment can be released for unrestricted access and conventional demolition. This activity may necessitate the dismantling and disposition of most of the systems and components (both clean and contaminated) located within these buildings. This activity facilitates surface decontamination and subsequent verification surveys required prior to obtaining release for demolition.

Routing of material removed in the decontamination and dismantling to a central processing area. Material certified to be free of contamination is released for unrestricted disposition, e.g., as scrap, recycle, or general disposal. Contaminated material is characterized and segregated for additional off-site processing (disassembly, chemical cleaning, volume reduction, and waste treatment), and/or


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packaged for controlled disposal at a low-level radioactive waste disposal facility.

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).”[22] This document incorporates the statistical approaches to survey design and data interpretation used by the EPA. It also identifies commercially available instrumentation and procedures for conducting radiological surveys. Use of this guidance ensures that the surveys are conducted in a manner that provides a high degree of 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 the requested change to the operating license (that would release the property, exclusive of the ISFSI, for unrestricted use). The NRC will amend 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 property (exclusive of the ISFSI) is suitable for release.

2.1.3 Period 3 - Site Restoration Following completion of decommissioning operations, site restoration activities can 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, fuel handling, radioactive waste, solidification facility and condensate polishing 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


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have been recorded, or where it is required to confirm that subsurface process and drain lines were not breached over the operating life of the station. It is not currently anticipated that these structures would be repaired and preserved after the radiological contamination is removed. The cost to dismantle site structures with a work force already mobilized on site is more efficient than if the process is deferred. This cost study presumes that site structures and other 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 Transfer of spent fuel to a DOE repository or interim facility is assumed to be exclusively from the ISFSI once the fuel pools have been emptied and the fuel handling buildings released for decommissioning. The ISFSI will continue to operate under a general license (10 CFR Part 50) following the amendment of the operating license to release the adjacent (power block) property. Assuming the DOE starts accepting fuel from Catawba in 2028, transfer of spent fuel from the ISFSI is anticipated to continue through the year 2066. At the conclusion of the spent fuel transfer process, the ISFSI will be decommissioned. The Commission will terminate the Part 50 license if 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


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facility is suitable for release. Once the requirements are satisfied, the NRC can terminate the license for the ISFSI. The design of the ISFSI is based upon a transportable storage canister to house the spent fuel assemblies, and a steel-lined vertical concrete cask for pad storage. It is assumed that once the canisters containing the spent fuel assemblies have been removed, any required decontamination is performed on the storage modules (some minor neutron activation is assumed), and the license for the facility terminated, the modules can be dismantled using conventional techniques for the demolition of reinforced concrete. The concrete storage pad is then removed and the area regraded.

2.2 SAFSTOR

The NRC defines SAFSTOR as "the alternative in which the nuclear facility is placed and maintained in a condition that allows the nuclear facility to be safely stored and subsequently decontaminated (deferred decontamination) to levels that permit release for unrestricted use." The facility is left intact (during the dormancy period), with structures maintained in a sound condition. Systems that are not required to support the spent fuel pools or site surveillance and security are drained, de-energized, and secured. Minimal cleaning/removal of loose contamination and/or fixation and sealing of remaining contamination are performed. Access to contaminated areas is 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. 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:


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Isolation of the spent fuel storage services and fuel handling systems 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.

Transferring the spent fuel from the storage pools to the DOE, following the minimum required cooling period in the spent fuel pools.

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

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 including 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.

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


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maintenance, heating and ventilation of buildings, routine radiological inspections of contaminated structures, maintenance of structural integrity, and a site environmental and radiation monitoring program. Resident maintenance personnel perform equipment maintenance, inspection activities, routine services to maintain safe conditions, adequate lighting, heating, and ventilation, and periodic preventive maintenance on essential site services. An environmental surveillance program is carried out during the dormancy period to ensure that releases of radioactive material to the environment are prevented or detected and controlled. Appropriate 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 are maintained throughout the dormancy period. Fire and radiation alarms are also functional. Consistent with the DECON scenario, the spent fuel storage pools are emptied within ten years of the cessation of operations. The transfer of the spent fuel from the ISFSI to a DOE facility begins in 2058 and continues throughout the dormancy period until completed in 2066. Once emptied, the ISFSI is decommissioned along with the power block structures in Period 4. After a period of storage (such that license termination is accomplished within 60 years of final shutdown), it is required that the licensee submit an application to terminate the license, along with a LTP (described in Section 2.1.2), thereby initiating the third phase.

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 and the assembly of activity specifications and detailed work procedures are also initiated at this time.


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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 this deferred scenario is the absence, in the latter, of any constraint on the dismantling process due to the operation of the spent fuel pools in the DECON option. Radioactive decay over the length of the dormancy period will have some effect upon the quantities of radioactive wastes generated from system and structure removal operations. However, given the levels of radioactivity and spectrum of radionuclides expected from 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. 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 estimate for this delayed scenario incorporates reduced ALARA controls for the SAFSTOR's lower occupational exposure potential. Although the initial radiation levels due to 60Co will substantially 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, 59Ni, and 63Ni. Therefore, the dismantling procedures described for the DECON alternative would still be employed during this scenario. Portions of the biological shield will still be radioactive due to the presence of activated trace elements with long half-lives (152Eu and 154Eu). Decontamination will require controlled 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.


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2.2.4 Period 5 - Site Restoration Following completion of decommissioning operations, site-restoration activities begin. Dismantling, as a continuation of the decommissioning process is a cost-effective option, as described in Section 2.1.3. The basis for the dismantling cost is consistent with that described for DECON, presuming the removal of structures and site facilities to a nominal depth of three feet below grade and the limited restoration of the site.


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3. COST ESTIMATES The cost estimates prepared for decommissioning Catawba consider the unique features of the site, including the nuclear steam supply system, electric power generating systems, structures, and supporting facilities. The basis of the estimates, including the sources of information relied upon, the estimating methodology employed, site-specific considerations, and other pertinent assumptions, is described in this section. 3.1 BASIS OF ESTIMATES

The current estimates were developed using the site-specific, technical information relied upon in the decommissioning analysis prepared in 2008. This information was reviewed for the current analysis and updated as deemed appropriate. The site-specific considerations and assumptions used in the previous evaluation were also revisited. Modifications were incorporated where new information was available or experience from ongoing decommissioning programs provided viable alternatives or improved processes.

3.2 METHODOLOGY The methodology used to develop the estimates follows the basic approach originally presented in the AIF/NESP-036 study report, "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates,"[23] and the DOE "Decommissioning Handbook."[24] These documents present a unit factor method for estimating decommissioning activity costs, which simplifies the estimating calculations. Unit factors for concrete removal ($/cubic yard), steel removal ($/ton), and cutting costs ($/inch) are developed using local labor rates. The activity-dependent costs are estimated with the item quantities (cubic yards and tons), developed from plant drawings and inventory documents. Removal rates and material costs for the conventional disposition of components and structures rely upon information available in the industry publication, "Building Construction Cost Data," published by R.S. Means.[25] 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.


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This analysis reflects lessons learned from TLG’s involvement in the Shippingport Station Decommissioning Project, 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, Oyster Creek, 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 inefficiencies associated with working in confined, hazardous environments. The ranges used for the WDFs are as follows:

Access Factor 10% to 20%

Respiratory Protection Factor 10% to 50%

Radiation/ALARA Factor 10% to 37%

Protective Clothing Factor 10% to 30%

Work Break Factor 8.33% The factors and their associated range of values were developed in conjunction with the AIF/NESP-036 study. The application of the factors is discussed in more detail in that publication. Scheduling Program Durations The unit factors, adjusted by the WDFs as described above, are applied against the inventory of materials to be removed in the radiological controlled areas. The resulting labor-hours, or crew-hours, are used in the development of the decommissioning program schedule, using resource loading and event sequencing considerations. The scheduling of conventional removal and dismantling activities is based upon productivity information available from the "Building Construction Cost Data" publication. In the DECON alternative, dismantling of the fuel handing building systems and decontamination of the spent fuel pools is also dependent upon the timetable for the transfer of the spent fuel assemblies from the pool to the DOE.


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

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, spent fuel management and site restoration. 3.3.1 Contingency

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. 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”[26] 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 a contingency percentage 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.


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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% Low-Level Radioactive Waste Disposal 25% Reactor Segmentation 75% NSSS Component Removal 25% Reactor Waste Packaging 25% Reactor Waste Transport 25% Reactor Vessel Component Disposal 50%

GTCC Disposal 15% Spent Fuel Management 15% Non-Radioactive Component Removal 15% Heavy Equipment and Tooling 15% Supplies 25%

Engineering 15% Energy 15% Characterization and Termination Surveys 30% Construction 15% Taxes and Fees 10%

Insurance 10% 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). For example, the composite contingency value reported for the DECON


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alternative in Appendix C is approximately 18.3%; the corresponding SAFSTOR alternative in Appendix D is approximately 17.1%.

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 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, or the start and rate of acceptance of spent fuel by the DOE.

Pricing changes for basic inputs such as labor, energy, materials, and waste disposal.

This cost study does not add any additional costs to the estimate for financial risk, since there is insufficient historical data from which to project future liabilities. Consequently, the areas of uncertainty or risk


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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 Catawba. 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 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 requirement is prepared for 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.[27] 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 shut down 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. ISFSI An ISFSI has been constructed within the protected area to support continued plant operations. The ISFSI will be expected to operate throughout decommissioning, and beyond the conclusion of the remediation phase in the DECON decommissioning scenario, until such


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time that the transfer of spent fuel to the DOE can be completed. The scenario is similar for the SAFSTOR alternative; however, based upon the expected completion date for fuel transfer, the ISFSI will be emptied prior to the commencement of decommissioning operations. Operation and maintenance costs for the spent fuel pools and the ISFSI are included within the estimates and address the cost for staffing the facility, as well as other costs (e.g., security, insurance, and licensing fees). The estimates also include the costs to transfer the transportable storage canisters to the DOE. Costs are also provided for the final disposition of the facilities once the transfer is complete. Storage Canister Design The design and capacity of the ISFSI is based upon the NAC Magnastor dry cask storage system. The system consists of a transportable storage canister with a nominal capacity of 37 fuel assemblies and a steel lined concrete storage overpack. For fuel transferred directly from the pools to the DOE, the DOE was assumed to provide Transport, Aging and Disposal (TAD) canisters with a 21 assembly capacity at no additional cost to the owner. Canister Loading and Transfer The estimates include the cost for the materials and labor equipment to seal and load each spent fuel canister (TAD) into the DOE transport cask from the wet storage pools and an allowance to transfer each spent fuel canister from the ISFSI to the DOE. Operations and Maintenance The estimates also include the cost of operating and maintaining the spent fuel pools and the ISFSI, respectively. Pool operations are expected to continue approximately ten years after the cessation of operations. It is assumed that the ten years provides the necessary cooling period for the final core to meet DOE’s transport system requirements for decay heat and/or the dry cask storage vendor’s system. ISFSI operating costs are based upon the previously stated assumptions on fuel transfer expectations.


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ISFSI Decommissioning In accordance with 10 CFR §72.30, licensees must have a proposed decommissioning plan for the ISFSI site and facilities that includes a cost estimate to implement. The plan should contain sufficient information on the proposed practices and procedures for the decontamination of the ISFSI and for the disposal of residual radioactive materials after all spent fuel, high-level radioactive waste, and reactor-related GTCC waste have been removed.

The ISFSI storage overpacks are assumed to have some level of neutron-induced activation as a result of the long-term storage of the fuel, i.e., to levels exceeding free-release limits. As an allowance for cask remediation, 12 cask are assumed to have some level of neutron-induced activation (i.e., to levels exceeding free-release limits), equivalent to the number of casks required to accommodate the final core off loads. The ISFSI pad is not expected to be contaminated and will be demolished accordingly after a confirmation survey. The cost estimate for decommissioning the ISFSI reflects: 1) the cost of an independent contractor performing the decommissioning activities; 2) an adequate contingency factor; and 3) the cost of meeting the criteria for unrestricted use. The cost summary for decommissioning the ISFSI is presented in Appendix E.

GTCC The dismantling of the reactor internals is expected to generate 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 the DOE is responsible for disposing of GTCC waste, any costs for that service have not been determined. For purposes of this estimate, the GTCC is packaged in canisters compatible with the spent fuel dry storage system and disposed of at a cost equivalent to that envisioned for the spent fuel. It is assumed that the DOE would not accept this waste prior to completing the transfer of spent fuel. Therefore, until such time the


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DOE is ready to accept GTCC waste, it is reasonable to assume that this material would remain in storage at the Catawba site (for the DECON alternative). In the SAFSTOR scenario, 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 delayed dismantling.

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 refueling canal, 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 cavity. Transportation cask specifications and transportation regulations dictate the segmentation and packaging methodology. Intact disposal of reactor vessel shells has been successfully demonstrated at several of the sites that have been 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.


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It is not known whether this option will be available when the Catawba plant 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 that the reactor vessel will require segmentation, as a bounding condition.

3.4.3 Primary System Components

In the DECON scenario, the reactor coolant system components are assumed to be decontaminated using chemical agents prior to the start of dismantling operations. This type of decontamination can be 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. The following discussion deals with the removal and disposition of the steam generators, but the techniques involved are also applicable to other large components, such as heat exchangers, component coolers, and the pressurizer. The steam generators’ size and weight, as well as their location within the reactor building, will ultimately determine the removal strategy. A trolley crane is set up for the removal of the generators. It can also be used to move portions of the steam generator cubicle walls and floor slabs from the reactor building to a location where they can be decontaminated and transported to the material handling area. Interferences within the work area, such as grating, piping, and other components are removed to create sufficient laydown space for processing these large components. The generators are rigged for removal, disconnected from the surrounding piping and supports, and maneuvered into the open area where they are lowered onto a dolly. Each generator is rotated into the horizontal position for extraction from the containment and placed onto a multi-wheeled vehicle for transport to an on-site processing and storage area.


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Disposal costs are based upon the displaced volume and weight of the units. Each component is then loaded onto a rail car for transport to the disposal facility. Reactor coolant 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) is dropped below the nozzle zone. The piping is boxed and transported by shielded van. The reactor coolant pumps and motors are lifted out intact, packaged, and transported for processing and/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 Retired Components

The estimates include the cost to dispose of the four Unit 1 retired steam generators expected to be in storage at the site upon the cessation of plant operations. The components are processed for disposal in the same manner as described for the installed units.

3.4.6 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.[28] 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 10 CFR Part 71, in Type B containers. It is conceivable that the reactor, due to its limited specific activity, could qualify as LSA II or III. However, the high radiation levels on the outer surface would require that additional shielding be incorporated


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within the packaging so as to attenuate the dose to levels acceptable for transport. 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., 137Cs, 90Sr, 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 to the Barnwell disposal facility. Truck transport costs were developed from published tariffs from Tri-State Motor Transit.[29] based upon the mileage to the Barnwell facility and/or the EnergySolutions facility in Clive, Utah. Transportation costs for off-site waste processing are based upon the mileage to Oak Ridge, Tennessee. The disposal cost for the GTCC material is assumed to be inclusive of the transportation cost.

3.4.7 Low-Level Radioactive Waste 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


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the detailed Appendices C and D, and summarized in Section 5. The quantified waste summaries shown in these tables are consistent with 10 CFR Part 61 classifications. Commercially available steel containers are presumed to be used for the disposal of piping, small components, and concrete. Larger 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. 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 lowest level and majority of the material generated from the decontamination and dismantling activities is based upon the current cost for disposal at EnergySolutions facility in Clive, Utah. Disposal costs for the higher activity waste (Class B and C) are based upon the rate schedule for the Barnwell facility. Material exceeding Class C limits (limited to material closest to the reactor core and comprising less than 1% of the total waste volume) is generally not suitable for shallow-land disposal. This material is packaged in the same multi-purpose canisters used for spent fuel storage/transport.

3.4.8 Site Conditions Following Decommissioning

The NRC will amend or terminate the site license if it determines that site remediation has been performed in accordance with the license termination plan, and that the terminal radiation survey and associated documentation demonstrate that the facility is suitable for release. The NRC’s involvement in the decommissioning process will end at this point. Building codes and environmental regulations will dictate the next step in the decommissioning process, as well as owner’s own future plans for the site. All structures will be removed except for the switchyard. The switchyard is required for grid operations. Structures to be removed include but are


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not limited to the reactor buildings, auxiliary buildings, service building, turbine buildings, intake and discharge structures, ponds, dams, and dikes. The landfill and firing range will be remediated and closed. The structures that may require decontamination or radiological remediation are the reactor buildings, auxiliary buildings, containment mechanical equipment building, fuel buildings, retired steam generator storage facility, monitor tank building, contaminated material storage warehouse and the asphalt pad under the RP storage tent. The estimates presented herein include the dismantling of the major structures to a nominal depth of three feet below grade, backfilling and the collapsing of below grade voids, and general terra-forming such that the site upon which the power block and supplemental structures are located is transformed into a “grassy plain.” The estimates do not assume the remediation of any significant volume of 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. Costs are included for the remediation of the landfill and firing range at the site. The post-closure care and maintenance program of the landfill is maintained for a twenty year period. Environmental Remediation For purposes of this estimate, the sanitary and chemical treatment ponds are not projected to require remediation. The first sanitary pond has a synthetic liner and will not require remediation. The tertiary pond is not lined, but the liquid is releasable; therefore, no remediation will be required. As for the chemical treatment ponds, the initial hold-up pond is concrete and should not require remediation. The conventional waste basins are earthen and unlined. Current groundwater monitoring around these basins has not indicated any problems; therefore, no remediation cost has been included. The final hold-up pond has a synthetic liner and should not require remediation. All ponds will be backfilled to grade level.

3.5 ASSUMPTIONS The following are the major assumptions made in the development of the estimates for decommissioning the site.


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3.5.1 Estimating Basis Decommissioning costs are reported in the year of projected expenditure; however, the values are provided in 2013 dollars. Costs are not inflated, escalated, or discounted over the periods of performance. The estimates rely upon the physical plant inventory that was the basis for the 2008 analysis (updated to reflect any significant changes to the plant over the past five years). 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

For purposes of this analysis, Duke Energy will continue to provide site operations support, including decommissioning program management, licensing, radiological protection, and site security. Duke Energy will serve as the Decommissioning Operations Contractor, providing the supervisory staff needed to oversee the labor subcontractors, consultants, and specialty contractors needed to perform the work envisioned in the decontamination and dismantling effort. Duke Energy will also provide the engineering services needed to develop activity specifications, detailed procedures, detailed activation analyses, and support field activities such as structural modifications. Severance and retention costs are not included in the estimate. Reduction in staff levels will be handled through normal staffing processes. Personnel costs are based upon average salary information provided by Duke Energy. Overhead costs are included for site and corporate support, reduced commensurate with the staffing of the project. The craft labor required to decontaminate and dismantle the nuclear plant is acquired through standard site contracting practices. The current cost of labor at the site is used as an estimating basis.


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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., 137Cs, 90Sr, 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.[30] Actual estimates are derived from the curie/gram values contained therein and adjusted for the different mass of the Catawba components, projected operating life, and different periods of decay. Additional short-lived isotopes were derived from NUREG/CR-0130[31] and NUREG/CR-0672,[32] and benchmarked to the long-lived values from NUREG/CR-3474. Neutron activation of the containment building structure is assumed to be confined to the biological shield.

3.5.4 General

Transition Activities Existing warehouses are cleared of non-essential material and remain for use by Duke Energy 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. Disposal of operating wastes (e.g., filtration media, resins) during this initial period is not considered a decommissioning expense.


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Scrap and Salvage

The existing plant equipment is considered obsolete and suitable for scrap as deadweight quantities only. Duke Energy 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 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.


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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.”[33] The NRC’s financial protection requirements are based on various reactor (and spent fuel) configurations. Taxes

Property tax payments continue throughout the decommissioning process, although at a substantially reduced level. The rate of decrease in disbursements is consistent over the same time interval for both the DECON and SAFSTOR alternatives. The value of plant structures and equipment decreases from 100% to 0% over an eight-year period. The property taxes are determined based on a 100% value of the plant structures and equipment for the first two years, 66.7% of the value for the next three years, 33.3% of the value for the next three years, and 0% for the remainder of the decommissioning period.

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.

Integrated earthworks created during the initial formation of the Lake Wylie area and integral with it will be left intact and maintained in accordance with the current dam maintenance and inspection program. The on-site dike and earthwork network forming water retention ponds and lagoons will be disabled to relieve ongoing inspection requirements.

3.6 COST ESTIMATE SUMMARY

Schedules of expenditures are provided in Tables 3.2 through 3.5. The tables delineate the cost contributors by year of expenditures as well as cost contributor (e.g., labor, materials, and waste disposal).


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The tables in Appendices C and D provide additional detail. The cost elements in these tables are 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 plant’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 from the wet storage pools to the DOE, as well as the eventual transfer of the spent fuel in storage at the ISFSI to the DOE. Costs are also included for the operations of the pools and management of the ISFSI until such time that the transfer of all fuel from this facility to an off-site location (e.g., interim storage facility) 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. As discussed in Section 3.4.1, it is assumed that the DOE will not accept the GTCC waste prior to completing the transfer of spent fuel. Therefore, the cost of GTCC disposal is shown in the final year of ISFSI operation (for the DECON alternative). While designated for disposal at a federal facility along with the spent fuel, GTCC waste is still classified as low-level radioactive waste and, as such, included as a “License Termination” expense. Decommissioning costs are reported in 2013 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.


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TABLE 3.1 SPENT FUEL MANAGEMENT SCHEDULE

(Fuel Assembly Totals by Location) DOE Year Pools ISFSI Acceptance

2025 2212 1834 0 2026 2210 1908 0 2027 2243 2019 0 2028 2243 2019 72 2029 2243 2019 72 2030 2243 2019 144 2031 2243 2019 72 2032 2243 2019 72 2033 2243 2019 144 2034 2243 2019 72 2035 2243 2019 72 2036 2243 2019 144 2037 2243 2019 72 2038 2243 2019 72 2039 2243 2019 144 2040 2243 2019 72 2041 2243 2019 72 2042 2243 2019 144 2043 2518 2019 111 2044 2307 2019 211 2045 2051 2019 256 2046 1795 2019 256 2047 1539 2019 256 2048 1283 2019 256 2049 1027 2019 256 2050 771 2019 256 2051 515 2019 256 2052 259 2019 256 2053 0 2019 259 2054 2019 0 2055 2019 0 2056 2019 0


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TABLE 3.1 (continued) SPENT FUEL MANAGEMENT SCHEDULE

(Fuel Assembly Totals by Location) DOE Year Pools ISFSI Acceptance

2057 2019 0 2058 1801 218 2059 1580 221 2060 1359 221 2061 1138 221 2062 917 221 2063 696 221 2064 475 221 2065 252 223 2066 0 252

Total 6,088


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TABLE 3.2 DECON ALTERNATIVE, UNIT 1

TOTAL ANNUAL EXPENDITURES (thousands, 2013 dollars)

Equipment & Year Labor Materials Energy Burial Other Total

2043 3,001 209 62 3 1,142 4,418 2044 41,246 3,904 912 161 17,269 63,492 2045 47,958 21,744 1,177 17,542 26,289 114,710 2046 47,987 25,406 803 29,129 17,199 120,524 2047 39,579 10,533 651 14,510 12,733 78,006 2048 38,707 8,828 635 12,847 12,247 73,265 2049 20,444 4,765 366 5,455 7,434 38,465 2050 7,042 1,784 169 24 3,906 12,926 2051 7,042 1,784 169 24 3,906 12,926 2052 7,062 1,789 169 24 3,917 12,962 2053 7,105 1,800 169 53 3,915 13,042 2054 27,903 3,820 230 3,777 4,377 40,108 2055 14,492 7,396 94 3 2,010 23,995 2056 9,901 6,330 65 0 1,445 17,740 2057 153 460 0 0 0 613 2058 153 460 0 0 0 613 2059 153 460 0 0 0 613 2060 154 461 0 0 0 615 2061 153 460 0 0 0 613 2062 153 460 0 0 0 613 2063 153 460 0 0 0 613 2064 154 461 0 0 0 615 2065 153 460 0 0 0 613 2066 147 1,403 0 0 16,453 18,003

Total 320,997 105,636 5,672 83,553 134,243 650,100


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TABLE 3.2a DECON ALTERNATIVE, UNIT 1

LICENSE TERMINATION EXPENDITURES (thousands, 2013 dollars)


2043 2,956 136 62 3 996 4,153 2044 40,589 2,885 912 161 15,289 59,837 2045 46,664 20,432 1,177 17,542 24,243 110,058 2046 46,619 24,057 803 29,129 15,101 115,708 2047 37,722 9,181 651 14,510 11,106 73,170 2048 36,788 7,473 635 12,847 10,671 68,414 2049 19,374 3,420 366 5,455 5,862 34,477 2050 6,595 443 169 24 2,334 9,566 2051 6,595 443 169 24 2,334 9,566 2052 6,613 444 169 24 2,341 9,592 2053 6,660 463 169 53 2,345 9,690 2054 27,903 3,820 230 3,777 3,705 39,436 2055 3,124 195 19 3 260 3,601 2056 45 0 0 0 0 45 2057 0 0 0 0 0 0 2058 0 0 0 0 0 0 2059 0 0 0 0 0 0 2060 0 0 0 0 0 0 2061 0 0 0 0 0 0 2062 0 0 0 0 0 0 2063 0 0 0 0 0 0 2064 0 0 0 0 0 0 2065 0 0 0 0 0 0 2066 0 963 0 0 16,453 17,415

Total 288,247 74,355 5,533 83,553 113,041 564,728


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TABLE 3.2b DECON ALTERNATIVE, UNIT 1

SPENT FUEL MANAGEMENT EXPENDITURES (thousands, 2013 dollars)


2043 25 74 0 0 146 244 2044 340 1,019 0 0 1,980 3,338 2045 427 1,280 0 0 1,742 3,448 2046 431 1,294 0 0 1,572 3,297 2047 431 1,292 0 0 1,572 3,295 2048 432 1,296 0 0 1,576 3,304 2049 440 1,320 0 0 1,572 3,332 2050 447 1,341 0 0 1,572 3,360 2051 447 1,341 0 0 1,572 3,360 2052 448 1,345 0 0 1,576 3,369 2053 446 1,337 0 0 1,570 3,353 2054 0 0 0 0 672 672 2055 1,788 0 0 0 1,203 2,991 2056 1,581 110 0 0 972 2,663 2057 153 460 0 0 0 613 2058 153 460 0 0 0 613 2059 153 460 0 0 0 613 2060 154 461 0 0 0 615 2061 153 460 0 0 0 613 2062 153 460 0 0 0 613 2063 153 460 0 0 0 613 2064 154 461 0 0 0 615 2065 153 460 0 0 0 613 2066 147 441 0 0 0 588

Total 9,209 17,627 0 0 19,297 46,133


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TABLE 3.2c DECON ALTERNATIVE, UNIT 1

SITE RESTORATION EXPENDITURES (thousands, 2013 dollars)


2043 21 0 0 0 0 21 2044 317 0 0 0 0 317 2045 868 32 0 0 304 1,204 2046 937 56 0 0 526 1,519 2047 1,426 59 0 0 55 1,540 2048 1,487 60 0 0 0 1,547 2049 630 25 0 0 0 655 2050 0 0 0 0 0 0 2051 0 0 0 0 0 0 2052 0 0 0 0 0 0 2053 0 0 0 0 0 0 2054 0 0 0 0 0 0 2055 9,580 7,201 75 0 547 17,403 2056 8,275 6,220 65 0 473 15,032 2057 0 0 0 0 0 0 2058 0 0 0 0 0 0 2059 0 0 0 0 0 0 2060 0 0 0 0 0 0 2061 0 0 0 0 0 0 2062 0 0 0 0 0 0 2063 0 0 0 0 0 0 2064 0 0 0 0 0 0 2065 0 0 0 0 0 0 2066 0 0 0 0 0 0

Total 23,541 13,653 139 0 1,904 39,238


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TABLE 3.3 DECON ALTERNATIVE, UNIT 2

TOTAL ANNUAL EXPENDITURES (thousands, 2013 dollars)


2043 3,001 209 62 3 1,124 4,400 2044 41,106 3,725 912 161 16,411 62,316 2045 47,395 21,143 1,177 13,518 22,295 105,528 2046 48,339 26,069 803 22,167 16,298 113,675 2047 42,318 14,659 651 16,023 13,637 87,288 2048 41,733 13,369 635 15,351 13,365 84,453 2049 21,725 6,688 366 6,515 7,993 43,288 2050 7,042 1,784 169 24 4,056 13,075 2051 7,042 1,784 169 24 4,056 13,075 2052 7,062 1,789 169 24 4,067 13,111 2053 7,106 1,805 169 53 4,064 13,197 2054 29,117 4,553 230 3,795 4,349 42,044 2055 18,480 18,101 94 3 2,414 39,092 2056 14,006 15,566 65 0 2,430 32,067 2057 3,652 460 0 0 2,650 6,761 2058 3,652 460 0 0 2,650 6,761 2059 3,652 460 0 0 2,650 6,761 2060 3,662 461 0 0 2,657 6,779 2061 3,652 460 0 0 2,650 6,761 2062 3,652 460 0 0 2,650 6,761 2063 3,652 460 0 0 2,650 6,761 2064 3,662 461 0 0 2,657 6,779 2065 3,652 460 0 0 2,650 6,761 2066 3,652 1,418 0 25 19,094 24,190 2067 3,006 2,254 45 3,023 778 9,105

Total 375,016 139,057 5,718 80,710 160,293 760,793


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TABLE 3.3a DECON ALTERNATIVE, UNIT 2



2043 2,956 136 62 3 968 4,125 2044 40,450 2,707 912 161 14,303 58,533 2045 45,949 19,821 1,177 13,518 20,121 100,586 2046 46,707 24,702 803 22,167 14,072 108,451 2047 39,478 11,318 651 16,023 10,978 78,449 2048 38,744 9,790 635 15,351 10,648 75,168 2049 20,203 4,401 366 6,515 5,838 37,323 2050 6,595 443 169 24 2,309 9,541 2051 6,595 443 169 24 2,309 9,541 2052 6,613 444 169 24 2,315 9,567 2053 6,660 468 169 53 2,319 9,670 2054 29,117 4,553 230 3,795 3,503 41,198 2055 3,324 207 19 3 235 3,788 2056 45 0 0 0 0 45 2057 0 0 0 0 0 0 2058 0 0 0 0 0 0 2059 0 0 0 0 0 0 2060 0 0 0 0 0 0 2061 0 0 0 0 0 0 2062 0 0 0 0 0 0 2063 0 0 0 0 0 0 2064 0 0 0 0 0 0 2065 0 0 0 0 0 0 2066 17 977 0 25 16,458 17,477 2067 2,043 1,800 31 3,023 651 7,548

Total 295,497 82,210 5,564 80,710 107,030 571,010


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TABLE 3.3b DECON ALTERNATIVE, UNIT 2



2043 25 74 0 0 156 254 2044 340 1,019 0 0 2,108 3,466 2045 427 1,280 0 0 1,870 3,576 2046 431 1,294 0 0 1,700 3,425 2047 431 1,292 0 0 1,700 3,423 2048 432 1,296 0 0 1,705 3,432 2049 440 1,320 0 0 1,700 3,461 2050 447 1,341 0 0 1,700 3,488 2051 447 1,341 0 0 1,700 3,488 2052 448 1,345 0 0 1,705 3,498 2053 446 1,337 0 0 1,698 3,481 2054 0 0 0 0 800 800 2055 1,788 0 0 0 1,584 3,372 2056 2,415 110 0 0 1,909 4,434 2057 3,652 460 0 0 2,603 6,715 2058 3,652 460 0 0 2,603 6,715 2059 3,652 460 0 0 2,603 6,715 2060 3,662 461 0 0 2,610 6,733 2061 3,652 460 0 0 2,603 6,715 2062 3,652 460 0 0 2,603 6,715 2063 3,652 460 0 0 2,603 6,715 2064 3,662 461 0 0 2,610 6,733 2065 3,652 460 0 0 2,603 6,715 2066 3,636 441 0 0 2,592 6,668 2067 0 0 0 0 0 0

Total 45,036 17,627 0 0 48,073 110,736


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TABLE 3.3c DECON ALTERNATIVE, UNIT 2



2043 21 0 0 0 0 21 2044 317 0 0 0 0 317 2045 1,020 43 0 0 304 1,366 2046 1,200 74 0 0 526 1,799 2047 2,409 2,048 0 0 959 5,416 2048 2,557 2,284 0 0 1,012 5,852 2049 1,083 967 0 0 455 2,505 2050 0 0 0 0 46 46 2051 0 0 0 0 46 46 2052 0 0 0 0 46 46 2053 0 0 0 0 46 46 2054 0 0 0 0 46 46 2055 13,368 17,894 75 0 595 31,932 2056 11,547 15,456 65 0 521 27,588 2057 0 0 0 0 46 46 2058 0 0 0 0 46 46 2059 0 0 0 0 46 46 2060 0 0 0 0 46 46 2061 0 0 0 0 46 46 2062 0 0 0 0 46 46 2063 0 0 0 0 46 46 2064 0 0 0 0 46 46 2065 0 0 0 0 46 46 2066 0 0 0 0 44 44 2067 963 454 14 0 127 1,557

Total 34,484 39,220 153 0 5,190 79,047


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TABLE 3.4 SAFSTOR ALTERNATIVE, UNIT 1 TOTAL ANNUAL EXPENDITURES

(thousands, 2013 dollars) Equipment & Year Labor Materials Energy Burial Other Total

2043 2,467 173 62 3 1,143 3,849 2044 34,220 3,240 847 158 19,105 57,570 2045 20,543 4,939 458 876 17,729 44,545 2046 7,070 1,738 169 13 5,585 14,576 2047 7,070 1,738 169 13 5,585 14,576 2048 7,090 1,743 169 13 5,600 14,615 2049 7,070 1,738 169 13 5,585 14,576 2050 7,070 1,738 169 13 5,585 14,576 2051 7,070 1,738 169 13 5,585 14,576 2052 7,090 1,743 169 13 5,600 14,615 2053 7,059 1,735 169 13 5,574 14,550 2054 2,783 659 84 6 1,778 5,311 2055 2,783 659 84 6 1,778 5,311 2056 2,791 660 85 6 1,783 5,326 2057 2,783 659 84 6 1,778 5,311 2058 2,783 659 84 6 1,778 5,311 2059 2,783 659 84 6 1,778 5,311 2060 2,791 660 85 6 1,783 5,326 2061 2,783 659 84 6 1,778 5,311 2062 2,783 659 84 6 1,778 5,311 2063 2,783 659 84 6 1,778 5,311 2064 2,791 660 85 6 1,783 5,326 2065 2,783 659 84 6 1,778 5,311 2066 2,780 658 84 6 1,776 5,305 2067 1,556 294 84 6 998 2,939 2068 1,560 295 85 6 1,001 2,947 2069 1,556 294 84 6 998 2,939 2070 1,556 294 84 6 998 2,939 2071 1,556 294 84 6 998 2,939 2072 1,560 295 85 6 1,001 2,947 2073 1,556 294 84 6 998 2,939 2074 1,556 294 84 6 998 2,939


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TABLE 3.4 (continued) SAFSTOR ALTERNATIVE, UNIT 1 TOTAL ANNUAL EXPENDITURES


2075 1,556 294 84 6 998 2,939 2076 1,560 295 85 6 1,001 2,947 2077 1,556 294 84 6 998 2,939 2078 1,556 294 84 6 998 2,939 2079 1,556 294 84 6 998 2,939 2080 1,560 295 85 6 1,001 2,947 2081 1,556 294 84 6 998 2,939 2082 1,556 294 84 6 998 2,939 2083 1,556 294 84 6 998 2,939 2084 1,560 295 85 6 1,001 2,947 2085 1,556 294 84 6 998 2,939 2086 1,556 294 84 6 998 2,939 2087 1,556 294 84 6 998 2,939 2088 1,560 295 85 6 1,001 2,947 2089 1,556 294 84 6 998 2,939 2090 1,556 294 84 6 998 2,939 2091 1,556 294 84 6 998 2,939 2092 1,560 295 85 6 1,001 2,947 2093 1,556 294 84 6 998 2,939 2094 1,556 294 84 6 998 2,939 2095 1,556 294 84 6 998 2,939 2096 1,560 295 85 6 1,001 2,947 2097 1,556 294 84 6 998 2,939 2098 25,558 3,490 780 28 2,590 32,448 2099 34,820 13,382 828 13,574 11,348 73,952 2100 41,618 22,839 779 31,792 20,829 117,857 2101 41,157 10,099 634 21,490 6,735 80,115 2102 6,804 1,667 242 3,361 1,363 13,437 2103 20,005 1,872 163 21 1,344 23,405 2104 11,439 8,160 85 0 590 20,273 2105 6,563 4,682 49 0 339 11,632

Total 386,242 106,151 9,999 71,677 181,918 755,987


TLG Services, Inc.

TABLE 3.4a SAFSTOR ALTERNATIVE, UNIT 1



2043 2,443 100 62 3 997 3,605 2044 33,882 2,224 847 158 17,125 54,235 2045 17,205 3,643 409 876 14,281 36,415 2046 1,556 420 84 13 1,037 3,111 2047 1,556 420 84 13 1,037 3,111 2048 1,560 421 85 13 1,040 3,119 2049 1,556 420 84 13 1,037 3,111 2050 1,556 420 84 13 1,037 3,111 2051 1,556 420 84 13 1,037 3,111 2052 1,560 421 85 13 1,040 3,119 2053 1,556 420 84 13 1,037 3,110 2054 1,556 298 84 6 1,022 2,967 2055 1,556 298 84 6 1,022 2,967 2056 1,560 299 85 6 1,025 2,975 2057 1,556 298 84 6 1,022 2,967 2058 1,556 298 84 6 1,022 2,967 2059 1,556 298 84 6 1,022 2,967 2060 1,560 299 85 6 1,025 2,975 2061 1,556 298 84 6 1,022 2,967 2062 1,556 298 84 6 1,022 2,967 2063 1,556 298 84 6 1,022 2,967 2064 1,560 299 85 6 1,025 2,975 2065 1,556 298 84 6 1,022 2,967 2066 1,556 298 84 6 1,022 2,966 2067 1,556 294 84 6 998 2,939 2068 1,560 295 85 6 1,001 2,947 2069 1,556 294 84 6 998 2,939 2070 1,556 294 84 6 998 2,939 2071 1,556 294 84 6 998 2,939 2072 1,560 295 85 6 1,001 2,947 2073 1,556 294 84 6 998 2,939 2074 1,556 294 84 6 998 2,939


TLG Services, Inc.

TABLE 3.4a (continued) SAFSTOR ALTERNATIVE, UNIT 1



2075 1,556 294 84 6 998 2,939 2076 1,560 295 85 6 1,001 2,947 2077 1,556 294 84 6 998 2,939 2078 1,556 294 84 6 998 2,939 2079 1,556 294 84 6 998 2,939 2080 1,560 295 85 6 1,001 2,947 2081 1,556 294 84 6 998 2,939 2082 1,556 294 84 6 998 2,939 2083 1,556 294 84 6 998 2,939 2084 1,560 295 85 6 1,001 2,947 2085 1,556 294 84 6 998 2,939 2086 1,556 294 84 6 998 2,939 2087 1,556 294 84 6 998 2,939 2088 1,560 295 85 6 1,001 2,947 2089 1,556 294 84 6 998 2,939 2090 1,556 294 84 6 998 2,939 2091 1,556 294 84 6 998 2,939 2092 1,560 295 85 6 1,001 2,947 2093 1,556 294 84 6 998 2,939 2094 1,556 294 84 6 998 2,939 2095 1,556 294 84 6 998 2,939 2096 1,560 295 85 6 1,001 2,947 2097 1,556 294 84 6 998 2,939 2098 25,290 3,490 780 28 2,590 32,179 2099 33,784 13,354 828 13,574 11,347 72,887 2100 40,180 22,763 779 31,792 20,827 116,342 2101 38,492 9,992 634 21,490 6,735 77,343 2102 6,388 1,651 242 3,361 1,363 13,004 2103 19,198 1,292 157 21 1,302 21,970 2104 77 0 0 0 0 77 2105 44 0 0 0 0 44

Total 297,929 74,875 9,135 71,677 129,142 582,758


TLG Services, Inc.

TABLE 3.4b SAFSTOR ALTERNATIVE, UNIT 1



2043 25 74 0 0 146 244 2044 339 1,016 0 0 1,980 3,335 2045 3,338 1,296 48 0 3,448 8,130 2046 5,515 1,318 84 0 4,548 11,465 2047 5,515 1,318 84 0 4,548 11,465 2048 5,530 1,322 85 0 4,560 11,496 2049 5,515 1,318 84 0 4,548 11,465 2050 5,515 1,318 84 0 4,548 11,465 2051 5,515 1,318 84 0 4,548 11,465 2052 5,530 1,322 85 0 4,560 11,496 2053 5,503 1,315 84 0 4,537 11,440 2054 1,228 361 0 0 756 2,345 2055 1,228 361 0 0 756 2,345 2056 1,231 362 0 0 758 2,351 2057 1,228 361 0 0 756 2,345 2058 1,228 361 0 0 756 2,345 2059 1,228 361 0 0 756 2,345 2060 1,231 362 0 0 758 2,351 2061 1,228 361 0 0 756 2,345 2062 1,228 361 0 0 756 2,345 2063 1,228 361 0 0 756 2,345 2064 1,231 362 0 0 758 2,351 2065 1,228 361 0 0 756 2,345 2066 1,224 360 0 0 754 2,338

2067-2105 0 0 0 0 0 0

Total 63,803 17,627 724 0 51,802 133,957


TLG Services, Inc.

TABLE 3.4c SAFSTOR ALTERNATIVE, UNIT 1


Equipment & Year Labor Materials Energy Burial Other Total 2043-97 0 0 0 0 0 0

2098 269 0 0 0 0 269 2099 1,035 28 0 0 1 1,065 2100 1,438 75 0 0 2 1,515 2101 2,665 107 0 0 0 2,772 2102 416 17 0 0 0 433 2103 807 580 6 0 42 1,435 2104 11,362 8,160 85 0 590 20,196 2105 6,519 4,682 49 0 339 11,588

Total 24,511 13,648 139 0 974 39,272


TLG Services, Inc.

TABLE 3.5 SAFSTOR ALTERNATIVE, UNIT 2 TOTAL ANNUAL EXPENDITURES


2043 2,467 173 62 3 1,222 3,928 2044 34,238 3,285 847 166 18,863 57,399 2045 20,615 5,054 458 895 14,984 42,006 2046 7,127 1,757 169 13 5,745 14,812 2047 7,127 1,757 169 13 5,745 14,812 2048 7,146 1,762 169 13 5,761 14,852 2049 7,127 1,757 169 13 5,745 14,812 2050 7,127 1,757 169 13 5,745 14,812 2051 7,127 1,757 169 13 5,745 14,812 2052 7,146 1,762 169 13 5,761 14,852 2053 7,115 1,754 169 13 5,735 14,786 2054 2,840 678 84 6 1,932 5,540 2055 2,840 678 84 6 1,932 5,540 2056 2,848 679 85 6 1,937 5,555 2057 2,840 678 84 6 1,932 5,540 2058 2,840 678 84 6 1,932 5,540 2059 2,840 678 84 6 1,932 5,540 2060 2,848 679 85 6 1,937 5,555 2061 2,840 678 84 6 1,932 5,540 2062 2,840 678 84 6 1,932 5,540 2063 2,840 678 84 6 1,932 5,540 2064 2,848 679 85 6 1,937 5,555 2065 2,840 678 84 6 1,932 5,540 2066 2,837 677 84 6 1,929 5,533 2067 1,612 313 84 6 1,002 3,018 2068 1,617 314 85 6 1,004 3,026 2069 1,612 313 84 6 1,002 3,018 2070 1,612 313 84 6 1,002 3,018 2071 1,612 313 84 6 1,002 3,018 2072 1,617 314 85 6 1,004 3,026 2073 1,612 313 84 6 1,002 3,018 2074 1,612 313 84 6 1,002 3,018


TLG Services, Inc.

TABLE 3.5 (continued) SAFSTOR ALTERNATIVE, UNIT 2 TOTAL ANNUAL EXPENDITURES


2075 1,612 313 84 6 1,002 3,018 2076 1,617 314 85 6 1,004 3,026 2077 1,612 313 84 6 1,002 3,018 2078 1,612 313 84 6 1,002 3,018 2079 1,612 313 84 6 1,002 3,018 2080 1,617 314 85 6 1,004 3,026 2081 1,612 313 84 6 1,002 3,018 2082 1,612 313 84 6 1,002 3,018 2083 1,612 313 84 6 1,002 3,018 2084 1,617 314 85 6 1,004 3,026 2085 1,612 313 84 6 1,002 3,018 2086 1,612 313 84 6 1,002 3,018 2087 1,612 313 84 6 1,002 3,018 2088 1,617 314 85 6 1,004 3,026 2089 1,612 313 84 6 1,002 3,018 2090 1,612 313 84 6 1,002 3,018 2091 1,612 313 84 6 1,002 3,018 2092 1,617 314 85 6 1,004 3,026 2093 1,612 313 84 6 1,002 3,018 2094 1,612 313 84 6 1,002 3,018 2095 1,612 313 84 6 1,002 3,018 2096 1,617 314 85 6 1,004 3,026 2097 1,612 313 84 6 1,002 3,018 2098 1,612 313 84 6 1,002 3,018 2099 24,181 2,378 764 28 2,508 29,859 2100 34,602 13,161 829 9,314 10,387 68,293 2101 42,794 25,197 783 24,701 20,164 113,638 2102 47,458 20,601 634 28,225 7,904 104,821 2103 29,895 6,423 244 4,969 2,504 44,035 2104 16,175 20,471 85 0 630 37,360 2105 9,281 11,745 49 0 361 21,436

Total 407,312 141,389 9,911 68,682 182,714 810,007


TLG Services, Inc.

TABLE 3.5a SAFSTOR ALTERNATIVE, UNIT 2



2043 2,443 100 62 3 970 3,577 2044 33,899 2,269 847 166 15,533 52,714 2045 17,277 3,758 409 895 11,362 33,701 2046 1,612 439 84 13 1,023 3,172 2047 1,612 439 84 13 1,023 3,172 2048 1,617 440 85 13 1,026 3,181 2049 1,612 439 84 13 1,023 3,172 2050 1,612 439 84 13 1,023 3,172 2051 1,612 439 84 13 1,023 3,172 2052 1,617 440 85 13 1,026 3,181 2053 1,612 439 84 13 1,023 3,172 2054 1,612 317 84 6 1,012 3,032 2055 1,612 317 84 6 1,012 3,032 2056 1,617 318 85 6 1,015 3,040 2057 1,612 317 84 6 1,012 3,032 2058 1,612 317 84 6 1,012 3,032 2059 1,612 317 84 6 1,012 3,032 2060 1,617 318 85 6 1,015 3,040 2061 1,612 317 84 6 1,012 3,032 2062 1,612 317 84 6 1,012 3,032 2063 1,612 317 84 6 1,012 3,032 2064 1,617 318 85 6 1,015 3,040 2065 1,612 317 84 6 1,012 3,032 2066 1,612 317 84 6 1,012 3,032 2067 1,612 313 84 6 1,002 3,018 2068 1,617 314 85 6 1,004 3,026 2069 1,612 313 84 6 1,002 3,018 2070 1,612 313 84 6 1,002 3,018 2071 1,612 313 84 6 1,002 3,018 2072 1,617 314 85 6 1,004 3,026 2073 1,612 313 84 6 1,002 3,018 2074 1,612 313 84 6 1,002 3,018


TLG Services, Inc.

TABLE 3.5a (continued) SAFSTOR ALTERNATIVE, UNIT 2



2075 1,612 313 84 6 1,002 3,018 2076 1,617 314 85 6 1,004 3,026 2077 1,612 313 84 6 1,002 3,018 2078 1,612 313 84 6 1,002 3,018 2079 1,612 313 84 6 1,002 3,018 2080 1,617 314 85 6 1,004 3,026 2081 1,612 313 84 6 1,002 3,018 2082 1,612 313 84 6 1,002 3,018 2083 1,612 313 84 6 1,002 3,018 2084 1,617 314 85 6 1,004 3,026 2085 1,612 313 84 6 1,002 3,018 2086 1,612 313 84 6 1,002 3,018 2087 1,612 313 84 6 1,002 3,018 2088 1,617 314 85 6 1,004 3,026 2089 1,612 313 84 6 1,002 3,018 2090 1,612 313 84 6 1,002 3,018 2091 1,612 313 84 6 1,002 3,018 2092 1,617 314 85 6 1,004 3,026 2093 1,612 313 84 6 1,002 3,018 2094 1,612 313 84 6 1,002 3,018 2095 1,612 313 84 6 1,002 3,018 2096 1,617 314 85 6 1,004 3,026 2097 1,612 313 84 6 1,002 3,018 2098 1,612 313 84 6 1,002 3,018 2099 23,919 2,378 764 28 2,508 29,597 2100 33,453 13,125 829 9,314 10,386 67,106 2101 40,847 24,632 783 24,701 20,074 111,037 2102 42,877 16,508 634 28,225 7,161 95,405 2103 27,948 4,251 238 4,969 2,329 39,736 2104 77 0 0 0 0 77 2105 44 0 0 0 0 44

Total 308,287 84,681 9,047 68,682 123,756 594,452


TLG Services, Inc.

TABLE 3.5b SAFSTOR ALTERNATIVE, UNIT 2



2043 25 74 0 0 156 254 2044 339 1,016 0 0 2,108 3,463 2045 3,338 1,296 48 0 3,576 8,258 2046 5,515 1,318 84 0 4,676 11,593 2047 5,515 1,318 84 0 4,676 11,593 2048 5,530 1,322 85 0 4,689 11,625 2049 5,515 1,318 84 0 4,676 11,593 2050 5,515 1,318 84 0 4,676 11,593 2051 5,515 1,318 84 0 4,676 11,593 2052 5,530 1,322 85 0 4,689 11,625 2053 5,503 1,315 84 0 4,666 11,568 2054 1,228 361 0 0 884 2,473 2055 1,228 361 0 0 884 2,473 2056 1,231 362 0 0 887 2,480 2057 1,228 361 0 0 884 2,473 2058 1,228 361 0 0 884 2,473 2059 1,228 361 0 0 884 2,473 2060 1,231 362 0 0 887 2,480 2061 1,228 361 0 0 884 2,473 2062 1,228 361 0 0 884 2,473 2063 1,228 361 0 0 884 2,473 2064 1,231 362 0 0 887 2,480 2065 1,228 361 0 0 884 2,473 2066 1,224 360 0 0 882 2,466

2067-2105 0 0 0 0 0 0

Total 63,803 17,627 724 0 54,762 136,917


TLG Services, Inc.

TABLE 3.5c SAFSTOR ALTERNATIVE, UNIT 2



2043 0 0 0 0 97 97 2044 0 0 0 0 1,222 1,222 2045 0 0 0 0 46 46 2046 0 0 0 0 46 46 2047 0 0 0 0 46 46 2048 0 0 0 0 46 46 2049 0 0 0 0 46 46 2050 0 0 0 0 46 46 2051 0 0 0 0 46 46 2052 0 0 0 0 46 46 2053 0 0 0 0 46 46 2054 0 0 0 0 35 35 2055 0 0 0 0 35 35 2056 0 0 0 0 35 35 2057 0 0 0 0 35 35 2058 0 0 0 0 35 35 2059 0 0 0 0 35 35 2060 0 0 0 0 35 35 2061 0 0 0 0 35 35 2062 0 0 0 0 35 35 2063 0 0 0 0 35 35 2064 0 0 0 0 35 35 2065 0 0 0 0 35 35 2066 0 0 0 0 35 35

2067-98 0 0 0 0 0 0 2099 262 0 0 0 0 262 2100 1,150 36 0 0 1 1,187 2101 1,947 565 0 0 90 2,601 2102 4,581 4,092 0 0 743 9,416 2103 1,947 2,172 6 0 175 4,300 2104 16,099 20,471 85 0 630 37,283 2105 9,237 11,745 49 0 361 21,392

Total 35,222 39,081 139 0 4,196 78,638


TLG Services, Inc.

4. SCHEDULE ESTIMATE The schedules for the decommissioning scenarios considered in this analysis follow the sequences 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 described in Section 3.4.1. A schedule or sequence of activities for the DECON alternative is presented in Figure 4.1. The scheduling sequence is based on the fuel being removed from the spent fuel pools within ten years. The key activities listed in the schedule do not reflect a one-to-one correspondence with those activities in the cost tables, but reflect dividing some activities for clarity and combining others for convenience. The schedule was prepared using the "Microsoft Project Professional 2010" computer software.[34] 4.1 SCHEDULE ESTIMATE ASSUMPTIONS The schedule reflects the results of a precedence network developed for the site

decommissioning activities, i.e., a PERT (Program Evaluation and Review Technique) Software Package. The work activity durations used in the precedence network reflect the actual man-hour estimates from the cost table, adjusted by stretching certain activities over their slack range and shifting the start and end dates of others. The following assumptions were made in the development of the decommissioning schedule:

The fuel handling buildings are isolated until such time that all spent fuel

has been discharged from the spent fuel pools to the ISFSI. Decontamination and dismantling of the storage pools is initiated once the transfer of spent fuel is complete (DECON option).

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.

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 the detailed cost tables are based upon the durations developed in the 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. A second critical path is shown for the spent fuel storage period, which determines the release of the fuel handling buildings for final decontamination. Project timelines are provided in Figures 4.2 and 4.3, with milestone dates based on the 2043 shutdown date. The fuel pools are emptied ten years after shutdown, while ISFSI operations continue until the DOE can complete the transfer of assemblies. Deferred decommissioning in the SAFSTOR scenario is assumed to commence so that the operating licenses are terminated within a 60-year period from the cessation of plant operations.


TLG Services, Inc.

FIGURE 4.1 ACTIVITY SCHEDULE

LEGEND

1. Red text and/or shaded scheduling bars indicate critical path activities

2. Shaded scheduling bars associated with major decommissioning periods, e.g., Period 1a, indicate overall duration of that period

3. Blue text and/or diamond symbols indicate major milestones

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TLG Services, Inc.

FIGURE 4.2 DECOMMISSIONING TIMELINE

DECON (not to scale)

Unit 1Periods 1a 1b 2a 2b 2c 2d 2f 3b 3c 3d EndStart Dates 05-Dec-43 04-Dec-44 04-Jun-45 08-Feb-47 04-Jun-49 31-Dec-53 13-May-54 12-Feb-55 06-Oct-56 17-Dec-66 31-Dec-66Durations (Years) 1.0 0.5 1.7 2.3 4.6 0.4 0.8 1.6 10.2 0.04Elapsed Time (Years) 1.5 3.2 5.5 10.1 10.4 11.2 12.8 23.0 23.1

Unit 2Periods 1a 1b 2a 2b 2c 2d 2f 3b 3c 3d 3e 3f EndStart Dates 05-Dec-43 04-Dec-44 04-Jun-45 08-Feb-47 04-Jun-49 31-Dec-53 13-May-54 12-Feb-55 06-Oct-56 17-Dec-66 31-Dec-66 03-May-67 03-Jul-67Durations (Years) 1.0 0.5 1.7 2.3 4.6 0.4 0.8 1.6 10.2 0.04 0.3 0.2Elapsed Time (Years) 1.5 3.2 5.5 10.1 10.4 11.2 12.8 23.0 23.1 23.4 23.6

CNS Spent Fuel ScheduleCNS Pool 10 24 24 62 120 Total(DOE Cask Loaded)

CNS ISFSI 63 63 Total

(Cask to DOE)

Note: Cask distribution is provided as a general representation of inventory per period, totals per period are not actuals as used to calculate costs.


Shutdown and Decommisioning

Preparation

Prompt DecommissioningDECON

Post -Decommissioning ISFSI Operations

Site Restoration ISFSI Decon and Demolition


TLG Services, Inc.

FIGURE 4.3 DECOMMISSIONING TIMELINE

SAFSTOR (not to scale)

Unit 1Periods 1a 1b 1c 2a 2b 2c 3a 3b 4a 4b 4e 4f 5b End

Start Dates 05-Dec-43 04-Dec-44 06-Mar-45 06-Jun-45 31-Dec-53 31-Dec-66 01-Feb-98 01-Feb-99 06-Aug-99 12-Nov-00 27-Feb-02 06-Mar-03 06-Dec-03 30-Jul-05

Durations (Years) 1.0 0.3 0.3 8.6 13.0 31.1 1.0 0.5 1.3 1.3 1.0 0.8 1.6Elapsed Time (Years) 1.3 1.5 10.1 23.1 54.2 55.2 55.7 56.9 58.2 59.2 60.0 61.6

Unit 2Periods 1a 1b 1c 2a 2b 2c 3a 3b 4a 4b 4f 5b End

Start Dates 05-Dec-43 04-Dec-44 06-Mar-45 06-Jun-45 31-Dec-53 31-Dec-66 09-Feb-99 09-Feb-00 14-Aug-00 19-Nov-01 06-Mar-03 06-Dec-03 30-Jul-05

Durations (Years) 1.0 0.3 0.3 8.6 13.0 32.1 1.0 0.5 1.3 1.3 0.8 1.6Elapsed Time (Years) 1.3 1.5 10.1 23.1 55.2 56.2 56.7 58.0 59.2 60.0 61.6

CNS Spent Fuel ScheduleCNS Pool 10 110 120 Total(DOE Cask Loaded)

CNS ISFSI 63 63 Total

(Cask to DOE)

Note: Cask distribution is provided as a general representation of inventory per period, totals per period are not actuals as used to calculate costs.


Shutdown and Decommisioning

Preparation

Preparationsfor

Safe-Storage

Wet & Dry & No Fuel Dormancy

Delayed Decommissioning SAFSTOR

Site Restoration


TLG Services, Inc.

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,[35] 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 destinations for the various waste streams from decommissioning are identified in Figures 5.1 and 5.2. The volumes are shown on a line-item basis in Appendices C and D and summarized in Tables 5.1 and 5.2. The volumes are calculated based on the exterior dimensions for containerized material and on the displaced volume of 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 casks. 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 137Cs will still control the disposition requirements.


TLG Services, Inc.

The waste material produced in the decontamination and dismantling of the nuclear plant 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 (e.g., concrete and dry active waste) and metal with low levels of contamination are sent to processing facilities in Tennessee for conditioning and disposal. The disposal volumes reported in the tables reflect the savings resulting from reprocessing and recycling. Heavily contaminated components and activated materials are routed for direct, controlled disposal. For purposes of constructing the estimates, the cost for disposal at the EnergySolutions’ and Barnwell facilities were used as a proxy for future disposal facilities. Separate rates were used for containerized waste and large components, including the steam generators and reactor coolant pump motors. 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 rate schedule for the Barnwell facility. Additional surcharges were included for activity, dose rate, and/or handling added as appropriate for the particular package. A small quantity of material will be generated during the decommissioning will not be considered suitable for near-surface disposal, and is assumed to be disposed of in a geologic repository, in a manner similar to that envisioned for spent fuel disposal. This material, known as GTCC material, is estimated to require seven spent fuel storage canisters (or the equivalent) per unit to dispose of the most radioactive portions of the reactor vessel internals. The volume and weight reported in Tables 5.1 and 5.2 represent the packaged weight and volume of the spent fuel storage canisters.


TLG Services, Inc.

FIGURE 5.1 RADIOACTIVE WASTE DISPOSITION


TLG Services, Inc.

Barnwell, SC

Oak Ridge, TN

EnergySolutions Clive, UT

FIGURE 5.2 DECOMMISSIONING WASTE DESTINATIONS

RADIOLOGICAL


TLG Services, Inc.

TABLE 5.1 DECON ALTERNATIVE

DECOMMISSIONING WASTE SUMMARY

Waste Cost Basis Class [1] Waste Form Waste Volume

(cubic feet) Weight

(pounds)

Low-Level Radioactive Waste (near-surface disposal)

EnergySolutions A Containerized 145,183 10,216,934

A Bulk 54,609 2,601,288

Barnwell A Large Components 104,572 10,030,358

Barnwell B Shielded Cask 3,429 357,821

Barnwell C Shielded Cask 689 92,447

GTCC (geologic repository)

Spent Fuel Equivalent GTCC TSC 4,999 1,001,600

Processed/Conditioned (off-site recycling center)

Recycling Vendors A Bulk 548,680 21,363,860

Total [2]

862,160 45,664,307

[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.

TABLE 5.2 SAFSTOR ALTERNATIVE

DECOMMISSIONING WASTE SUMMARY

Waste Cost Basis Class [1] Waste Form Waste Volume

(cubic feet) Weight

(pounds)

Low-Level Radioactive Waste (near-surface disposal)

EnergySolutions A Containerized 81,518 6,141,484

A Bulk 59,473 2,679,122

Barnwell A Large Components 104,969 9,234,134

Barnwell B Shielded Cask 250 14,400

Barnwell C Shielded Cask 689 92,447

GTCC (geologic repository)

Spent Fuel Equivalent GTCC TSC 4,999 1,001,600

Processed/Conditioned (off-site recycling center)

Recycling Vendors A Bulk 596,834 23,428,250

Total [2]

848,732 42,591,428

[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.


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6. RESULTS The analysis to estimate the costs to decommission Catawba relied upon the site-specific, technical information developed for a previous analysis prepared in 2008. While not an engineering study, the estimates provide the owners with sufficient information to assess their financial obligations, as they pertain to the eventual decommissioning of the nuclear station. The estimates described in this report are based on numerous fundamental assumptions, including regulatory requirements, project contingencies, low-level radioactive waste disposal practices, high-level radioactive waste management options, and site restoration requirements. The decommissioning scenarios assume continued operation of the station’s spent fuel pools for a minimum of ten years following the cessation of operations for continued cooling of the assemblies. The cost projected to promptly decommission (DECON) Catawba is estimated to be $1,410.9 million. The majority of this cost (approximately 80.5%) is associated with the physical decontamination and dismantling of the nuclear plant so that the operating license can be terminated. Another 11.1% is associated with the management, interim storage, and eventual transfer of the spent fuel. The remaining 8.4% is for the demolition of the designated structures and limited restoration of the site. The cost projected for deferred decommissioning (SAFSTOR) is estimated to be $1,566.0 million. The majority of this cost (approximately 75.2%) is associated with placing the plant in storage, ongoing caretaking of the plant during dormancy, and the eventual physical decontamination and dismantling of the nuclear plant so that the operating license can be terminated. Another 17.3% is associated with the management, interim storage, and eventual transfer of the spent fuel. The remaining 7.5% is for the demolition of the designated structures and limited restoration of the site. The primary cost contributors, identified in Tables 6.1 and 6.2, 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 Duke Energy will oversee the decommissioning program, acting as the 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


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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 pools will remain operational for a minimum of ten years following the cessation of operations. The pools will be isolated and an independent spent fuel island created. This will allow decommissioning operations to proceed in and around the pool areas. Over the ten-year period, the spent fuel will be packaged into transportable canisters for loading into a DOE-provided transport cask. Spent fuel will also be in storage at the ISFSI (from operations). This inventory will be transferred to the DOE after the pools are emptied. 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 requiring controlled disposal is at the EnergySolutions’ and Barnwell facilities. Highly activated components, requiring additional 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 union 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.


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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 plant. 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 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.


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TABLE 6.1 DECON ALTERNATIVE

DECOMMISSIONING COST ELEMENTS (thousands of $2013)

Cost Element Unit 1 Unit 2 Total % Decontamination 14,962 15,689 30,651 2.2 Removal 100,495 147,281 247,776 17.6 Packaging 29,027 27,033 56,060 4.0 Transportation 11,840 11,379 23,218 1.6 Waste Disposal 70,123 66,172 136,295 9.7 Off-site Waste Processing 29,882 30,991 60,873 4.3 Program Management [1] 204,914 215,764 420,677 29.8 Site Security 32,518 58,282 90,801 6.4 Corporate A&G 19,251 20,282 39,534 2.8 Site O&M 1,895 1,933 3,829 0.3 Spent Fuel Pool Isolation 12,145 8,096 20,241 1.4 Spent Fuel (Direct Expenditures) 41,811 63,133 104,943 7.4 Insurance and Regulatory Fees 15,591 20,455 36,047 2.6 Energy 5,672 5,718 11,390 0.8 Characterization and Licensing Surveys 21,116 22,072 43,188 3.1 Property Taxes 32,292 32,884 65,176 4.6 Miscellaneous Equipment 6,566 6,604 13,170 0.9 Miscellaneous Site Services 0 7,025 7,025 0.5 Total [3] 650,100 760,793 1,410,893 100.0 Cost Element Unit 1 Unit 2 Total % License Termination 564,728 571,010 1,135,738 80.5 Spent Fuel Management 46,133 110,736 156,869 11.1 Site Restoration 39,238 79,047 118,285 8.4 Total [3] 650,100 760,793 1,410,893 100.0





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TABLE 6.2 SAFSTOR ALTERNATIVE

DECOMMISSIONING COST ELEMENTS (thousands of $2013)

Cost Element Unit 1 Unit 2 Total % Decontamination 12,441 12,943 25,384 1.6 Removal 94,722 141,170 235,892 15.1 Packaging 21,817 19,823 41,640 2.7 Transportation 7,890 7,310 15,201 1.0 Waste Disposal 55,435 51,117 106,552 6.8 Off-site Waste Processing 32,695 34,018 66,713 4.3 Program Management [1] 236,442 237,093 473,535 30.2 Site Security 69,210 70,138 139,348 8.9 Corporate A&G 22,620 22,684 45,303 2.9 Site O&M 3,925 3,950 7,875 0.5 Spent Fuel Pool Isolation 12,145 8,096 20,241 1.3 Spent Fuel (Direct Expenditures) 48,694 51,655 100,349 6.4 Insurance and Regulatory Fees 55,132 54,315 109,447 7.0 Energy 9,999 9,941 19,940 1.3 Characterization and Licensing Surveys 20,176 21,130 41,306 2.6 Property Taxes 33,630 33,651 67,281 4.3 Miscellaneous Equipment 19,015 23,946 42,960 2.7 Miscellaneous Site Services 7,025 7,025 0.4 Total [3] 755,987 810,007 1,565,994 100.0 Cost Element Unit 1 Unit 2 Total % License Termination 582,758 594,452 1,177,210 75.2 Spent Fuel Management 133,957 136,917 270,874 17.3 Site Restoration 39,272 78,638 117,910 7.5 Total [3] 755,987 810,007 1,565,994 100.0





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7. REFERENCES 1. “Decommissioning Cost Analysis for the Catawba Nuclear Station,” Document

D03-1594-002, Rev. 0, TLG Services, Inc., December 2008. 2. 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, 53 Fed. Reg. 24018, June 27, 1988.

3. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.159, "Assuring the

Availability of Funds for Decommissioning Nuclear Reactors," Rev. 2, October 2011.

4. U.S. Code of Federal Regulations, Title 10, Part 20, Subpart E, “Radiological

Criteria for License Termination.” 5. U.S. Code of Federal Regulations, Title 10, Parts 20 and 50, “Entombment

Options for Power Reactors,” Advanced Notice of Proposed Rulemaking, 66 Fed. Reg. 52551, October 16, 2001.

6. U.S. Code of Federal Regulations, Title 10, Parts 2, 50 and 51,

"Decommissioning of Nuclear Power Reactors," Nuclear Regulatory Commission, 61 Fed. Reg. 39278, July 29, 1996.

7. “Nuclear Waste Policy Act of 1982,” 42 U.S. Code 10101, et seq. 8. “Nuclear Waste Policy Amendments of 1987,” 42 U.S. Code 10172 9. “Blue Ribbon Commission on America’s Nuclear Future, Report to the

Secretary of Energy,” http://www.brc.gov/, January 2012 10. “Strategy for the Management and Disposal of Used Nuclear Fuel and High-

Level Radioactive Waste,” U.S. DOE, January 11, 2013 11. U.S. Code of Federal Regulations, Title 10, Part 961.11, Article IV –

Responsibilities of the Parties, B. DOE Responsibilities, 5.(a) “… DOE shall issue an annual acceptance priority ranking for receipt of SNF and/or HLW at the DOE repository. This priority ranking shall be based on the age of SNF and/or HLW as calculated from the date of discharge of such materials from the civilian nuclear power reactor. The oldest fuel or waste will have the highest priority for acceptance …”


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7. REFERENCES (continued)

12. “Acceptance Priority Ranking & Annual Capacity Report,” DOE/RW-0567, July

2004 13. U.S. Code of Federal Regulations, Title 10, Part 50, “Domestic Licensing of

Production and Utilization Facilities,” Subpart 54 (bb), “Conditions of Licenses.” 14. U.S. Code of Federal Regulations, Title 10, Part 72, Subpart K, “General

License for Storage of Spent Fuel at Power Reactor Sites.” 15. “Low Level Radioactive Waste Policy Act,” Public Law 96-573, 1980. 16. “Low-Level Radioactive Waste Policy Amendments Act of 1985,” Public Law 99-

240, 1986. 17. U.S. Code of Federal Regulations, Title 10, Part 61.55 “Waste Classification.” 18. U.S. Code of Federal Regulations, Title 10, Part 20, Subpart E, “Final Rule,

Radiological Criteria for License Termination,” 62 Fed. Reg. 39058, July 21, 1997.

19. “Establishment of Cleanup Levels for CERCLA Sites with Radioactive

Contamination,” EPA Memorandum OSWER No. 9200.4-18, August 22, 1997. 20. 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.”

21. “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.

22. “Multi-Agency Radiation Survey and Site Investigation Manual (MARSSIM),”

NUREG/CR-1575, Rev. 1, EPA 402-R-97-016, Rev. 1, August 2000 23. T.S. LaGuardia et al., "Guidelines for Producing Commercial Nuclear Power

Plant Decommissioning Cost Estimates," AIF/NESP-036, May 1986.


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7. REFERENCES (continued)

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

Department of Energy, DOE/EV/10128-1, November 1980. 25. "Building Construction Cost Data 2013," Robert Snow Means Company, Inc.,

Kingston, Massachusetts. 26. Project and Cost Engineers’ Handbook, Second Edition, p. 239, American

Association of Cost Engineers, Marcel Dekker, Inc., New York, New York, 1984. 27. Civilian Radioactive Waste Management System Waste Acceptance System

Requirements Document, Revision 5” (DOE/RW-0351) issued May 31, 2007. 28. U.S. Department of Transportation, Title 49 of the Code of Federal Regulations,

"Transportation," Parts 173 through 178. 29. Tri-State Motor Transit Company, published tariffs, Interstate Commerce

Commission (ICC), Docket No. MC-427719 Rules Tariff, March 2004, Radioactive Materials Tariff, August 2011.

30. J.C. Evans et al., "Long-Lived Activation Products in Reactor Materials"

NUREG/CR-3474, Pacific Northwest Laboratory for the Nuclear Regulatory Commission, August 1984.

31. R.I. Smith, G.J. Konzek, W.E. Kennedy, Jr., "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.

32. 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.

33. “Financial Protection Requirements for Permanently Shutdown Nuclear Power

Reactors,” 10 CFR Parts 50 and 140, Proposed Rule, 62 Fed. Reg. 58690, October 30, 1997.

34. "Microsoft Project Professional 2010," Microsoft Corporation, Redmond, WA. 35. “Atomic Energy Act of 1954,” (68 Stat. 919).

Catawba Nuclear Station Document D03-1671-001, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 1 of 4

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APPENDIX A

UNIT COST FACTOR DEVELOPMENT


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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 (50% of critical duration) 128 + Radiation/ALARA adjustment (37.1% of critical duration) 95 Adjusted work duration 478 + Protective clothing adjustment (30% of adjusted duration) 143 Productive work duration 621 + Work break adjustment (8.33 % of productive duration) 52 Total work duration (minutes) 673 *** Total duration = 11.217 hr ***

* alpha designators indicate activities that can be performed in parallel


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APPENDIX A (continued)

3. LABOR REQUIRED Duration Rate Crew Number (hours) ($/hr) Cost --------------------------------------------------------------------------------------------------------------------- Laborers 3.00 11.217 $**.** $***.** Craftsmen 2.00 11.217 $**.** $***.** Foreman 1.00 11.217 $**.** $***.** General Foreman 0.25 11.217 $**.** $**.** Fire Watch 0.05 11.217 $**.** $**.** Health Physics Technician 1.00 11.217 $**.** $***.** Total Labor Cost $3,194.92 4. EQUIPMENT & CONSUMABLES COSTS Equipment Costs none Consumables/Materials Costs -Universal Sorbent 50 @ $0.63 sq. ft. {1} $31.50 -Tarpaulins (oil resistant/fire retardant) 50 @ $0.28/sq. ft. {2} $14.00 -Gas torch consumables 1 @ $17.50/hr. x 1 hr. {3} $17.50 Subtotal cost of equipment and materials $63.00 Overhead & profit on equipment and materials @ 17.00 % $10.71 Total costs, equipment & material $73.71 TOTAL COST: Removal of contaminated heat exchanger <3000 pounds: $3,268.63 Total labor cost: $3,194.92 Total equipment/material costs: $73.71 Total craft labor man-hours required per unit: 81.88

** denotes business sensitive information


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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. www.mcmaster.com online catalog, McMaster Carr Spill Control

(7193T88) 2. R.S. Means (2013) Division 01 56, Section 13.60-0600, page 22 3. R.S. Means (2013) Division 01 54 33, Section 40-6360, page 688

Material and consumable costs were adjusted using the regional indices for

Rock Hill, South Carolina

Catawba Nuclear Station Document D03-1671-001, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 1 of 7

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APPENDIX B

UNIT COST FACTOR LISTING (DECON: Power Block Structures Only)


APPENDIX B

UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit($) -------------------------------------------------------------------------------------------------------------------------

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Removal of clean instrument and sampling tubing, $/linear foot 0.32 Removal of clean pipe 0.25 to 2 inches diameter, $/linear foot 3.31 Removal of clean pipe >2 to 4 inches diameter, $/linear foot 4.92 Removal of clean pipe >4 to 8 inches diameter, $/linear foot 10.25 Removal of clean pipe >8 to 14 inches diameter, $/linear foot 19.14 Removal of clean pipe >14 to 20 inches diameter, $/linear foot 25.01 Removal of clean pipe >20 to 36 inches diameter, $/linear foot 36.77 Removal of clean pipe >36 inches diameter, $/linear foot 43.63 Removal of clean valve >2 to 4 inches 66.75 Removal of clean valve >4 to 8 inches 102.45 Removal of clean valve >8 to 14 inches 191.37 Removal of clean valve >14 to 20 inches 250.12 Removal of clean valve >20 to 36 inches 367.66 Removal of clean valve >36 inches 436.26 Removal of clean pipe hanger for small bore piping 23.78 Removal of clean pipe hanger for large bore piping 78.43 Removal of clean pump, <300 pound 175.51 Removal of clean pump, 300-1000 pound 499.13 Removal of clean pump, 1000-10,000 pound 1,932.01 Removal of clean pump, >10,000 pound 3,745.67 Removal of clean pump motor, 300-1000 pound 206.98 Removal of clean pump motor, 1000-10,000 pound 800.40 Removal of clean pump motor, >10,000 pound 1,800.90 Removal of clean heat exchanger <3000 pound 1,043.02 Removal of clean heat exchanger >3000 pound 2,638.37 Removal of clean feedwater heater/deaerator 7,398.11 Removal of clean moisture separator/reheater 15,156.51 Removal of clean tank, <300 gallons 225.45 Removal of clean tank, 300-3000 gallon 705.77 Removal of clean tank, >3000 gallons, $/square foot surface area 6.16


APPENDIX B



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Removal of clean electrical equipment, <300 pound 93.55 Removal of clean electrical equipment, 300-1000 pound 337.01 Removal of clean electrical equipment, 1000-10,000 pound 674.01 Removal of clean electrical equipment, >10,000 pound 1,625.56 Removal of clean electrical transformer < 30 tons 1,128.93 Removal of clean electrical transformer > 30 tons 3,251.12 Removal of clean standby diesel generator, <100 kW 1,153.10 Removal of clean standby diesel generator, 100 kW to 1 MW 2,573.81 Removal of clean standby diesel generator, >1 MW 5,328.28 Removal of clean electrical cable tray, $/linear foot 8.91 Removal of clean electrical conduit, $/linear foot 3.90 Removal of clean mechanical equipment, <300 pound 93.55 Removal of clean mechanical equipment, 300-1000 pound 337.01 Removal of clean mechanical equipment, 1000-10,000 pound 674.01 Removal of clean mechanical equipment, >10,000 pound 1,625.56 Removal of clean HVAC equipment, <300 pound 113.11 Removal of clean HVAC equipment, 300-1000 pound 404.95 Removal of clean HVAC equipment, 1000-10,000 pound 807.05 Removal of clean HVAC equipment, >10,000 pound 1,625.56 Removal of clean HVAC ductwork, $/pound 0.34 Removal of contaminated instrument and sampling tubing, $/linear foot 1.14 Removal of contaminated pipe 0.25 to 2 inches diameter, $/linear foot 16.65 Removal of contaminated pipe >2 to 4 inches diameter, $/linear foot 27.65 Removal of contaminated pipe >4 to 8 inches diameter, $/linear foot 45.71 Removal of contaminated pipe >8 to 14 inches diameter, $/linear foot 86.69 Removal of contaminated pipe >14 to 20 inches diameter, $/linear foot 103.58 Removal of contaminated pipe >20 to 36 inches diameter, $/linear foot 142.02 Removal of contaminated pipe >36 inches diameter, $/linear foot 167.18 Removal of contaminated valve >2 to 4 inches 340.70 Removal of contaminated valve >4 to 8 inches 410.38


APPENDIX B



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Removal of contaminated valve >8 to 14 inches 813.62 Removal of contaminated valve >14 to 20 inches 1,030.78 Removal of contaminated valve >20 to 36 inches 1,367.02 Removal of contaminated valve >36 inches 1,618.61 Removal of contaminated pipe hanger for small bore piping 109.42 Removal of contaminated pipe hanger for large bore piping 338.43 Removal of contaminated pump, <300 pound 736.06 Removal of contaminated pump, 300-1000 pound 1,716.67 Removal of contaminated pump, 1000-10,000 pound 5,341.91 Removal of contaminated pump, >10,000 pound 13,009.93 Removal of contaminated pump motor, 300-1000 pound 747.34 Removal of contaminated pump motor, 1000-10,000 pound 2,193.08 Removal of contaminated pump motor, >10,000 pound 4,923.91 Removal of contaminated heat exchanger <3000 pound 3,268.63 Removal of contaminated heat exchanger >3000 pound 9,534.89 Removal of contaminated tank, <300 gallons 1,227.57 Removal of contaminated tank, >300 gallons, $/square foot 23.78 Removal of contaminated electrical equipment, <300 pound 558.14 Removal of contaminated electrical equipment, 300-1000 pound 1,374.88 Removal of contaminated electrical equipment, 1000-10,000 pound 2,648.19 Removal of contaminated electrical equipment, >10,000 pound 5,223.03 Removal of contaminated electrical cable tray, $/linear foot 27.04 Removal of contaminated electrical conduit, $/linear foot 13.24 Removal of contaminated mechanical equipment, <300 pound 620.91 Removal of contaminated mechanical equipment, 300-1000 pound 1,518.29 Removal of contaminated mechanical equipment, 1000-10,000 pound 2,919.64 Removal of contaminated mechanical equipment, >10,000 pound 5,223.03 Removal of contaminated HVAC equipment, <300 pound 620.91 Removal of contaminated HVAC equipment, 300-1000 pound 1,518.29 Removal of contaminated HVAC equipment, 1000-10,000 pound 2,919.64


APPENDIX B



TLG Services, Inc.

Removal of contaminated HVAC equipment, >10,000 pound 5,223.03 Removal of contaminated HVAC ductwork, $/pound 1.75 Removal/plasma arc cut of contaminated thin metal components, $/linear in. 2.94 Additional decontamination of surface by washing, $/square foot 6.07 Additional decontamination of surfaces by hydrolasing, $/square foot 29.09 Decontamination rig hook up and flush, $/ 250 foot length 5,232.87 Chemical flush of components/systems, $/gallon 19.73 Removal of clean standard reinforced concrete, $/cubic yard 124.57 Removal of grade slab concrete, $/cubic yard 156.77 Removal of clean concrete floors, $/cubic yard 334.81 Removal of sections of clean concrete floors, $/cubic yard 963.46 Removal of clean heavily rein concrete w/#9 rebar, $/cubic yard 220.99 Removal of contaminated heavily rein concrete w/#9 rebar, $/cubic yard 1,816.94 Removal of clean heavily rein concrete w/#18 rebar, $/cubic yard 279.42 Removal of contaminated heavily rein concrete w/#18 rebar, $/cubic yard 2,402.40 Removal heavily rein concrete w/#18 rebar & steel embedments, $/cubic yard 398.92 Removal of below-grade suspended floors, $/cubic yard 334.81 Removal of clean monolithic concrete structures, $/cubic yard 771.54 Removal of contaminated monolithic concrete structures, $/cubic yard 1,807.50 Removal of clean foundation concrete, $/cubic yard 609.91 Removal of contaminated foundation concrete, $/cubic yard 1,684.83 Explosive demolition of bulk concrete, $/cubic yard 28.01 Removal of clean hollow masonry block wall, $/cubic yard 79.38 Removal of contaminated hollow masonry block wall, $/cubic yard 278.42 Removal of clean solid masonry block wall, $/cubic yard 79.38 Removal of contaminated solid masonry block wall, $/cubic yard 278.42 Backfill of below-grade voids, $/cubic yard 34.67 Removal of subterranean tunnels/voids, $/linear foot 96.50 Placement of concrete for below-grade voids, $/cubic yard 126.80 Excavation of clean material, $/cubic yard 3.43


APPENDIX B



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Excavation of contaminated material, $/cubic yard 40.28 Removal of clean concrete rubble (tipping fee included), $/cubic yard 24.60 Removal of contaminated concrete rubble, $/cubic yard 25.37 Removal of building by volume, $/cubic foot 0.29 Removal of clean building metal siding, $/square foot 0.96 Removal of contaminated building metal siding, $/square foot 3.52 Removal of standard asphalt roofing, $/square foot 1.50 Removal of transite panels, $/square foot 1.74 Scarifying contaminated concrete surfaces (drill & spall), $/square foot 11.20 Scabbling contaminated concrete floors, $/square foot 6.36 Scabbling contaminated concrete walls, $/square foot 16.38 Scabbling contaminated ceilings, $/square foot 55.83 Scabbling structural steel, $/square foot 5.24 Removal of clean overhead crane/monorail < 10 ton capacity 491.08 Removal of contaminated overhead crane/monorail < 10 ton capacity 1,459.57 Removal of clean overhead crane/monorail >10-50 ton capacity 1,178.60 Removal of contaminated overhead crane/monorail >10-50 ton capacity 3,502.39 Removal of polar crane > 50 ton capacity 4,972.29 Removal of gantry crane > 50 ton capacity 20,319.49 Removal of structural steel, $/pound 0.17 Removal of clean steel floor grating, $/square foot 3.88 Removal of contaminated steel floor grating, $/square foot 11.50 Removal of clean free standing steel liner, $/square foot 9.24 Removal of contaminated free standing steel liner, $/square foot 27.69 Removal of clean concrete-anchored steel liner, $/square foot 4.62 Removal of contaminated concrete-anchored steel liner, $/square foot 32.30 Placement of scaffolding in clean areas, $/square foot 13.24 Placement of scaffolding in contaminated areas, $/square foot 20.89 Landscaping with topsoil, $/acre 25,345.56 Cost of CPC B-88 LSA box & preparation for use 2,122.67


APPENDIX B



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Cost of CPC B-25 LSA box & preparation for use 1,935.77 Cost of CPC B-12V 12 gauge LSA box & preparation for use 1,565.24 Cost of CPC B-144 LSA box & preparation for use 11,109.44 Cost of LSA drum & preparation for use 187.38 Cost of cask liner for CNSI 8 120A cask (resins) 8,366.71 Cost of cask liner for CNSI 8 120A cask (filters) 8,212.62 Decontamination of surfaces with vacuuming, $/square foot 0.66

Catawba Nuclear Station Document D03-1671-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 1 of 21

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APPENDIX C

DETAILED COST ANALYSIS

DECON

Table Page

C-1 Unit 1, DECON Decommissioning Cost Estimate ............................................. 2 C-2 Unit 2, DECON Decommissioning Cost Estimate ........................................... 11

Catawba Nuclear StationDecommissioning Cost Analysis

Document D03-1671-001, Rev. 0Appendix C, Page 2 of 21

Table C-1Catawba Nuclear Station, Unit 1

DECON Decommissioning Cost Estimate(thousands of 2013 dollars)

Costs run: Fri, Nov 8, 2013 at 10:41:57 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial / Utility andActivity DECCER Version 2010.09.09i Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft ContractorIndex Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours

PERIOD 1a - Shutdown through Transition

Period 1a Direct Decommissioning Activities1a.1.1 Prepare preliminary decommissioning cost - - - - - - 70 10 80 80 - - - - - - - - - 928 1a.1.2 Notification of Cessation of Operations a 1a.1.3 Remove fuel & source material n/a1a.1.4 Notification of Permanent Defueling a 1a.1.5 Deactivate plant systems & process waste a 1a.1.6 Prepare and submit PSDAR - - - - - - 107 16 123 123 - - - - - - - - - 1,428 1a.1.7 Review plant dwgs & specs. - - - - - - 247 37 284 284 - - - - - - - - - 3,284 1a.1.8 Perform detailed rad survey a 1a.1.9 Estimate by-product inventory - - - - - - 54 8 62 62 - - - - - - - - - 714 1a.1.10 End product description - - - - - - 54 8 62 62 - - - - - - - - - 714 1a.1.11 Detailed by-product inventory - - - - - - 70 10 80 80 - - - - - - - - - 928 1a.1.12 Define major work sequence - - - - - - 402 60 462 462 - - - - - - - - - 5,355 1a.1.13 Perform SER and EA - - - - - - 166 25 191 191 - - - - - - - - - 2,213 1a.1.14 Perform Site-Specific Cost Study - - - - - - 268 40 308 308 - - - - - - - - - 3,570 1a.1.15 Prepare/submit License Termination Plan - - - - - - 220 33 252 252 - - - - - - - - - 2,925 1a.1.16 Receive NRC approval of termination plan a

Activity Specifications

1a.1.17.1 Plant & temporary facilities - - - - - - 264 40 303 273 - 30 - - - - - - - 3,513 1a.1.17.2 Plant systems - - - - - - 223 33 257 231 - 26 - - - - - - - 2,975 1a.1.17.3 NSSS Decontamination Flush - - - - - - 27 4 31 31 - - - - - - - - - 357 1a.1.17.4 Reactor internals - - - - - - 381 57 438 438 - - - - - - - - - 5,069 1a.1.17.5 Reactor vessel - - - - - - 348 52 401 401 - - - - - - - - - 4,641 1a.1.17.6 Biological shield - - - - - - 27 4 31 31 - - - - - - - - - 357 1a.1.17.7 Steam generators - - - - - - 167 25 192 192 - - - - - - - - - 2,228 1a.1.17.8 Reinforced concrete - - - - - - 86 13 99 49 - 49 - - - - - - - 1,142 1a.1.17.9 Main Turbine - - - - - - 21 3 25 - - 25 - - - - - - - 286 1a.1.17.10 Main Condensers - - - - - - 21 3 25 - - 25 - - - - - - - 286 1a.1.17.11 Plant structures & buildings - - - - - - 167 25 192 96 - 96 - - - - - - - 2,228 1a.1.17.12 Waste management - - - - - - 247 37 284 284 - - - - - - - - - 3,284 1a.1.17.13 Facility & site closeout - - - - - - 48 7 55 28 - 28 - - - - - - - 643 1a.1.17 Total - - - - - - 2,027 304 2,331 2,053 - 278 - - - - - - - 27,008

Planning & Site Preparations1a.1.18 Prepare dismantling sequence - - - - - - 129 19 148 148 - - - - - - - - - 1,714 1a.1.19 Plant prep. & temp. svces - - - - - - 2,900 435 3,335 3,335 - - - - - - - - - - 1a.1.20 Design water clean-up system - - - - - - 75 11 86 86 - - - - - - - - - 1,000 1a.1.21 Rigging/Cont. Cntrl Envlps/tooling/etc. - - - - - - 2,200 330 2,530 2,530 - - - - - - - - - - 1a.1.22 Procure casks/liners & containers - - - - - - 66 10 76 76 - - - - - - - - - 878 1a.1 Subtotal Period 1a Activity Costs - - - - - - 9,053 1,358 10,411 10,132 - 278 - - - - - - - 52,659

Period 1a Collateral Costs1a.3.1 Spent Fuel Capital and Transfer - - - - - - 1,154 173 1,328 - 1,328 - - - - - - - - - 1a.3 Subtotal Period 1a Collateral Costs - - - - - - 1,154 173 1,328 - 1,328 - - - - - - - - -

Period 1a Period-Dependent Costs1a.4.1 Insurance - - - - - - 1,233 123 1,356 1,356 - - - - - - - - - - 1a.4.2 Property taxes - - - - - - 7,150 715 7,865 7,865 - - - - - - - - - - 1a.4.3 Health physics supplies - 470 - - - - - 118 588 588 - - - - - - - - - - 1a.4.4 Heavy equipment rental - 563 - - - - - 84 647 647 - - - - - - - - - - 1a.4.5 Disposal of DAW generated - - 13 2 - 29 - 9 52 52 - - - 593 - - - 11,865 19 - 1a.4.6 Plant energy budget - - - - - - 735 110 845 845 - - - - - - - - - - 1a.4.7 NRC Fees - - - - - - 1,164 116 1,280 1,280 - - - - - - - - - - 1a.4.8 Emergency Planning Fees - - - - - - 611 61 672 - 672 - - - - - - - - - 1a.4.9 FEMA Fees - - - - - - 350 52 402 - 402 - - - - - - - - - 1a.4.10 Spent Fuel Pool O&M - - - - - - 783 117 900 - 900 - - - - - - - - - 1a.4.11 Corporate A&G - - - - - - 2,362 354 2,717 2,717 - - - - - - - - - - 1a.4.12 Site O&M - - - - - - 212 32 244 244 - - - - - - - - - - 1a.4.13 Security Staff Cost - - - - - - 3,303 495 3,798 3,798 - - - - - - - - - 102,075 1a.4.14 Utility Staff Cost - - - - - - 23,144 3,472 26,616 26,616 - - - - - - - - - 395,243 1a.4 Subtotal Period 1a Period-Dependent Costs - 1,033 13 2 - 29 41,046 5,860 47,983 46,009 1,974 - - 593 - - - 11,865 19 497,318

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1a.0 TOTAL PERIOD 1a COST - 1,033 13 2 - 29 51,253 7,391 59,721 56,141 3,302 278 - 593 - - - 11,865 19 549,977

PERIOD 1b - Decommissioning Preparations

Period 1b Direct Decommissioning Activities

Detailed Work Procedures1b.1.1.1 Plant systems - - - - - - 254 38 292 263 - 29 - - - - - - - 3,379 1b.1.1.2 NSSS Decontamination Flush - - - - - - 54 8 62 62 - - - - - - - - - 714 1b.1.1.3 Reactor internals - - - - - - 134 20 154 154 - - - - - - - - - 1,785 1b.1.1.4 Remaining buildings - - - - - - 72 11 83 21 - 62 - - - - - - - 964 1b.1.1.5 CRD cooling assembly - - - - - - 54 8 62 62 - - - - - - - - - 714 1b.1.1.6 CRD housings & ICI tubes - - - - - - 54 8 62 62 - - - - - - - - - 714 1b.1.1.7 Incore instrumentation - - - - - - 54 8 62 62 - - - - - - - - - 714 1b.1.1.8 Reactor vessel - - - - - - 195 29 224 224 - - - - - - - - - 2,592 1b.1.1.9 Facility closeout - - - - - - 64 10 74 37 - 37 - - - - - - - 857 1b.1.1.10 Missile shields - - - - - - 24 4 28 28 - - - - - - - - - 321 1b.1.1.11 Biological shield - - - - - - 64 10 74 74 - - - - - - - - - 857 1b.1.1.12 Steam generators - - - - - - 247 37 284 284 - - - - - - - - - 3,284 1b.1.1.13 Reinforced concrete - - - - - - 54 8 62 31 - 31 - - - - - - - 714 1b.1.1.14 Main Turbine - - - - - - 84 13 96 - - 96 - - - - - - - 1,114 1b.1.1.15 Main Condensers - - - - - - 84 13 96 - - 96 - - - - - - - 1,114 1b.1.1.16 Auxiliary building - - - - - - 146 22 168 151 - 17 - - - - - - - 1,949 1b.1.1.17 Reactor building - - - - - - 146 22 168 151 - 17 - - - - - - - 1,949 1b.1.1 Total - - - - - - 1,782 267 2,049 1,664 - 385 - - - - - - - 23,736

1b.1.2 Decon primary loop 629 - - - - - - 314 943 943 - - - - - - - - 1,067 - 1b.1 Subtotal Period 1b Activity Costs 629 - - - - - 1,782 582 2,992 2,606 - 385 - - - - - - 1,067 23,736

Period 1b Additional Costs1b.2.1 Spent fuel pool isolation - - - - - - 10,561 1,584 12,145 12,145 - - - - - - - - - - 1b.2.2 Site Characterization - - - - - - 2,778 833 3,612 3,612 - - - - - - - - 19,100 7,852 1b.2 Subtotal Period 1b Additional Costs - - - - - - 13,339 2,418 15,756 15,756 - - - - - - - - 19,100 7,852

Period 1b Collateral Costs1b.3.1 Decon equipment 924 - - - - - - 139 1,062 1,062 - - - - - - - - - - 1b.3.2 Staff relocation expenses - - - - - - 1,130 169 1,299 1,299 - - - - - - - - - - 1b.3.3 Process decommissioning water waste 27 - 12 63 - 71 - 42 213 213 - - - 169 - - - 10,154 33 - 1b.3.4 Process decommissioning chemical flush waste 2 - 52 368 - 578 - 206 1,206 1,206 - - - - 781 - - 83,178 146 - 1b.3.5 Small tool allowance - 1 - - - - - 0 2 2 - - - - - - - - - - 1b.3.6 Pipe cutting equipment - 1,100 - - - - - 165 1,265 1,265 - - - - - - - - - - 1b.3.7 Decon rig 1,500 - - - - - - 225 1,725 1,725 - - - - - - - - - - 1b.3.8 Spent Fuel Capital and Transfer - - - - - - 729 109 838 - 838 - - - - - - - - - 1b.3 Subtotal Period 1b Collateral Costs 2,452 1,101 64 431 - 649 1,858 1,055 7,610 6,773 838 - - 169 781 - - 93,333 179 -

Period 1b Period-Dependent Costs1b.4.1 Decon supplies 28 - - - - - - 7 35 35 - - - - - - - - - - 1b.4.2 Insurance - - - - - - 615 61 676 676 - - - - - - - - - - 1b.4.3 Property taxes - - - - - - 2,558 256 2,814 2,814 - - - - - - - - - - 1b.4.4 Health physics supplies - 257 - - - - - 64 322 322 - - - - - - - - - - 1b.4.5 Heavy equipment rental - 281 - - - - - 42 323 323 - - - - - - - - - - 1b.4.6 Disposal of DAW generated - - 7 1 - 16 - 5 30 30 - - - 338 - - - 6,755 11 - 1b.4.7 Plant energy budget - - - - - - 733 110 843 843 - - - - - - - - - - 1b.4.8 NRC Fees - - - - - - 342 34 376 376 - - - - - - - - - - 1b.4.9 Emergency Planning Fees - - - - - - 305 30 335 - 335 - - - - - - - - - 1b.4.10 FEMA Fees - - - - - - 174 26 201 - 201 - - - - - - - - - 1b.4.11 Spent Fuel Pool O&M - - - - - - 390 59 449 - 449 - - - - - - - - - 1b.4.12 Corporate A&G - - - - - - 1,458 219 1,676 1,676 - - - - - - - - - - 1b.4.13 Site O&M - - - - - - 131 20 151 151 - - - - - - - - - - 1b.4.14 Security Staff Cost - - - - - - 1,647 247 1,894 1,894 - - - - - - - - - 50,898 1b.4.15 Utility Staff Cost - - - - - - 14,560 2,184 16,744 16,744 - - - - - - - - - 243,880 1b.4 Subtotal Period 1b Period-Dependent Costs 28 538 7 1 - 16 22,912 3,364 26,867 25,883 984 - - 338 - - - 6,755 11 294,778

1b.0 TOTAL PERIOD 1b COST 3,109 1,639 71 432 - 665 39,891 7,418 53,226 51,018 1,822 385 - 507 781 - - 100,088 20,357 326,365

PERIOD 1 TOTALS 3,109 2,672 84 434 - 694 91,144 14,809 112,947 107,159 5,124 664 - 1,100 781 - - 111,953 20,376 876,342

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PERIOD 2a - Large Component Removal

Period 2a Direct Decommissioning Activities

Nuclear Steam Supply System Removal2a.1.1.1 Reactor Coolant Piping 212 207 27 53 - 550 - 306 1,356 1,356 - - - 1,348 - - - 154,125 9,274 - 2a.1.1.2 Pressurizer Relief Tank 21 18 6 11 - 108 - 44 208 208 - - - 272 - - - 30,174 885 - 2a.1.1.3 Reactor Coolant Pumps & Motors 78 77 178 222 - 1,263 - 425 2,243 2,243 - - - 4,511 - - - 807,600 4,187 100 2a.1.1.4 Pressurizer 50 47 508 96 - 1,155 - 391 2,247 2,247 - - - 4,126 - - - 292,560 2,712 938 2a.1.1.5 Steam Generators 339 3,001 3,206 1,276 3,037 6,953 - 3,626 21,437 21,437 - - 39,289 24,841 - - - 3,652,669 23,234 2,125 2a.1.1.6 Retired Steam Generator Units - - 2,285 1,220 3,037 6,746 - 2,554 15,841 15,841 - - 39,289 24,101 - - - 3,402,733 10,800 1,500 2a.1.1.7 CRDMs/ICIs/Service Structure Removal 152 112 364 124 - 551 - 297 1,599 1,599 - - - 5,881 - - - 154,244 5,482 - 2a.1.1.8 Reactor Vessel Internals 93 3,535 11,824 1,290 - 5,524 324 8,787 31,378 31,378 - - - 2,003 934 344 - 334,323 32,217 1,421 2a.1.1.9 Reactor Vessel 93 6,655 2,411 1,573 - 2,939 324 7,552 21,547 21,547 - - - 9,265 - - - 950,422 32,217 1,421 2a.1.1 Totals 1,039 13,652 20,808 5,866 6,073 25,789 649 23,981 97,856 97,856 - - 78,578 76,349 934 344 - 9,778,850 121,007 7,504

Removal of Major Equipment2a.1.2 Main Turbine/Generator - 395 404 90 698 564 - 398 2,548 2,548 - - 4,726 2,632 - - - 457,489 9,495 - 2a.1.3 Main Condensers - 1,326 228 97 805 717 - 669 3,843 3,843 - - 7,274 3,038 - - - 528,161 32,740 -

Cascading Costs from Clean Building Demolition2a.1.4.1 Reactor - 339 - - - - - 51 389 389 - - - - - - - - 4,509 - 2a.1.4.2 AB - Fw Pump/Switchgear Area - 23 - - - - - 3 26 26 - - - - - - - - 299 - 2a.1.4.3 Auxiliary Building - 182 - - - - - 27 210 210 - - - - - - - - 2,376 - 2a.1.4.4 Containment Mechanical Equipment - 6 - - - - - 1 7 7 - - - - - - - - 105 - 2a.1.4.5 Main Steam Doghouses - 100 - - - - - 15 115 115 - - - - - - - - 1,109 - 2a.1.4.6 Turbine Building - 294 - - - - - 44 339 339 - - - - - - - - 4,856 - 2a.1.4.7 Upper Head Injection Tank Building - 5 - - - - - 1 6 6 - - - - - - - - 70 - 2a.1.4.8 Fuel Building - 89 - - - - - 13 103 103 - - - - - - - - 1,173 - 2a.1.4 Totals - 1,038 - - - - - 156 1,194 1,194 - - - - - - - - 14,497 -

Disposal of Plant Systems2a.1.5.1 Aux Bldg Chilled Water - 89 2 3 109 - - 39 243 243 - - 1,094 - - - - 44,411 1,896 - 2a.1.5.2 Auxiliary Feedwater - 247 16 31 1,018 - - 221 1,532 1,532 - - 10,186 - - - - 413,660 5,567 - 2a.1.5.3 Auxiliary Steam - 13 - - - - - 2 15 - - 15 - - - - - - 386 - 2a.1.5.4 Auxiliary Steam RCA - 106 2 4 147 - - 49 309 309 - - 1,467 - - - - 59,568 2,289 - 2a.1.5.5 CCW Intake Screen Backwash - 5 - - - - - 1 6 - - 6 - - - - - - 144 - 2a.1.5.6 CO2 Gen Purge - 8 - - - - - 1 10 - - 10 - - - - - - 251 - 2a.1.5.7 Condensate - 368 - - - - - 55 424 - - 424 - - - - - - 10,255 - 2a.1.5.8 Condensate Storage - 65 - - - - - 10 74 - - 74 - - - - - - 1,737 - 2a.1.5.9 Condenser Cleaning - 40 - - - - - 6 46 - - 46 - - - - - - 1,125 - 2a.1.5.10 Condenser Steam Air Ejector - 34 - - - - - 5 39 - - 39 - - - - - - 988 - 2a.1.5.11 Containment Spray/Valve Inj Water - 234 5 10 339 - - 111 700 700 - - 3,389 - - - - 137,648 5,088 - 2a.1.5.12 Convent LP Service Water - 95 - - - - - 14 109 - - 109 - - - - - - 2,691 - 2a.1.5.13 Conventional Chemical Addition - 8 - - - - - 1 10 - - 10 - - - - - - 238 - 2a.1.5.14 Conventional Chemical Addition RCA - 15 0 0 11 - - 5 31 31 - - 109 - - - - 4,424 293 - 2a.1.5.15 DG Engine Cooling Water - 19 - - - - - 3 22 - - 22 - - - - - - 542 - 2a.1.5.16 DG Engine Fuel Oil - 67 - - - - - 10 77 - - 77 - - - - - - 1,753 - 2a.1.5.17 DG Engine Lube Oil - 29 - - - - - 4 33 - - 33 - - - - - - 829 - 2a.1.5.18 DG Engine Starting Air - 35 - - - - - 5 41 - - 41 - - - - - - 1,012 - 2a.1.5.19 DG Room Sump Pump - 6 - - - - - 1 7 - - 7 - - - - - - 175 - 2a.1.5.20 FDWP Condensate Seal - 22 - - - - - 3 25 - - 25 - - - - - - 632 - 2a.1.5.21 Feedwater - 54 - - - - - 8 62 - - 62 - - - - - - 1,525 - 2a.1.5.22 Feedwater Lube & Hydraulic Oil - 14 - - - - - 2 16 - - 16 - - - - - - 415 - 2a.1.5.23 Feedwater Pump Turbine Steam Seal - 3 - - - - - 0 3 - - 3 - - - - - - 80 - 2a.1.5.24 Feedwater RCA - 85 4 8 274 - - 64 436 436 - - 2,742 - - - - 111,348 1,971 - 2a.1.5.25 Generator Hydrogen - 7 - - - - - 1 8 - - 8 - - - - - - 217 - 2a.1.5.26 Generator Seal Oil - 10 - - - - - 2 12 - - 12 - - - - - - 311 - 2a.1.5.27 Heater Bleed Steam - 35 - - - - - 5 40 - - 40 - - - - - - 999 - 2a.1.5.28 Heater Drains - 135 - - - - - 20 155 - - 155 - - - - - - 3,850 - 2a.1.5.29 Heater Relief Valve - 20 - - - - - 3 23 - - 23 - - - - - - 525 - 2a.1.5.30 Heater Vent - 18 - - - - - 3 21 - - 21 - - - - - - 559 - 2a.1.5.31 MN Turbine Lube Oil & Purification - 40 - - - - - 6 46 - - 46 - - - - - - 1,130 - 2a.1.5.32 Main Steam - 15 - - - - - 2 18 - - 18 - - - - - - 450 - 2a.1.5.33 Main Steam Bypass to Condenser - 27 - - - - - 4 31 - - 31 - - - - - - 784 - 2a.1.5.34 Main Steam Leakoff & Steam Seal - 9 - - - - - 1 10 - - 10 - - - - - - 249 - 2a.1.5.35 Main Steam RCA - 29 1 2 59 - - 16 107 107 - - 594 - - - - 24,127 614 -

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Disposal of Plant Systems (continued)2a.1.5.36 Main Steam Vent - 130 4 8 252 - - 72 465 465 - - 2,525 - - - - 102,559 2,942 - 2a.1.5.37 Miscellaneous Equipment - 1 - - - - - 0 1 - - 1 - - - - - - 18 - 2a.1.5.38 Moisture Separator Reheater Bld Steam - 5 - - - - - 1 6 - - 6 - - - - - - 156 - 2a.1.5.39 Moisture Separator Reheater Drain - 152 - - - - - 23 175 - - 175 - - - - - - 4,233 - 2a.1.5.40 SG Wet Layup Recirculation - 21 0 1 17 - - 8 47 47 - - 174 - - - - 7,060 429 - 2a.1.5.41 SM Supply to Aux Equipment - 26 - - - - - 4 30 - - 30 - - - - - - 762 - 2a.1.5.42 SM Supply to Aux Equipment RCA - 10 0 0 10 - - 4 25 25 - - 100 - - - - 4,077 216 - 2a.1.5.43 Standby Shutdown Diesel - 3 - - - - - 0 3 - - 3 - - - - - - 84 - 2a.1.5.44 Steam Generator Blowdown Recycle - 311 46 57 630 372 - 278 1,693 1,693 - - 6,304 1,576 - - - 360,274 7,430 - 2a.1.5.45 Steam Supply to FW Pump Turbine - 26 - - - - - 4 29 - - 29 - - - - - - 743 - 2a.1.5.46 Turbine Crossover - 3 - - - - - 1 4 - - 4 - - - - - - 102 - 2a.1.5.47 Turbine Exhaust - 2 - - - - - 0 2 - - 2 - - - - - - 64 - 2a.1.5.48 Turbine Hydraulic Oil - 10 - - - - - 2 12 - - 12 - - - - - - 298 - 2a.1.5 Totals - 2,708 81 124 2,866 372 - 1,084 7,234 5,590 - 1,645 28,685 1,576 - - - 1,269,156 69,048 -

2a.1.6 Scaffolding in support of decommissioning - 807 16 4 77 14 - 219 1,137 1,137 - - 694 61 - - - 35,257 24,657 -

2a.1 Subtotal Period 2a Activity Costs 1,039 19,925 21,538 6,181 10,518 27,456 649 26,506 113,812 112,168 - 1,645 119,956 83,656 934 344 - 12,068,910 271,445 7,504

Period 2a Additional Costs2a.2.1 Remedial Action Surveys - - - - - - 1,708 512 2,220 2,220 - - - - - - - - 34,967 - 2a.2 Subtotal Period 2a Additional Costs - - - - - - 1,708 512 2,220 2,220 - - - - - - - - 34,967 -

Period 2a Collateral Costs2a.3.1 Process decommissioning water waste 54 - 24 128 - 144 - 84 434 434 - - - 345 - - - 20,708 67 - 2a.3.3 Small tool allowance - 223 - - - - - 33 256 231 - 26 - - - - - - - - 2a.3.4 Spent Fuel Capital and Transfer - - - - - - 2,523 378 2,902 - 2,902 - - - - - - - - - 2a.3 Subtotal Period 2a Collateral Costs 54 223 24 128 - 144 2,523 496 3,592 664 2,902 26 - 345 - - - 20,708 67 -

Period 2a Period-Dependent Costs2a.4.1 Decon supplies 95 - - - - - - 24 119 119 - - - - - - - - - - 2a.4.2 Insurance - - - - - - 955 96 1,051 1,051 - - - - - - - - - - 2a.4.3 Property taxes - - - - - - 8,037 804 8,841 7,957 - 884 - - - - - - - - 2a.4.4 Health physics supplies - 2,176 - - - - - 544 2,720 2,720 - - - - - - - - - - 2a.4.5 Heavy equipment rental - 3,626 - - - - - 544 4,170 4,170 - - - - - - - - - - 2a.4.6 Disposal of DAW generated - - 101 16 - 230 - 70 418 418 - - - 4,722 - - - 94,434 154 - 2a.4.7 Plant energy budget - - - - - - 1,174 176 1,350 1,350 - - - - - - - - - - 2a.4.8 NRC Fees - - - - - - 1,048 105 1,153 1,153 - - - - - - - - - - 2a.4.9 Emergency Planning Fees - - - - - - 1,028 103 1,130 - 1,130 - - - - - - - - - 2a.4.10 Spent Fuel Pool O&M - - - - - - 1,317 198 1,514 - 1,514 - - - - - - - - - 2a.4.11 Corporate A&G - - - - - - 4,299 645 4,943 4,943 - - - - - - - - - - 2a.4.12 Site O&M - - - - - - 453 68 521 521 - - - - - - - - - - 2a.4.13 Security Staff Cost - - - - - - 4,296 644 4,940 4,940 - - - - - - - - - 129,817 2a.4.14 Utility Staff Cost - - - - - - 43,697 6,554 50,251 50,251 - - - - - - - - - 719,257 2a.4 Subtotal Period 2a Period-Dependent Costs 95 5,802 101 16 - 230 66,302 10,574 83,120 79,592 2,645 884 - 4,722 - - - 94,434 154 849,074

2a.0 TOTAL PERIOD 2a COST 1,187 25,950 21,663 6,324 10,518 27,830 71,182 38,089 202,745 194,644 5,546 2,554 119,956 88,723 934 344 - 12,184,050 306,633 856,579

PERIOD 2b - Site Decontamination


Disposal of Plant Systems2b.1.1.1 Annulus Ventilation - 37 3 5 120 16 - 32 214 214 - - 1,203 68 - - - 53,382 822 - 2b.1.1.2 Aux & RB Heating Water - 479 6 12 398 - - 182 1,077 1,077 - - 3,980 - - - - 161,630 10,059 - 2b.1.1.3 Aux Bldg Ventilation - 190 17 25 443 114 - 148 936 936 - - 4,430 481 - - - 211,740 4,473 - 2b.1.1.4 Boron Recycle 380 408 42 46 312 362 - 440 1,990 1,990 - - 3,121 1,556 - - - 228,102 17,569 - 2b.1.1.5 Boron Thermal Regeneration 215 290 40 42 113 383 - 303 1,385 1,385 - - 1,132 1,619 - - - 153,131 10,010 - 2b.1.1.6 Chemical & Volume Control 702 692 191 186 307 1,743 - 1,053 4,874 4,874 - - 3,070 7,386 - - - 612,794 26,597 - 2b.1.1.7 Component Cooling - 98 - - - - - 15 113 - - 113 - - - - - - 2,823 - 2b.1.1.8 Component Cooling RCA - 172 5 10 341 - - 96 624 624 - - 3,413 - - - - 138,588 3,584 - 2b.1.1.9 Condenser Circulating Water - 98 - - - - - 15 113 - - 113 - - - - - - 2,771 - 2b.1.1.10 Cont Air Release & Addition - 42 4 4 23 34 - 24 131 131 - - 235 144 - - - 19,051 1,012 - 2b.1.1.11 Cont Air Return Ex & H2 Skimmer - 105 10 12 95 90 - 66 378 378 - - 955 382 - - - 64,092 2,533 - 2b.1.1.12 Cont CRD, & ICI Room Vent - 91 18 24 250 158 - 105 645 645 - - 2,502 671 - - - 145,963 2,203 - 2b.1.1.13 Cont Water Sample & Purge - 9 0 0 1 3 - 3 18 18 - - 10 14 - - - 1,303 242 -

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Disposal of Plant Systems (continued)2b.1.1.14 Containment Chilled Water - 26 - - - - - 4 30 - - 30 - - - - - - 712 - 2b.1.1.15 Containment Chilled Water RCA - 74 2 4 141 - - 41 262 262 - - 1,407 - - - - 57,124 1,665 - 2b.1.1.16 Containment Purge Ventilation - 177 23 33 482 178 - 168 1,061 1,061 - - 4,824 753 - - - 245,689 4,298 - 2b.1.1.17 Conventional Sampling - 371 36 29 46 270 - 175 926 926 - - 456 1,138 - - - 94,041 8,828 - 2b.1.1.18 Diesel Bldg Ventilation - 9 - - - - - 1 10 - - 10 - - - - - - 254 - 2b.1.1.19 Electrical (clean) - 2,432 - - - - - 365 2,797 - - 2,797 - - - - - - 64,849 - 2b.1.1.20 Electrical (contaminated) - 705 45 57 319 466 - 354 1,945 1,945 - - 3,192 1,975 - - - 260,184 16,383 - 2b.1.1.21 Electrical (contaminated) RCA - 4,421 85 162 5,353 - - 1,941 11,962 11,962 - - 53,582 - - - - 2,175,984 97,394 - 2b.1.1.22 Equipment Decon - 34 2 3 25 19 - 18 101 101 - - 255 81 - - - 15,749 803 - 2b.1.1.23 Fire Protection - 37 - - - - - 5 42 - - 42 - - - - - - 1,045 - 2b.1.1.24 Fire Protection RCA - 155 5 9 287 - - 83 538 538 - - 2,869 - - - - 116,495 3,515 - 2b.1.1.25 Ice Condenser Refrigeration - 502 13 26 851 - - 258 1,651 1,651 - - 8,522 - - - - 346,098 11,241 - 2b.1.1.26 Instrument Air - 203 - - - - - 30 233 - - 233 - - - - - - 6,048 - 2b.1.1.27 Instrument Air RCA - 728 9 17 566 - - 270 1,590 1,590 - - 5,663 - - - - 229,971 15,129 - 2b.1.1.28 Liquid Waste Recycle 720 920 125 124 212 1,157 - 942 4,199 4,199 - - 2,118 4,925 - - - 410,043 35,395 - 2b.1.1.29 Miscellaneous Ventilation - 46 - - - - - 7 52 - - 52 - - - - - - 1,469 - 2b.1.1.30 Nuclear Sampling - 300 26 20 27 185 - 131 688 688 - - 275 779 - - - 62,886 7,275 - 2b.1.1.31 Nuclear Service Water - 67 - - - - - 10 77 - - 77 - - - - - - 1,898 - 2b.1.1.32 Nuclear Service Water Pump Vent - 1 - - - - - 0 1 - - 1 - - - - - - 31 - 2b.1.1.33 Nuclear Service Water RCA - 519 18 35 1,164 - - 311 2,048 2,048 - - 11,651 - - - - 473,134 11,611 - 2b.1.1.34 Reactor Coolant - 125 38 45 91 419 - 160 878 878 - - 915 1,774 - - - 154,412 3,104 - 2b.1.1.35 Refueling Water - 328 20 27 449 135 - 189 1,149 1,149 - - 4,494 577 - - - 220,287 7,907 - 2b.1.1.36 Residual Heat Removal 166 155 33 34 48 320 - 217 974 974 - - 484 1,354 - - - 109,275 5,079 - 2b.1.1.37 Safety Injection - 433 112 114 461 993 - 454 2,569 2,569 - - 4,619 4,209 - - - 465,721 10,392 - 2b.1.1.38 Turbine Building Ventilation - 101 - - - - - 15 116 - - 116 - - - - - - 3,108 - 2b.1.1 Totals 2,184 15,579 929 1,104 12,925 7,043 - 8,633 48,398 44,813 - 3,584 129,375 29,886 - - - 7,226,870 404,130 -

2b.1.2 Scaffolding in support of decommissioning - 1,008 20 5 96 18 - 274 1,421 1,421 - - 867 76 - - - 44,071 30,822 -

Decontamination of Site Buildings2b.1.3.1 Reactor 1,129 847 47 291 949 1,402 - 1,317 5,982 5,982 - - 9,498 10,936 - - - 1,073,955 42,525 - 2b.1.3.2 Auxiliary Building 530 288 11 130 94 217 - 426 1,696 1,696 - - 943 3,637 - - - 351,591 18,395 - 2b.1.3.3 Containment Mechanical Equipment 23 20 1 5 12 9 - 21 91 91 - - 122 147 - - - 17,328 964 - 2b.1.3.4 Retired Steam Generator Facility 36 4 0 1 - 2 - 20 63 63 - - - 42 - - - 3,600 958 - 2b.1.3 Totals 1,717 1,158 59 428 1,055 1,631 - 1,784 7,832 7,832 - - 10,562 14,761 - - - 1,446,475 62,841 -

2b.1 Subtotal Period 2b Activity Costs 3,901 17,745 1,009 1,537 14,076 8,692 - 10,691 57,651 54,067 - 3,584 140,804 44,723 - - - 8,717,416 497,793 -

Period 2b Additional Costs2b.2.1 Remedial Action Surveys - - - - - - 2,358 708 3,066 3,066 - - - - - - - - 48,286 - 2b.2 Subtotal Period 2b Additional Costs - - - - - - 2,358 708 3,066 3,066 - - - - - - - - 48,286 -

Period 2b Collateral Costs2b.3.1 Process decommissioning water waste 134 - 62 327 - 369 - 214 1,106 1,106 - - - 885 - - - 53,078 172 - 2b.3.2 Process decommissioning chemical flush waste 4 - 133 938 - 1,472 - 524 3,071 3,071 - - - 1,988 - - - 211,788 372 - 2b.3.3 Small tool allowance - 339 - - - - - 51 390 390 - - - - - - - - - - 2b.3.4 Spent Fuel Capital and Transfer - - - - - - 3,480 522 4,002 - 4,002 - - - - - - - - - 2b.3 Subtotal Period 2b Collateral Costs 138 339 195 1,265 - 1,841 3,480 1,311 8,569 4,567 4,002 - - 2,872 - - - 264,866 544 -

Period 2b Period-Dependent Costs2b.4.1 Decon supplies 871 - - - - - - 218 1,089 1,089 - - - - - - - - - - 2b.4.2 Insurance - - - - - - 1,319 132 1,451 1,451 - - - - - - - - - - 2b.4.3 Property taxes - - - - - - 7,697 770 8,466 8,466 - - - - - - - - - - 2b.4.4 Health physics supplies - 3,498 - - - - - 874 4,372 4,372 - - - - - - - - - - 2b.4.5 Heavy equipment rental - 4,958 - - - - - 744 5,701 5,701 - - - - - - - - - - 2b.4.6 Disposal of DAW generated - - 145 22 - 330 - 100 598 598 - - - 6,757 - - - 135,133 220 - 2b.4.7 Plant energy budget - - - - - - 1,280 192 1,472 1,472 - - - - - - - - - - 2b.4.8 NRC Fees - - - - - - 1,448 145 1,592 1,592 - - - - - - - - - - 2b.4.9 Emergency Planning Fees - - - - - - 1,419 142 1,561 - 1,561 - - - - - - - - - 2b.4.10 Spent Fuel Pool O&M - - - - - - 1,818 273 2,091 - 2,091 - - - - - - - - - 2b.4.11 Liquid Radwaste Processing Equipment/Services - - - - - - 461 69 530 530 - - - - - - - - - - 2b.4.12 Corporate A&G - - - - - - 5,010 752 5,762 5,762 - - - - - - - - - - 2b.4.13 Site O&M - - - - - - 528 79 607 607 - - - - - - - - - - 2b.4.14 Security Staff Cost - - - - - - 5,933 890 6,823 6,823 - - - - - - - - - 179,291 2b.4.15 Utility Staff Cost - - - - - - 50,738 7,611 58,348 58,348 - - - - - - - - - 838,309 2b.4 Subtotal Period 2b Period-Dependent Costs 871 8,455 145 22 - 330 77,651 12,990 100,464 96,812 3,652 - - 6,757 - - - 135,133 220 1,017,600

TLG Services, Inc.






2b.0 TOTAL PERIOD 2b COST 4,910 26,539 1,349 2,825 14,076 10,862 83,489 25,700 169,751 158,512 7,655 3,584 140,804 54,352 - - - 9,117,415 546,843 1,017,600

PERIOD 2c - Spent fuel delay prior to SFP decon

Period 2c Direct Decommissioning Activities

Period 2c Collateral Costs2c.3.1 Spent Fuel Capital and Transfer - - - - - - 7,114 1,067 8,181 - 8,181 - - - - - - - - - 2c.3 Subtotal Period 2c Collateral Costs - - - - - - 7,114 1,067 8,181 - 8,181 - - - - - - - - -

Period 2c Period-Dependent Costs2c.4.1 Insurance - - - - - - 2,598 260 2,857 2,857 - - - - - - - - - - 2c.4.2 Property taxes - - - - - - 3,846 385 4,231 4,231 - - - - - - - - - - 2c.4.3 Health physics supplies - 1,589 - - - - - 397 1,986 1,986 - - - - - - - - - - 2c.4.4 Disposal of DAW generated - - 39 6 - 89 - 27 162 162 - - - 1,830 - - - 36,596 60 - 2c.4.5 Plant energy budget - - - - - - 672 101 773 773 - - - - - - - - - - 2c.4.6 NRC Fees - - - - - - 1,348 135 1,483 1,483 - - - - - - - - - - 2c.4.7 Emergency Planning Fees - - - - - - 2,795 279 3,074 - 3,074 - - - - - - - - - 2c.4.8 Spent Fuel Pool O&M - - - - - - 3,581 537 4,118 - 4,118 - - - - - - - - - 2c.4.9 Corporate A&G - - - - - - 1,654 248 1,902 1,902 - - - - - - - - - - 2c.4.10 Site O&M - - - - - - 174 26 200 200 - - - - - - - - - - 2c.4.11 Security Staff Cost - - - - - - 9,458 1,419 10,877 10,877 - - - - - - - - - 279,129 2c.4.12 Utility Staff Cost - - - - - - 16,780 2,517 19,297 19,297 - - - - - - - - - 276,743 2c.4 Subtotal Period 2c Period-Dependent Costs - 1,589 39 6 - 89 42,906 6,331 50,961 43,769 7,193 - - 1,830 - - - 36,596 60 555,871

2c.0 TOTAL PERIOD 2c COST - 1,589 39 6 - 89 50,020 7,398 59,142 43,769 15,373 - - 1,830 - - - 36,596 60 555,871

PERIOD 2d - Decontamination Following Wet Fuel Storage

Period 2d Direct Decommissioning Activities2d.1.1 Remove spent fuel racks 362 36 167 90 - 885 - 441 1,980 1,980 - - - 3,751 - - - 247,922 1,033 -

Disposal of Plant Systems2d.1.2.1 FHB Ventilation - 72 7 12 298 33 - 73 496 496 - - 2,985 138 - - - 130,319 1,642 - 2d.1.2.2 Spent Fuel Cooling 158 218 28 28 70 252 - 214 967 967 - - 700 1,068 - - - 99,152 7,616 - 2d.1.2 Totals 158 290 35 40 368 285 - 287 1,463 1,463 - - 3,685 1,206 - - - 229,472 9,258 -

Decontamination of Site Buildings2d.1.3.1 Fuel Building 785 871 11 37 339 71 - 685 2,799 2,799 - - 3,393 828 - - - 206,666 37,665 - 2d.1.3 Totals 785 871 11 37 339 71 - 685 2,799 2,799 - - 3,393 828 - - - 206,666 37,665 -

2d.1.4 Scaffolding in support of decommissioning - 202 4 1 19 4 - 55 284 284 - - 173 15 - - - 8,814 6,164 -

2d.1 Subtotal Period 2d Activity Costs 1,304 1,399 217 167 726 1,245 - 1,468 6,526 6,526 - - 7,251 5,800 - - - 692,874 54,120 -

Period 2d Additional Costs2d.2.1 License Termination Survey Planning - - - - - - 830 249 1,079 1,079 - - - - - - - - - 6,240 2d.2.2 Remedial Action Surveys - - - - - - 370 111 481 481 - - - - - - - - 7,574 - 2d.2 Subtotal Period 2d Additional Costs - - - - - - 1,200 360 1,560 1,560 - - - - - - - - 7,574 6,240

Period 2d Collateral Costs2d.3.1 Process decommissioning water waste 62 - 31 163 - 184 - 104 544 544 - - - 441 - - - 26,448 86 - 2d.3.2 Process decommissioning chemical flush waste 0 - 12 84 - 132 - 47 275 275 - - - 178 - - - 18,991 33 - 2d.3.3 Small tool allowance - 46 - - - - - 7 53 53 - - - - - - - - - - 2d.3.4 Decommissioning Equipment Disposition - - 141 37 664 125 - 151 1,118 1,118 - - 6,000 529 - - - 304,968 88 - 2d.3 Subtotal Period 2d Collateral Costs 62 46 184 284 664 441 - 309 1,991 1,991 - - 6,000 1,148 - - - 350,407 207 -

Period 2d Period-Dependent Costs2d.4.1 Decon supplies 160 - - - - - - 40 200 200 - - - - - - - - - - 2d.4.2 Insurance - - - - - - 207 21 228 228 - - - - - - - - - - 2d.4.3 Property taxes - - - - - - 9 1 10 10 - - - - - - - - - - 2d.4.4 Health physics supplies - 426 - - - - - 106 532 532 - - - - - - - - - - 2d.4.5 Heavy equipment rental - 778 - - - - - 117 894 894 - - - - - - - - - - 2d.4.6 Disposal of DAW generated - - 29 4 - 66 - 20 120 120 - - - 1,351 - - - 27,024 44 - 2d.4.7 Plant energy budget - - - - - - 107 16 123 123 - - - - - - - - - - 2d.4.8 NRC Fees - - - - - - 194 19 213 213 - - - - - - - - - - 2d.4.9 Emergency Planning Fees - - - - - - 223 22 245 - 245 - - - - - - - - -

TLG Services, Inc.






Period 2d Period-Dependent Costs (continued)2d.4.10 Liquid Radwaste Processing Equipment/Services - - - - - - 145 22 166 166 - - - - - - - - - - 2d.4.11 Corporate A&G - - - - - - 518 78 595 595 - - - - - - - - - - 2d.4.12 Site O&M - - - - - - 55 8 63 63 - - - - - - - - - - 2d.4.13 Security Staff Cost - - - - - - 499 75 574 574 - - - - - - - - - 13,779 2d.4.14 Utility Staff Cost - - - - - - 5,306 796 6,102 6,102 - - - - - - - - - 86,640 2d.4 Subtotal Period 2d Period-Dependent Costs 160 1,204 29 4 - 66 7,262 1,341 10,066 9,821 245 - - 1,351 - - - 27,024 44 100,419

2d.0 TOTAL PERIOD 2d COST 1,526 2,649 430 456 1,390 1,751 8,462 3,478 20,142 19,897 245 - 13,251 8,299 - - - 1,070,306 61,946 106,659

PERIOD 2f - License Termination

Period 2f Direct Decommissioning Activities2f.1.1 ORISE confirmatory survey - - - - - - 161 48 209 209 - - - - - - - - - - 2f.1.2 Terminate license a 2f.1 Subtotal Period 2f Activity Costs - - - - - - 161 48 209 209 - - - - - - - - - -

Period 2f Additional Costs2f.2.1 License Termination Survey - - - - - - 8,038 2,411 10,449 10,449 - - - - - - - - 182,954 3,120 2f.2 Subtotal Period 2f Additional Costs - - - - - - 8,038 2,411 10,449 10,449 - - - - - - - - 182,954 3,120

Period 2f Collateral Costs2f.3.1 Staff relocation expenses - - - - - - 1,130 169 1,299 1,299 - - - - - - - - - - 2f.3 Subtotal Period 2f Collateral Costs - - - - - - 1,130 169 1,299 1,299 - - - - - - - - - -

Period 2f Period-Dependent Costs2f.4.1 Insurance - - - - - - 392 39 431 431 - - - - - - - - - - 2f.4.2 Property taxes - - - - - - 19 2 21 21 - - - - - - - - - - 2f.4.3 Health physics supplies - 778 - - - - - 195 973 973 - - - - - - - - - - 2f.4.4 Disposal of DAW generated - - 7 1 - 16 - 5 29 29 - - - 332 - - - 6,639 11 - 2f.4.5 Plant energy budget - - - - - - 111 17 127 127 - - - - - - - - - - 2f.4.6 NRC Fees - - - - - - 453 45 499 499 - - - - - - - - - - 2f.4.7 Emergency Planning Fees - - - - - - 460 46 506 - 506 - - - - - - - - - 2f.4.8 Corporate A&G - - - - - - 589 88 678 678 - - - - - - - - - - 2f.4.9 Site O&M - - - - - - 62 9 71 71 - - - - - - - - - - 2f.4.10 Security Staff Cost - - - - - - 1,014 152 1,166 1,166 - - - - - - - - - 27,893 2f.4.11 Utility Staff Cost - - - - - - 6,335 950 7,285 7,285 - - - - - - - - - 98,607 2f.4 Subtotal Period 2f Period-Dependent Costs - 778 7 1 - 16 9,435 1,549 11,786 11,280 506 - - 332 - - - 6,639 11 126,500

2f.0 TOTAL PERIOD 2f COST - 778 7 1 - 16 18,763 4,178 23,744 23,238 506 - - 332 - - - 6,639 182,964 129,620

PERIOD 2 TOTALS 7,624 57,505 23,488 9,612 25,985 40,550 231,917 78,842 475,523 440,058 29,325 6,139 274,011 153,536 934 344 - 22,415,010 1,098,446 2,666,329

PERIOD 3b - Site Restoration


Demolition of Remaining Site Buildings3b.1.1.1 Reactor - 3,053 - - - - - 458 3,511 - - 3,511 - - - - - - 40,693 - 3b.1.1.2 AB - Fw Pump/Switchgear Area - 208 - - - - - 31 239 - - 239 - - - - - - 2,750 - 3b.1.1.3 Auxiliary Building - 1,647 - - - - - 247 1,895 - - 1,895 - - - - - - 21,564 - 3b.1.1.4 Containment Mechanical Equipment - 59 - - - - - 9 67 - - 67 - - - - - - 1,085 - 3b.1.1.5 Cooling Towers (3) - 2,246 - - - - - 337 2,583 - - 2,583 - - - - - - 34,180 - 3b.1.1.6 Diesel Generator Building - 332 - - - - - 50 382 - - 382 - - - - - - 4,152 - 3b.1.1.7 Main Steam Doghouses - 905 - - - - - 136 1,041 - - 1,041 - - - - - - 10,075 - 3b.1.1.8 Retired Steam Generator Facility - 338 - - - - - 51 389 - - 389 - - - - - - 4,660 - 3b.1.1.9 Turbine Building - 2,800 - - - - - 420 3,220 - - 3,220 - - - - - - 47,939 - 3b.1.1.10 Turbine Pedestal - 693 - - - - - 104 796 - - 796 - - - - - - 7,683 - 3b.1.1.11 Upper Head Injection Tank Building - 44 - - - - - 7 50 - - 50 - - - - - - 633 - 3b.1.1.12 Fuel Building - 824 - - - - - 124 947 - - 947 - - - - - - 11,073 - 3b.1.1 Totals - 13,148 - - - - - 1,972 15,120 - - 15,120 - - - - - - 186,487 -

Site Closeout Activities3b.1.2 Grade & landscape site - 203 - - - - - 30 233 - - 233 - - - - - - 420 - 3b.1.3 Final report to NRC - - - - - - 84 13 96 96 - - - - - - - - - 1,114 3b.1 Subtotal Period 3b Activity Costs - 13,350 - - - - 84 2,015 15,449 96 - 15,353 - - - - - - 186,907 1,114

TLG Services, Inc.






Period 3b Additional Costs3b.2.1 Concrete Crushing - 553 - - - - 3 83 640 - - 640 - - - - - - 2,669 - 3b.2 Subtotal Period 3b Additional Costs - 553 - - - - 3 83 640 - - 640 - - - - - - 2,669 -

Period 3b Collateral Costs3b.3.1 Small tool allowance - 136 - - - - - 20 157 - - 157 - - - - - - - - 3b.3.2 Corporate A&G - - - - - - 851 128 978 - - 978 - - - - - - - - 3b.3.3 Site O&M - - - - - - 33 5 38 - - 38 - - - - - - - - 3b.3 Subtotal Period 3b Collateral Costs - 136 - - - - 884 153 1,173 - - 1,173 - - - - - - - -

Period 3b Period-Dependent Costs3b.4.1 Insurance - - - - - - 859 86 944 - 944 - - - - - - - - - 3b.4.2 Property taxes - - - - - - 41 4 45 - 45 - - - - - - - - - 3b.4.3 Heavy equipment rental - 5,027 - - - - - 754 5,781 - - 5,781 - - - - - - - - 3b.4.4 Plant energy budget - - - - - - 121 18 139 - - 139 - - - - - - - - 3b.4.5 Emergency Planning Fees - - - - - - 1,007 101 1,108 - 1,108 - - - - - - - - - 3b.4.6 Security Staff Cost - - - - - - 2,128 319 2,447 - 2,105 343 - - - - - - - 58,067 3b.4.7 Utility Staff Cost - - - - - - 8,899 1,335 10,234 - 1,228 9,006 - - - - - - - 142,347 3b.4 Subtotal Period 3b Period-Dependent Costs - 5,027 - - - - 13,056 2,617 20,700 - 5,431 15,270 - - - - - - - 200,414

3b.0 TOTAL PERIOD 3b COST - 19,067 - - - - 14,026 4,869 37,962 96 5,431 32,435 - - - - - - 189,577 201,528

PERIOD 3c - Fuel Storage Operations/Shipping


Period 3c Collateral Costs3c.3.1 Spent Fuel Capital and Transfer - - - - - - 5,438 816 6,253 - 6,253 - - - - - - - - - 3c.3 Subtotal Period 3c Collateral Costs - - - - - - 5,438 816 6,253 - 6,253 - - - - - - - - -

3c.0 TOTAL PERIOD 3c COST - - - - - - 5,438 816 6,253 - 6,253 - - - - - - - - -

PERIOD 3d - GTCC shipping

Period 3d Direct Decommissioning Activities

Nuclear Steam Supply System Removal3d.1.1.1 Vessel & Internals GTCC Disposal - - 875 - - 14,307 - 2,234 17,415 17,415 - - - - - - 2,499 500,800 - - 3d.1.1 Totals - - 875 - - 14,307 - 2,234 17,415 17,415 - - - - - - 2,499 500,800 - - 3d.1 Subtotal Period 3d Activity Costs - - 875 - - 14,307 - 2,234 17,415 17,415 - - - - - - 2,499 500,800 - -

3d.0 TOTAL PERIOD 3d COST - - 875 - - 14,307 - 2,234 17,415 17,415 - - - - - - 2,499 500,800 - -

PERIOD 3 TOTALS - 19,067 875 - - 14,307 19,464 7,918 61,631 17,512 11,684 32,435 - - - - 2,499 500,800 189,577 201,528

TOTAL COST TO DECOMMISSION 10,732 79,245 24,447 10,046 25,985 55,551 342,525 101,569 650,100 564,729 46,133 39,238 274,011 154,636 1,714 344 2,499 23,027,760 1,308,399 3,744,199

TLG Services, Inc.






TOTAL COST TO DECOMMISSION WITH 18.52% CONTINGENCY: $650,100 thousands of 2013 dollars

TOTAL NRC LICENSE TERMINATION COST IS 86.87% OR: $564,729 thousands of 2013 dollars

SPENT FUEL MANAGEMENT COST IS 7.1% OR: $46,133 thousands of 2013 dollars

NON-NUCLEAR DEMOLITION COST IS 6.04% OR: $39,238 thousands of 2013 dollars

TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC): 156,695 cubic feet

TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED: 2,499 cubic feet

TOTAL SCRAP METAL REMOVED: 44,055 tons

TOTAL CRAFT LABOR REQUIREMENTS: 1,308,399 man-hours

End Notes:n/a - 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 non-zero.a cell containing " - " indicates a zero value

TLG Services, Inc.


Document D03-1671-001, Rev. 0Appendix C , Page 11 of 21

Table C-2 Catawba Nuclear Station, Unit 2


Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial / Utility andActivity Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft ContractorIndex Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours


Period 1a Direct Decommissioning Activities1a.1.1 Prepare preliminary decommissioning cost - - - - - - 70 10 80 80 - - - - - - - - - 928 1a.1.2 Notification of Cessation of Operations a 1a.1.3 Remove fuel & source material n/a1a.1.4 Notification of Permanent Defueling a 1a.1.5 Deactivate plant systems & process waste a 1a.1.6 Prepare and submit PSDAR - - - - - - 107 16 123 123 - - - - - - - - - 1,428 1a.1.7 Review plant dwgs & specs. - - - - - - 247 37 284 284 - - - - - - - - - 3,284 1a.1.8 Perform detailed rad survey a 1a.1.9 Estimate by-product inventory - - - - - - 54 8 62 62 - - - - - - - - - 714 1a.1.10 End product description - - - - - - 54 8 62 62 - - - - - - - - - 714 1a.1.11 Detailed by-product inventory - - - - - - 70 10 80 80 - - - - - - - - - 928 1a.1.12 Define major work sequence - - - - - - 402 60 462 462 - - - - - - - - - 5,355 1a.1.13 Perform SER and EA - - - - - - 166 25 191 191 - - - - - - - - - 2,213 1a.1.14 Perform Site-Specific Cost Study - - - - - - 268 40 308 308 - - - - - - - - - 3,570 1a.1.15 Prepare/submit License Termination Plan - - - - - - 220 33 252 252 - - - - - - - - - 2,925 1a.1.16 Receive NRC approval of termination plan a


1a.1.17.1 Plant & temporary facilities - - - - - - 264 40 303 273 - 30 - - - - - - - 3,513 1a.1.17.2 Plant systems - - - - - - 223 33 257 231 - 26 - - - - - - - 2,975 1a.1.17.3 NSSS Decontamination Flush - - - - - - 27 4 31 31 - - - - - - - - - 357 1a.1.17.4 Reactor internals - - - - - - 381 57 438 438 - - - - - - - - - 5,069 1a.1.17.5 Reactor vessel - - - - - - 348 52 401 401 - - - - - - - - - 4,641 1a.1.17.6 Biological shield - - - - - - 27 4 31 31 - - - - - - - - - 357 1a.1.17.7 Steam generators - - - - - - 167 25 192 192 - - - - - - - - - 2,228 1a.1.17.8 Reinforced concrete - - - - - - 86 13 99 49 - 49 - - - - - - - 1,142 1a.1.17.9 Main Turbine - - - - - - 21 3 25 - - 25 - - - - - - - 286 1a.1.17.10 Main Condensers - - - - - - 21 3 25 - - 25 - - - - - - - 286 1a.1.17.11 Plant structures & buildings - - - - - - 167 25 192 96 - 96 - - - - - - - 2,228 1a.1.17.12 Waste management - - - - - - 247 37 284 284 - - - - - - - - - 3,284 1a.1.17.13 Facility & site closeout - - - - - - 48 7 55 28 - 28 - - - - - - - 643 1a.1.17 Total - - - - - - 2,027 304 2,331 2,053 - 278 - - - - - - - 27,008



Period 1a Period-Dependent Costs1a.4.1 Insurance - - - - - - 1,233 123 1,356 1,356 - - - - - - - - - - 1a.4.2 Property taxes - - - - - - 7,150 715 7,865 7,865 - - - - - - - - - - 1a.4.3 Health physics supplies - 470 - - - - - 118 588 588 - - - - - - - - - - 1a.4.4 Heavy equipment rental - 563 - - - - - 84 647 647 - - - - - - - - - - 1a.4.5 Disposal of DAW generated - - 13 2 - 29 - 9 52 52 - - - 593 - - - 11,865 19 - 1a.4.6 Plant energy budget - - - - - - 735 110 845 845 - - - - - - - - - - 1a.4.7 NRC Fees - - - - - - 826 83 908 908 - - - - - - - - - - 1a.4.8 Emergency Planning Fees - - - - - - 611 61 672 - 672 - - - - - - - - - 1a.4.9 FEMA Fees - - - - - - 350 52 402 - 402 - - - - - - - - - 1a.4.10 Spent Fuel Pool O&M - - - - - - 783 117 900 - 900 - - - - - - - - - 1a.4.11 ISFSI Operating Costs - - - - - - 111 17 128 - 128 - - - - - - - - - 1a.4.12 Corporate A&G - - - - - - 2,362 354 2,717 2,717 - - - - - - - - - - 1a.4.13 Site O&M - - - - - - 212 32 244 244 - - - - - - - - - - 1a.4.14 Security Staff Cost - - - - - - 3,303 495 3,798 3,798 - - - - - - - - - 102,075 1a.4.15 Utility Staff Cost - - - - - - 23,144 3,472 26,616 26,616 - - - - - - - - - 395,243

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1a.4 Subtotal Period 1a Period-Dependent Costs - 1,033 13 2 - 29 40,820 5,843 47,739 45,636 2,103 - - 593 - - - 11,865 19 497,318

1a.0 TOTAL PERIOD 1a COST - 1,033 13 2 - 29 51,026 7,374 59,477 55,768 3,430 278 - 593 - - - 11,865 19 549,977



Detailed Work Procedures1b.1.1.1 Plant systems - - - - - - 254 38 292 263 - 29 - - - - - - - 3,379 1b.1.1.2 NSSS Decontamination Flush - - - - - - 54 8 62 62 - - - - - - - - - 714 1b.1.1.3 Reactor internals - - - - - - 134 20 154 154 - - - - - - - - - 1,785 1b.1.1.4 Remaining buildings - - - - - - 72 11 83 21 - 62 - - - - - - - 964 1b.1.1.5 CRD cooling assembly - - - - - - 54 8 62 62 - - - - - - - - - 714 1b.1.1.6 CRD housings & ICI tubes - - - - - - 54 8 62 62 - - - - - - - - - 714 1b.1.1.7 Incore instrumentation - - - - - - 54 8 62 62 - - - - - - - - - 714 1b.1.1.8 Reactor vessel - - - - - - 195 29 224 224 - - - - - - - - - 2,592 1b.1.1.9 Facility closeout - - - - - - 64 10 74 37 - 37 - - - - - - - 857 1b.1.1.10 Missile shields - - - - - - 24 4 28 28 - - - - - - - - - 321 1b.1.1.11 Biological shield - - - - - - 64 10 74 74 - - - - - - - - - 857 1b.1.1.12 Steam generators - - - - - - 247 37 284 284 - - - - - - - - - 3,284 1b.1.1.13 Reinforced concrete - - - - - - 54 8 62 31 - 31 - - - - - - - 714 1b.1.1.14 Main Turbine - - - - - - 84 13 96 - - 96 - - - - - - - 1,114 1b.1.1.15 Main Condensers - - - - - - 84 13 96 - - 96 - - - - - - - 1,114 1b.1.1.16 Auxiliary building - - - - - - 146 22 168 151 - 17 - - - - - - - 1,949 1b.1.1.17 Reactor building - - - - - - 146 22 168 151 - 17 - - - - - - - 1,949 1b.1.1 Total - - - - - - 1,782 267 2,049 1,664 - 385 - - - - - - - 23,736

1b.1.2 Decon primary loop 629 - - - - - - 314 943 943 - - - - - - - - 1,067 - 1b.1 Subtotal Period 1b Activity Costs 629 - - - - - 1,782 582 2,992 2,606 - 385 - - - - - - 1,067 23,736

Period 1b Additional Costs1b.2.1 Spent fuel pool isolation - - - - - - 7,040 1,056 8,096 8,096 - - - - - - - - - - 1b.2.2 Site Characterization - - - - - - 1,188 356 1,544 1,544 - - - - - - - - 8,167 3,357 1b.2 Subtotal Period 1b Additional Costs - - - - - - 8,228 1,412 9,641 9,641 - - - - - - - - 8,167 3,357

Period 1b Collateral Costs1b.3.1 Decon equipment 924 - - - - - - 139 1,062 1,062 - - - - - - - - - - 1b.3.2 Staff relocation expenses - - - - - - 1,130 169 1,299 1,299 - - - - - - - - - - 1b.3.3 Process decommissioning water waste 27 - 12 63 - 71 - 42 213 213 - - - 169 - - - 10,154 33 - 1b.3.4 Process decommissioning chemical flush waste 2 - 52 368 - 578 - 206 1,206 1,206 - - - - 781 - - 83,178 146 - 1b.3.5 Small tool allowance - 1 - - - - - 0 2 2 - - - - - - - - - - 1b.3.6 Pipe cutting equipment - 1,100 - - - - - 165 1,265 1,265 - - - - - - - - - - 1b.3.7 Decon rig 1,500 - - - - - - 225 1,725 1,725 - - - - - - - - - - 1b.3.8 Spent Fuel Capital and Transfer - - - - - - 729 109 838 - 838 - - - - - - - - - 1b.3 Subtotal Period 1b Collateral Costs 2,452 1,101 64 431 - 649 1,858 1,055 7,610 6,773 838 - - 169 781 - - 93,333 179 -

Period 1b Period-Dependent Costs1b.4.1 Decon supplies 28 - - - - - - 7 35 35 - - - - - - - - - - 1b.4.2 Insurance - - - - - - 615 61 676 676 - - - - - - - - - - 1b.4.3 Property taxes - - - - - - 2,558 256 2,814 2,814 - - - - - - - - - - 1b.4.4 Health physics supplies - 257 - - - - - 64 322 322 - - - - - - - - - - 1b.4.5 Heavy equipment rental - 281 - - - - - 42 323 323 - - - - - - - - - - 1b.4.6 Disposal of DAW generated - - 7 1 - 16 - 5 30 30 - - - 338 - - - 6,755 11 - 1b.4.7 Plant energy budget - - - - - - 733 110 843 843 - - - - - - - - - - 1b.4.8 NRC Fees - - - - - - 233 23 256 256 - - - - - - - - - - 1b.4.9 Emergency Planning Fees - - - - - - 305 30 335 - 335 - - - - - - - - - 1b.4.10 FEMA Fees - - - - - - 174 26 201 - 201 - - - - - - - - - 1b.4.11 Spent Fuel Pool O&M - - - - - - 390 59 449 - 449 - - - - - - - - - 1b.4.12 ISFSI Operating Costs - - - - - - 56 8 64 - 64 - - - - - - - - - 1b.4.13 Corporate A&G - - - - - - 1,458 219 1,676 1,676 - - - - - - - - - - 1b.4.14 Site O&M - - - - - - 131 20 151 151 - - - - - - - - - - 1b.4.15 Security Staff Cost - - - - - - 1,647 247 1,894 1,894 - - - - - - - - - 50,898 1b.4.16 Utility Staff Cost - - - - - - 14,560 2,184 16,744 16,744 - - - - - - - - - 243,880 1b.4 Subtotal Period 1b Period-Dependent Costs 28 538 7 1 - 16 22,859 3,362 26,811 25,763 1,048 - - 338 - - - 6,755 11 294,778

1b.0 TOTAL PERIOD 1b COST 3,109 1,639 71 432 - 665 34,727 6,411 47,054 44,782 1,886 385 - 507 781 - - 100,088 9,424 321,870

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PERIOD 1 TOTALS 3,109 2,672 84 434 - 694 85,753 13,784 106,531 100,551 5,316 664 - 1,100 781 - - 111,953 9,443 871,847



Nuclear Steam Supply System Removal2a.1.1.1 Reactor Coolant Piping 212 207 27 53 - 550 - 306 1,356 1,356 - - - 1,348 - - - 154,125 9,274 - 2a.1.1.2 Pressurizer Relief Tank 21 18 6 11 - 108 - 44 208 208 - - - 272 - - - 30,174 885 - 2a.1.1.3 Reactor Coolant Pumps & Motors 78 77 178 222 - 1,263 - 425 2,243 2,243 - - - 4,511 - - - 807,600 4,187 100 2a.1.1.4 Pressurizer 50 47 508 96 - 1,155 - 391 2,247 2,247 - - - 4,126 - - - 292,560 2,712 938 2a.1.1.5 Steam Generators 339 3,001 3,206 1,276 3,037 6,953 - 3,626 21,437 21,437 - - 39,289 24,841 - - - 3,652,669 23,234 2,125 2a.1.1.6 CRDMs/ICIs/Service Structure Removal 152 112 364 124 - 551 - 297 1,599 1,599 - - - 5,881 - - - 154,244 5,482 - 2a.1.1.7 Reactor Vessel Internals 93 3,535 11,824 1,290 - 5,523 324 8,786 31,376 31,376 - - - 2,003 934 344 - 334,323 32,217 1,421 2a.1.1.8 Reactor Vessel 93 6,655 2,411 1,575 - 2,939 324 7,553 21,550 21,550 - - - 9,265 - - - 950,439 32,217 1,421 2a.1.1 Totals 1,039 13,652 18,524 4,647 3,037 19,041 649 21,427 82,015 82,015 - - 39,289 52,248 934 344 - 6,376,133 110,207 6,004

Removal of Major Equipment2a.1.2 Main Turbine/Generator - 395 404 90 698 564 - 398 2,548 2,548 - - 4,726 2,632 - - - 457,489 9,495 - 2a.1.3 Main Condensers - 1,326 228 97 805 717 - 669 3,843 3,843 - - 7,274 3,038 - - - 528,161 32,740 -

Cascading Costs from Clean Building Demolition2a.1.4.1 Reactor - 508 - - - - - 76 584 584 - - - - - - - - 6,763 - 2a.1.4.2 AB - Battery & Cable Room (common) - 22 - - - - - 3 25 25 - - - - - - - - 295 - 2a.1.4.3 AB - FW Pump/Switchgear Area - 23 - - - - - 3 26 26 - - - - - - - - 299 - 2a.1.4.4 Auxiliary Building - 185 - - - - - 28 213 213 - - - - - - - - 2,409 - 2a.1.4.5 Auxiliary Service Building (common) - 101 - - - - - 15 116 116 - - - - - - - - 1,276 - 2a.1.4.6 Containment Mechanical Equipment - 6 - - - - - 1 7 7 - - - - - - - - 105 - 2a.1.4.7 Contaminated Materials Warehouse(common) - 23 - - - - - 3 26 26 - - - - - - - - 405 - 2a.1.4.8 Main Steam Doghouses - 100 - - - - - 15 115 115 - - - - - - - - 1,109 - 2a.1.4.9 Service Building (common) - 96 - - - - - 14 111 111 - - - - - - - - 1,607 - 2a.1.4.10 Turbine Building - 294 - - - - - 44 339 339 - - - - - - - - 4,856 - 2a.1.4.11 Upper Head Injection Tank Building - 5 - - - - - 1 6 6 - - - - - - - - 70 - 2a.1.4.12 Waste Solidification Facility (common) - 6 - - - - - 1 7 7 - - - - - - - - 78 - 2a.1.4.13 Fuel Building - 89 - - - - - 13 103 103 - - - - - - - - 1,173 - 2a.1.4 Totals - 1,458 - - - - - 219 1,677 1,677 - - - - - - - - 20,445 -

Disposal of Plant Systems2a.1.5.1 Aux Bldg Chilled Water - 89 2 3 109 - - 39 243 243 - - 1,094 - - - - 44,411 1,896 - 2a.1.5.2 Aux Bldg Rad Area Chilled Water (shared) - 119 3 5 166 - - 56 348 348 - - 1,663 - - - - 67,525 2,503 - 2a.1.5.3 Auxiliary Feedwater - 247 16 31 1,018 - - 221 1,532 1,532 - - 10,186 - - - - 413,660 5,567 - 2a.1.5.4 Auxiliary Steam - 19 - - - - - 3 22 - - 22 - - - - - - 564 - 2a.1.5.5 Auxiliary Steam RCA - 85 2 4 118 - - 40 248 248 - - 1,180 - - - - 47,930 1,840 - 2a.1.5.6 CCW Intake Screen Backwash - 5 - - - - - 1 6 - - 6 - - - - - - 142 - 2a.1.5.7 CO2 Gen Purge - 8 - - - - - 1 10 - - 10 - - - - - - 251 - 2a.1.5.8 Condensate - 369 - - - - - 55 424 - - 424 - - - - - - 10,260 - 2a.1.5.9 Condensate Storage - 75 - - - - - 11 86 - - 86 - - - - - - 2,003 - 2a.1.5.10 Condenser Cleaning - 40 - - - - - 6 46 - - 46 - - - - - - 1,125 - 2a.1.5.11 Condenser Steam Air Ejector - 34 - - - - - 5 40 - - 40 - - - - - - 996 - 2a.1.5.12 Containment Spray/Valve Inj Water - 234 5 10 339 - - 111 700 700 - - 3,389 - - - - 137,648 5,088 - 2a.1.5.13 Convent LP Service Water - 95 - - - - - 14 109 - - 109 - - - - - - 2,702 - 2a.1.5.14 Conventional Chemical Addition - 8 - - - - - 1 10 - - 10 - - - - - - 238 - 2a.1.5.15 Conventional Chemical Addition RCA - 15 0 0 11 - - 5 31 31 - - 109 - - - - 4,424 293 - 2a.1.5.16 Cooling Tower Water Treatment (shared) - 77 - - - - - 12 89 - - 89 - - - - - - 2,137 - 2a.1.5.17 DG Engine Cooling Water - 19 - - - - - 3 22 - - 22 - - - - - - 542 - 2a.1.5.18 DG Engine Fuel Oil - 67 - - - - - 10 77 - - 77 - - - - - - 1,753 - 2a.1.5.19 DG Engine Lube Oil - 36 - - - - - 5 41 - - 41 - - - - - - 998 - 2a.1.5.20 DG Engine Starting Air - 35 - - - - - 5 41 - - 41 - - - - - - 1,012 - 2a.1.5.21 DG Room Sump Pump - 6 - - - - - 1 7 - - 7 - - - - - - 175 - 2a.1.5.22 FDWP Condensate Seal - 22 - - - - - 3 25 - - 25 - - - - - - 632 - 2a.1.5.23 Feedwater - 54 - - - - - 8 62 - - 62 - - - - - - 1,527 - 2a.1.5.24 Feedwater Lube & Hydraulic Oil - 14 - - - - - 2 16 - - 16 - - - - - - 417 - 2a.1.5.25 Feedwater Pump Turbine Steam Seal - 3 - - - - - 0 3 - - 3 - - - - - - 80 - 2a.1.5.26 Feedwater RCA - 85 4 8 274 - - 64 436 436 - - 2,742 - - - - 111,348 1,971 - 2a.1.5.27 Generator Hydrogen - 7 - - - - - 1 8 - - 8 - - - - - - 217 - 2a.1.5.28 Generator Seal Oil - 11 - - - - - 2 12 - - 12 - - - - - - 312 - 2a.1.5.29 Heater Bleed Steam - 35 - - - - - 5 40 - - 40 - - - - - - 1,006 -

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Disposal of Plant Systems (continued)2a.1.5.30 Heater Drains - 135 - - - - - 20 155 - - 155 - - - - - - 3,866 - 2a.1.5.31 Heater Relief Valve - 20 - - - - - 3 23 - - 23 - - - - - - 525 - 2a.1.5.32 Heater Vent - 18 - - - - - 3 21 - - 21 - - - - - - 559 - 2a.1.5.33 Hydrogen Blanket & Bulk Storage (shared) - 15 - - - - - 2 17 - - 17 - - - - - - 436 - 2a.1.5.34 MN Turbine Lube Oil & Purification - 40 - - - - - 6 46 - - 46 - - - - - - 1,132 - 2a.1.5.35 Main Steam - 15 - - - - - 2 18 - - 18 - - - - - - 450 - 2a.1.5.36 Main Steam Bypass to Condenser - 27 - - - - - 4 31 - - 31 - - - - - - 784 - 2a.1.5.37 Main Steam Leakoff & Steam Seal - 9 - - - - - 1 10 - - 10 - - - - - - 249 - 2a.1.5.38 Main Steam RCA - 29 1 2 59 - - 16 107 107 - - 594 - - - - 24,127 614 - 2a.1.5.39 Main Steam Vent - 130 4 8 252 - - 72 465 465 - - 2,525 - - - - 102,559 2,942 - 2a.1.5.40 Main Vacuum (shared) - 11 - - - - - 2 12 - - 12 - - - - - - 291 - 2a.1.5.41 Makeup Demineralized Water (shared) - 108 - - - - - 16 124 - - 124 - - - - - - 3,097 - 2a.1.5.42 Miscellaneous Equipment - 1 - - - - - 0 1 - - 1 - - - - - - 18 - 2a.1.5.43 Moisture Separator Reheater Bld Steam - 5 - - - - - 1 6 - - 6 - - - - - - 156 - 2a.1.5.44 Moisture Separator Reheater Drain - 152 - - - - - 23 175 - - 175 - - - - - - 4,238 - 2a.1.5.45 Nitrogen (shared) - 13 - - - - - 2 15 - - 15 - - - - - - 402 - 2a.1.5.46 Recirculated Cooling Water (shared) - 138 - - - - - 21 159 - - 159 - - - - - - 3,964 - 2a.1.5.47 SG Wet Layup Recirculation - 21 0 1 17 - - 8 47 47 - - 174 - - - - 7,060 429 - 2a.1.5.48 SM Supply to Aux Equipment - 26 - - - - - 4 30 - - 30 - - - - - - 762 - 2a.1.5.49 SM Supply to Aux Equipment RCA - 10 0 0 10 - - 4 25 25 - - 100 - - - - 4,077 216 - 2a.1.5.50 Standby Shutdown Diesel - 6 - - - - - 1 7 - - 7 - - - - - - 158 - 2a.1.5.51 Steam Generator Blowdown Recycle - 312 46 57 631 373 - 279 1,697 1,697 - - 6,315 1,579 - - - 360,906 7,448 - 2a.1.5.52 Steam Supply to FW Pump Turbine - 26 - - - - - 4 29 - - 29 - - - - - - 743 - 2a.1.5.53 Turbine Crossover - 3 - - - - - 1 4 - - 4 - - - - - - 102 - 2a.1.5.54 Turbine Exhaust - 2 - - - - - 0 2 - - 2 - - - - - - 64 - 2a.1.5.55 Turbine Hydraulic Oil - 10 - - - - - 2 12 - - 12 - - - - - - 298 - 2a.1.5.56 Vacuum Priming (shared) - 18 - - - - - 3 21 - - 21 - - - - - - 519 - 2a.1.5 Totals - 3,215 83 129 3,004 373 - 1,191 7,995 5,881 - 2,115 30,071 1,579 - - - 1,325,675 82,713 -

2a.1.6 Scaffolding in support of decommissioning - 3,207 21 5 100 19 - 824 4,176 4,176 - - 901 79 - - - 45,817 35,092 -

2a.1 Subtotal Period 2a Activity Costs 1,039 23,253 19,260 4,968 7,643 20,714 649 24,729 102,254 100,140 - 2,115 82,262 59,576 934 344 - 8,733,275 290,692 6,004

Period 2a Additional Costs2a.2.1 Misc Waste Disposal - - 2 4 16 - - 3 25 25 - - 118 - - - - 7,404 101 - 2a.2.2 Remedial Action Surveys - - - - - - 1,708 512 2,220 2,220 - - - - - - - - 34,967 - 2a.2 Subtotal Period 2a Additional Costs - - 2 4 16 - 1,708 516 2,245 2,245 - - 118 - - - - 7,404 35,068 -

Period 2a Collateral Costs2a.3.1 Process decommissioning water waste 55 - 24 130 - 146 - 86 441 441 - - - 351 - - - 21,071 68 - 2a.3.3 Small tool allowance - 241 - - - - - 36 278 250 - 28 - - - - - - - - 2a.3.4 Spent Fuel Capital and Transfer - - - - - - 2,523 378 2,902 - 2,902 - - - - - - - - - 2a.3 Subtotal Period 2a Collateral Costs 55 241 24 130 - 146 2,523 501 3,621 691 2,902 28 - 351 - - - 21,071 68 -

Period 2a Period-Dependent Costs2a.4.1 Decon supplies 95 - - - - - - 24 119 119 - - - - - - - - - - 2a.4.2 Insurance - - - - - - 955 96 1,051 1,051 - - - - - - - - - - 2a.4.3 Property taxes - - - - - - 8,037 804 8,841 7,957 - 884 - - - - - - - - 2a.4.4 Health physics supplies - 2,262 - - - - - 566 2,828 2,828 - - - - - - - - - - 2a.4.5 Heavy equipment rental - 3,626 - - - - - 544 4,170 4,170 - - - - - - - - - - 2a.4.6 Disposal of DAW generated - - 102 16 - 232 - 71 421 421 - - - 4,759 - - - 95,175 155 - 2a.4.7 Plant energy budget - - - - - - 1,174 176 1,350 1,350 - - - - - - - - - - 2a.4.8 NRC Fees - - - - - - 736 74 809 809 - - - - - - - - - - 2a.4.9 Emergency Planning Fees - - - - - - 1,028 103 1,130 - 1,130 - - - - - - - - - 2a.4.10 Spent Fuel Pool O&M - - - - - - 1,317 198 1,514 - 1,514 - - - - - - - - - 2a.4.11 ISFSI Operating Costs - - - - - - 188 28 216 - 216 - - - - - - - - - 2a.4.12 Corporate A&G - - - - - - 4,299 645 4,943 4,943 - - - - - - - - - - 2a.4.13 Site O&M - - - - - - 453 68 521 521 - - - - - - - - - - 2a.4.14 Security Staff Cost - - - - - - 4,296 644 4,940 4,940 - - - - - - - - - 129,817 2a.4.15 Utility Staff Cost - - - - - - 43,697 6,554 50,251 50,251 - - - - - - - - - 719,257 2a.4 Subtotal Period 2a Period-Dependent Costs 95 5,888 102 16 - 232 66,177 10,593 83,103 79,359 2,860 884 - 4,759 - - - 95,175 155 849,074

2a.0 TOTAL PERIOD 2a COST 1,188 29,382 19,389 5,117 7,659 21,092 71,057 36,337 191,223 182,435 5,762 3,026 82,380 64,686 934 344 - 8,856,926 325,983 855,079

TLG Services, Inc.








Disposal of Plant Systems2b.1.1.1 Admin Bldg Chilled Water (shared) - 14 - - - - - 2 17 - - 17 - - - - - - 416 - 2b.1.1.2 Admin Bldg Ventilation (shared) - 6 - - - - - 1 7 - - 7 - - - - - - 181 - 2b.1.1.3 Annulus Ventilation - 37 3 5 120 16 - 32 214 214 - - 1,203 68 - - - 53,382 822 - 2b.1.1.4 Aux & RB Heating Water - 479 6 12 398 - - 182 1,077 1,077 - - 3,982 - - - - 161,718 10,064 - 2b.1.1.5 Aux Bldg Ventilation - 191 17 25 444 114 - 148 939 939 - - 4,440 484 - - - 212,275 4,483 - 2b.1.1.6 Boron Recycle 380 408 42 46 312 362 - 441 1,991 1,991 - - 3,121 1,557 - - - 228,203 17,577 - 2b.1.1.7 Boron Thermal Regeneration 215 290 40 42 113 383 - 303 1,385 1,385 - - 1,132 1,619 - - - 153,131 10,010 - 2b.1.1.8 Breathing Air (shared) - 154 2 3 104 - - 55 316 316 - - 1,037 - - - - 42,110 3,483 - 2b.1.1.9 Chemical & Volume Control 706 696 192 187 310 1,750 - 1,058 4,900 4,900 - - 3,103 7,418 - - - 616,225 26,771 - 2b.1.1.10 Comp Room Chilled Water (shared) - 46 - - - - - 7 53 - - 53 - - - - - - 1,295 - 2b.1.1.11 Component Cooling - 108 - - - - - 16 124 - - 124 - - - - - - 3,092 - 2b.1.1.12 Component Cooling RCA - 153 5 9 306 - - 86 560 560 - - 3,066 - - - - 124,493 3,199 - 2b.1.1.13 Computer Air Cond. (shared) - 25 2 4 130 - - 27 188 188 - - 1,296 - - - - 52,647 510 - 2b.1.1.14 Condenser Circulating Water - 98 - - - - - 15 113 - - 113 - - - - - - 2,781 - 2b.1.1.15 Cont Air Release & Addition - 42 4 4 23 34 - 24 131 131 - - 235 144 - - - 19,051 1,012 - 2b.1.1.16 Cont Air Return Ex & H2 Skimmer - 105 10 12 95 90 - 66 378 378 - - 955 382 - - - 64,092 2,533 - 2b.1.1.17 Cont CRD, & ICI Room Vent - 91 18 24 250 158 - 105 645 645 - - 2,502 671 - - - 145,963 2,203 - 2b.1.1.18 Cont Water Sample & Purge - 9 0 0 1 3 - 3 18 18 - - 10 14 - - - 1,303 242 - 2b.1.1.19 Containment Chilled Water - 26 - - - - - 4 30 - - 30 - - - - - - 712 - 2b.1.1.20 Containment Chilled Water RCA - 74 2 4 141 - - 41 262 262 - - 1,407 - - - - 57,124 1,665 - 2b.1.1.21 Containment Purge Ventilation - 179 23 33 484 178 - 169 1,066 1,066 - - 4,847 754 - - - 246,697 4,334 - 2b.1.1.22 Control Area Chilled Water (shared) - 314 6 12 396 - - 140 870 870 - - 3,969 - - - - 161,176 6,751 - 2b.1.1.23 Control Area HVAC (shared) - 72 6 12 383 - - 78 551 551 - - 3,834 - - - - 155,703 1,662 - 2b.1.1.24 Conventional Sampling - 371 36 29 46 270 - 175 926 926 - - 456 1,138 - - - 94,041 8,828 - 2b.1.1.25 Conventional Waste Mont & Treat (shared) - 90 - - - - - 13 103 - - 103 - - - - - - 2,469 - 2b.1.1.26 Convntl Waste Mont & Treat (shared) RCA - 227 6 12 390 - - 118 753 753 - - 3,901 - - - - 158,411 5,082 - 2b.1.1.27 Diesel Bldg Ventilation - 9 - - - - - 1 10 - - 10 - - - - - - 254 - 2b.1.1.28 Drinking Water (shared) - 48 - - - - - 7 55 - - 55 - - - - - - 1,400 - 2b.1.1.29 Electrical (clean) - 2,774 - - - - - 416 3,190 - - 3,190 - - - - - - 73,972 - 2b.1.1.30 Electrical (contaminated) - 935 60 76 429 619 - 470 2,590 2,590 - - 4,297 2,624 - - - 347,958 21,756 - 2b.1.1.31 Electrical (contaminated) RCA - 5,861 113 216 7,143 - - 2,581 15,915 15,915 - - 71,504 - - - - 2,903,830 129,195 - 2b.1.1.32 Equipment Decon - 34 2 3 25 19 - 18 101 101 - - 255 81 - - - 15,749 803 - 2b.1.1.33 Filtered Water (shared) - 68 - - - - - 10 79 - - 79 - - - - - - 1,811 - 2b.1.1.34 Filtered Water (shared) RCA - 29 1 1 41 - - 14 85 85 - - 412 - - - - 16,721 637 - 2b.1.1.35 Fire Protection - 45 - - - - - 7 51 - - 51 - - - - - - 1,274 - 2b.1.1.36 Fire Protection (shared) - 413 - - - - - 62 475 - - 475 - - - - - - 11,816 - 2b.1.1.37 Fire Protection RCA - 128 4 7 238 - - 69 447 447 - - 2,383 - - - - 96,755 2,919 - 2b.1.1.38 Gaseous Waste Management (shared) - 277 31 30 168 246 - 164 916 916 - - 1,684 1,051 - - - 137,306 6,462 - 2b.1.1.39 Groundwater Drainage (shared) - 22 - - - - - 3 25 - - 25 - - - - - - 591 - 2b.1.1.40 Heating Boiler Feedwater (shared) - 52 - - - - - 8 60 - - 60 - - - - - - 1,454 - 2b.1.1.41 Ice Condenser Refrigeration - 502 13 26 851 - - 258 1,651 1,651 - - 8,522 - - - - 346,098 11,241 - 2b.1.1.42 Instrument Air - 203 - - - - - 30 234 - - 234 - - - - - - 6,051 - 2b.1.1.43 Instrument Air RCA - 728 9 17 566 - - 270 1,590 1,590 - - 5,663 - - - - 229,971 15,129 - 2b.1.1.44 Liquid Waste Recycle 720 921 125 124 212 1,159 - 943 4,202 4,202 - - 2,119 4,933 - - - 410,643 35,405 - 2b.1.1.45 Miscellaneous Ventilation - 46 - - - - - 7 52 - - 52 - - - - - - 1,469 - 2b.1.1.46 Nuclear Prod Office Chilled Water (shrd) - 23 - - - - - 3 27 - - 27 - - - - - - 681 - 2b.1.1.47 Nuclear Sampling - 300 26 20 27 185 - 131 688 688 - - 275 779 - - - 62,886 7,275 - 2b.1.1.48 Nuclear Service Water - 67 - - - - - 10 77 - - 77 - - - - - - 1,898 - 2b.1.1.49 Nuclear Service Water Pump Vent - 1 - - - - - 0 1 - - 1 - - - - - - 31 - 2b.1.1.50 Nuclear Service Water RCA - 519 18 35 1,165 - - 312 2,050 2,050 - - 11,665 - - - - 473,732 11,623 - 2b.1.1.51 Nuclear Solid Waste Disposal (shared) 223 272 39 39 94 357 - 292 1,316 1,316 - - 940 1,529 - - - 138,209 11,188 - 2b.1.1.52 Oxygen (shared) - 4 - - - - - 1 5 - - 5 - - - - - - 124 - 2b.1.1.53 Reactor Coolant - 125 38 45 91 419 - 160 878 878 - - 915 1,774 - - - 154,412 3,104 - 2b.1.1.54 Refueling Water - 328 20 27 449 135 - 189 1,149 1,149 - - 4,494 577 - - - 220,287 7,907 - 2b.1.1.55 Residual Heat Removal 166 155 33 34 48 320 - 217 974 974 - - 484 1,354 - - - 109,275 5,079 - 2b.1.1.56 Safety Injection - 465 110 112 493 960 - 458 2,598 2,598 - - 4,938 4,074 - - - 469,341 11,174 - 2b.1.1.57 Sanitation & Waste Treatment (shared) - 31 - - - - - 5 35 - - 35 - - - - - - 887 - 2b.1.1.58 Service Bldg & Warehouse Vent (shared) - 49 - - - - - 7 56 - - 56 - - - - - - 1,508 - 2b.1.1.59 Service Bldg Chilled Water (shared) - 40 - - - - - 6 46 - - 46 - - - - - - 1,165 - 2b.1.1.60 Station Air (shared) - 23 - - - - - 4 27 - - 27 - - - - - - 685 - 2b.1.1.61 Station Air (shared) RCA - 274 3 6 214 - - 102 599 599 - - 2,140 - - - - 86,897 5,628 - 2b.1.1.62 TB & Service Bldg Sump & Drains (shared) - 45 - - - - - 7 52 - - 52 - - - - - - 1,261 -

TLG Services, Inc.






Disposal of Plant Systems (continued)2b.1.1.63 Tech Support Center Vent (shared) - 5 - - - - - 1 6 - - 6 - - - - - - 145 - 2b.1.1.64 Turbine Building Ventilation - 101 - - - - - 15 116 - - 116 - - - - - - 3,108 - 2b.1.1 Totals 2,410 20,229 1,067 1,293 16,702 7,777 - 10,567 60,045 54,919 - 5,125 167,186 33,025 - - - 8,967,818 520,289 -

2b.1.2 Scaffolding in support of decommissioning - 4,009 27 6 125 23 - 1,030 5,220 5,220 - - 1,127 99 - - - 57,272 43,864 -

Decontamination of Site Buildings2b.1.3.1 Reactor 1,129 847 47 291 949 1,402 - 1,317 5,982 5,982 - - 9,498 10,936 - - - 1,073,947 42,524 - 2b.1.3.2 Auxiliary Building 518 277 11 130 83 216 - 415 1,651 1,651 - - 833 3,640 - - - 347,692 17,873 - 2b.1.3.3 Auxiliary Service Building (common) 32 14 1 4 13 7 - 24 93 93 - - 126 108 - - - 14,015 1,077 - 2b.1.3.4 Containment Mechanical Equipment 23 20 1 5 12 9 - 21 91 91 - - 122 147 - - - 17,328 964 - 2b.1.3.5 Contaminated Materials Warehouse(common) 71 31 1 18 - 30 - 54 206 206 - - - 518 - - - 44,850 2,293 - 2b.1.3.6 Monitor Tank Building (common) 86 7 0 3 - 4 - 46 146 146 - - - 73 - - - 6,354 2,261 - 2b.1.3.7 RMC Bldg - New Structure 4 16 0 6 - 10 - 9 46 46 - - - 177 - - - 15,300 399 - 2b.1.3.8 Waste Solidification Facility (common) 14 11 1 4 9 6 - 13 58 58 - - 93 100 - - - 12,151 573 - 2b.1.3 Totals 1,877 1,222 62 461 1,066 1,686 - 1,901 8,274 8,274 - - 10,672 15,698 - - - 1,531,637 67,964 -


Period 2b Additional Costs2b.2.1 Landfill and Firing Range Closure - - - - - - 1,203 180 1,384 - - 1,384 - - - - - - - - 2b.2.2 Pond Closure - - - - - - 3,341 501 3,842 - - 3,842 - - - - - - 9,285 - 2b.2.3 RP Storage Tent Asphalt Disposal - 6 1 61 - 172 - 54 293 293 - - - 2,925 - - - 351,000 135 - 2b.2.4 Underground Services Excavation - 1,955 - - - - 835 419 3,209 - - 3,209 - - - - - - 14,000 - 2b.2.5 Remedial Action Surveys - - - - - - 2,358 708 3,066 3,066 - - - - - - - - 48,286 - 2b.2 Subtotal Period 2b Additional Costs - 1,961 1 61 - 172 7,738 1,861 11,793 3,359 - 8,434 - 2,925 - - - 351,000 71,705 -

Period 2b Collateral Costs2b.3.1 Process decommissioning water waste 154 - 71 376 - 424 - 246 1,271 1,271 - - - 1,016 - - - 60,983 198 - 2b.3.2 Process decommissioning chemical flush waste 4 - 137 968 - 1,519 - 540 3,168 3,168 - - - 2,050 - - - 218,492 384 - 2b.3.3 Small tool allowance - 436 - - - - - 65 502 502 - - - - - - - - - - 2b.3.4 Spent Fuel Capital and Transfer - - - - - - 3,480 522 4,002 - 4,002 - - - - - - - - - 2b.3 Subtotal Period 2b Collateral Costs 158 436 208 1,344 - 1,942 3,480 1,374 8,943 4,941 4,002 - - 3,067 - - - 279,475 582 -

Period 2b Period-Dependent Costs2b.4.1 Decon supplies 965 - - - - - - 241 1,207 1,207 - - - - - - - - - - 2b.4.2 Insurance - - - - - - 1,319 132 1,451 1,451 - - - - - - - - - - 2b.4.3 Property taxes - - - - - - 7,697 770 8,466 8,466 - - - - - - - - - - 2b.4.4 Health physics supplies - 4,200 - - - - - 1,050 5,251 5,251 - - - - - - - - - - 2b.4.5 Heavy equipment rental - 4,958 - - - - - 744 5,701 5,701 - - - - - - - - - - 2b.4.6 Disposal of DAW generated - - 173 27 - 392 - 119 711 711 - - - 8,039 - - - 160,788 262 - 2b.4.7 Plant energy budget - - - - - - 1,280 192 1,472 1,472 - - - - - - - - - - 2b.4.8 NRC Fees - - - - - - 1,016 102 1,118 1,118 - - - - - - - - - - 2b.4.9 Emergency Planning Fees - - - - - - 1,419 142 1,561 - 1,561 - - - - - - - - - 2b.4.10 Spent Fuel Pool O&M - - - - - - 1,818 273 2,091 - 2,091 - - - - - - - - - 2b.4.11 Liquid Radwaste Processing Equipment/Services - - - - - - 461 69 530 530 - - - - - - - - - - 2b.4.12 ISFSI Operating Costs - - - - - - 259 39 298 - 298 - - - - - - - - - 2b.4.13 Corporate A&G - - - - - - 5,010 752 5,762 5,762 - - - - - - - - - - 2b.4.14 Site O&M - - - - - - 528 79 607 607 - - - - - - - - - - 2b.4.15 Security Staff Cost - - - - - - 5,933 890 6,823 6,823 - - - - - - - - - 179,291 2b.4.16 Utility Staff Cost - - - - - - 50,738 7,611 58,348 58,348 - - - - - - - - - 838,309 2b.4 Subtotal Period 2b Period-Dependent Costs 965 9,158 173 27 - 392 77,478 13,204 101,397 97,447 3,950 - - 8,039 - - - 160,788 262 1,017,600

2b.0 TOTAL PERIOD 2b COST 5,410 37,015 1,537 3,192 17,893 11,992 88,696 29,937 195,672 174,160 7,953 13,560 178,985 62,853 - - - 11,347,990 704,667 1,017,600

PERIOD 2c - Spent fuel delay prior to SFP decon


Period 2c Additional Costs2c.2.1 Landfill Post Closure Maintenance - - - - - - 184 28 212 - - 212 - - - - - - - - 2c.2 Subtotal Period 2c Additional Costs - - - - - - 184 28 212 - - 212 - - - - - - - -

Period 2c Collateral Costs2c.3.1 Spent Fuel Capital and Transfer - - - - - - 7,114 1,067 8,181 - 8,181 - - - - - - - - - 2c.3 Subtotal Period 2c Collateral Costs - - - - - - 7,114 1,067 8,181 - 8,181 - - - - - - - - -

TLG Services, Inc.






Period 2c Period-Dependent Costs2c.4.1 Insurance - - - - - - 2,598 260 2,857 2,857 - - - - - - - - - - 2c.4.2 Property taxes - - - - - - 3,846 385 4,231 4,231 - - - - - - - - - - 2c.4.3 Health physics supplies - 1,589 - - - - - 397 1,986 1,986 - - - - - - - - - - 2c.4.4 Disposal of DAW generated - - 39 6 - 89 - 27 162 162 - - - 1,830 - - - 36,596 60 - 2c.4.5 Plant energy budget - - - - - - 672 101 773 773 - - - - - - - - - - 2c.4.6 NRC Fees - - - - - - 1,243 124 1,368 1,368 - - - - - - - - - - 2c.4.7 Emergency Planning Fees - - - - - - 2,795 279 3,074 - 3,074 - - - - - - - - - 2c.4.8 Spent Fuel Pool O&M - - - - - - 3,581 537 4,118 - 4,118 - - - - - - - - - 2c.4.9 ISFSI Operating Costs - - - - - - 510 77 587 - 587 - - - - - - - - - 2c.4.10 Corporate A&G - - - - - - 1,654 248 1,902 1,902 - - - - - - - - - - 2c.4.11 Site O&M - - - - - - 174 26 200 200 - - - - - - - - - - 2c.4.12 Security Staff Cost - - - - - - 9,458 1,419 10,877 10,877 - - - - - - - - - 279,129 2c.4.13 Utility Staff Cost - - - - - - 16,780 2,517 19,297 19,297 - - - - - - - - - 276,743 2c.4 Subtotal Period 2c Period-Dependent Costs - 1,589 39 6 - 89 43,311 6,397 51,432 43,653 7,779 - - 1,830 - - - 36,596 60 555,871

2c.0 TOTAL PERIOD 2c COST - 1,589 39 6 - 89 50,609 7,492 59,825 43,653 15,960 212 - 1,830 - - - 36,596 60 555,871

PERIOD 2d - Decontamination Following Wet Fuel Storage

Period 2d Direct Decommissioning Activities2d.1.1 Remove spent fuel racks 362 36 167 90 - 885 - 441 1,980 1,980 - - - 3,751 - - - 247,922 1,033 -

Disposal of Plant Systems2d.1.2.1 FHB Ventilation - 72 7 12 298 33 - 73 496 496 - - 2,985 138 - - - 130,319 1,642 - 2d.1.2.2 Spent Fuel Cooling 158 219 28 28 70 253 - 214 968 968 - - 701 1,069 - - - 99,253 7,624 - 2d.1.2 Totals 158 291 35 40 368 285 - 288 1,464 1,464 - - 3,685 1,207 - - - 229,572 9,266 -

Decontamination of Site Buildings2d.1.3.1 Fuel Building 785 871 11 37 339 71 - 685 2,799 2,799 - - 3,393 828 - - - 206,666 37,665 - 2d.1.3 Totals 785 871 11 37 339 71 - 685 2,799 2,799 - - 3,393 828 - - - 206,666 37,665 -

2d.1.4 Scaffolding in support of decommissioning - 802 5 1 25 5 - 206 1,044 1,044 - - 225 20 - - - 11,454 8,773 -

2d.1 Subtotal Period 2d Activity Costs 1,304 1,999 218 167 732 1,246 - 1,620 7,287 7,287 - - 7,303 5,806 - - - 695,615 56,737 -

Period 2d Additional Costs2d.2.1 License Termination Survey Planning - - - - - - 830 249 1,079 1,079 - - - - - - - - - 6,240 2d.2.2 Landfill Post Closure Maintenance - - - - - - 15 2 17 - - 17 - - - - - - - - 2d.2.3 Remedial Action Surveys - - - - - - 370 111 481 481 - - - - - - - - 7,574 - 2d.2 Subtotal Period 2d Additional Costs - - - - - - 1,214 362 1,576 1,560 - 17 - - - - - - 7,574 6,240

Period 2d Collateral Costs2d.3.1 Process decommissioning water waste 62 - 31 163 - 184 - 105 545 545 - - - 441 - - - 26,473 86 - 2d.3.2 Process decommissioning chemical flush waste 0 - 12 84 - 132 - 47 275 275 - - - 178 - - - 18,996 33 - 2d.3.3 Small tool allowance - 48 - - - - - 7 55 55 - - - - - - - - - - 2d.3.4 Decommissioning Equipment Disposition - - 141 37 664 125 - 151 1,118 1,118 - - 6,000 529 - - - 304,968 88 - 2d.3 Subtotal Period 2d Collateral Costs 62 48 184 285 664 441 - 309 1,993 1,993 - - 6,000 1,149 - - - 350,437 208 -

Period 2d Period-Dependent Costs2d.4.1 Decon supplies 160 - - - - - - 40 200 200 - - - - - - - - - - 2d.4.2 Insurance - - - - - - 207 21 228 228 - - - - - - - - - - 2d.4.3 Property taxes - - - - - - 9 1 10 10 - - - - - - - - - - 2d.4.4 Health physics supplies - 438 - - - - - 109 547 547 - - - - - - - - - - 2d.4.5 Heavy equipment rental - 778 - - - - - 117 894 894 - - - - - - - - - - 2d.4.6 Disposal of DAW generated - - 32 5 - 74 - 22 134 134 - - - 1,511 - - - 30,213 49 - 2d.4.7 Plant energy budget - - - - - - 107 16 123 123 - - - - - - - - - - 2d.4.8 NRC Fees - - - - - - 134 13 148 148 - - - - - - - - - - 2d.4.9 Emergency Planning Fees - - - - - - 223 22 245 - 245 - - - - - - - - - 2d.4.10 Liquid Radwaste Processing Equipment/Services - - - - - - 145 22 166 166 - - - - - - - - - - 2d.4.11 ISFSI Operating Costs - - - - - - 41 6 47 - 47 - - - - - - - - - 2d.4.12 Corporate A&G - - - - - - 518 78 595 595 - - - - - - - - - - 2d.4.13 Site O&M - - - - - - 55 8 63 63 - - - - - - - - - - 2d.4.14 Security Staff Cost - - - - - - 499 75 574 574 - - - - - - - - - 13,779 2d.4.15 Utility Staff Cost - - - - - - 5,306 796 6,102 6,102 - - - - - - - - - 86,640 2d.4 Subtotal Period 2d Period-Dependent Costs 160 1,215 32 5 - 74 7,243 1,346 10,076 9,784 292 - - 1,511 - - - 30,213 49 100,419

TLG Services, Inc.






2d.0 TOTAL PERIOD 2d COST 1,526 3,262 434 457 1,396 1,761 8,458 3,638 20,932 20,623 292 17 13,303 8,465 - - - 1,076,265 64,568 106,659



Period 2f Additional Costs2f.2.1 License Termination Survey - - - - - - 9,045 2,714 11,759 11,759 - - - - - - - - 207,436 3,120 2f.2.2 Landfill Post Closure Maintenance - - - - - - 30 5 35 - - 35 - - - - - - - - 2f.2 Subtotal Period 2f Additional Costs - - - - - - 9,076 2,718 11,794 11,759 - 35 - - - - - - 207,436 3,120


Period 2f Period-Dependent Costs2f.4.1 Insurance - - - - - - 392 39 431 431 - - - - - - - - - - 2f.4.2 Property taxes - - - - - - 19 2 21 21 - - - - - - - - - - 2f.4.3 Health physics supplies - 845 - - - - - 211 1,056 1,056 - - - - - - - - - - 2f.4.4 Disposal of DAW generated - - 7 1 - 16 - 5 29 29 - - - 332 - - - 6,639 11 - 2f.4.5 Plant energy budget - - - - - - 111 17 127 127 - - - - - - - - - - 2f.4.6 NRC Fees - - - - - - 304 30 335 335 - - - - - - - - - - 2f.4.7 Emergency Planning Fees - - - - - - 460 46 506 - 506 - - - - - - - - - 2f.4.8 ISFSI Operating Costs - - - - - - 84 13 97 - 97 - - - - - - - - - 2f.4.9 Corporate A&G - - - - - - 589 88 678 678 - - - - - - - - - - 2f.4.10 Site O&M - - - - - - 62 9 71 71 - - - - - - - - - - 2f.4.11 Security Staff Cost - - - - - - 1,014 152 1,166 1,166 - - - - - - - - - 27,893 2f.4.12 Utility Staff Cost - - - - - - 6,335 950 7,285 7,285 - - - - - - - - - 98,607 2f.4 Subtotal Period 2f Period-Dependent Costs - 845 7 1 - 16 9,370 1,563 11,802 11,199 603 - - 332 - - - 6,639 11 126,500

2f.0 TOTAL PERIOD 2f COST - 845 7 1 - 16 19,736 4,499 25,104 24,467 603 35 - 332 - - - 6,639 207,446 129,620

PERIOD 2 TOTALS 8,124 72,094 21,407 8,773 26,948 34,950 238,557 81,903 492,756 445,338 30,569 16,850 274,669 138,166 934 344 - 21,324,410 1,302,724 2,664,829



Demolition of Remaining Site Buildings3b.1.1.1 Reactor - 2,883 - - - - - 432 3,316 - - 3,316 - - - - - - 38,439 - 3b.1.1.2 AB - Battery & Cable Room (common) - 204 - - - - - 31 235 - - 235 - - - - - - 2,772 - 3b.1.1.3 AB - FW Pump/Switchgear Area - 208 - - - - - 31 239 - - 239 - - - - - - 2,750 - 3b.1.1.4 Administration Building (common) - 246 - - - - - 37 283 - - 283 - - - - - - 4,366 - 3b.1.1.5 Auxiliary Building - 1,692 - - - - - 254 1,946 - - 1,946 - - - - - - 22,370 - 3b.1.1.6 Auxiliary Service Building (common) - 917 - - - - - 138 1,055 - - 1,055 - - - - - - 11,789 - 3b.1.1.7 Containment Mechanical Equipment - 59 - - - - - 9 67 - - 67 - - - - - - 1,085 - 3b.1.1.8 Contaminated Materials Warehouse(common) - 263 - - - - - 40 303 - - 303 - - - - - - 5,478 - 3b.1.1.9 Cooling Towers (3) - 2,246 - - - - - 337 2,583 - - 2,583 - - - - - - 34,180 - 3b.1.1.10 Diesel Generator Building - 332 - - - - - 50 382 - - 382 - - - - - - 4,152 - 3b.1.1.11 Lagoons & Yard Basins (common) - 202 - - - - - 30 232 - - 232 - - - - - - 3,401 - 3b.1.1.12 Low Pressure Service Water (common) - 280 - - - - - 42 322 - - 322 - - - - - - 3,570 - 3b.1.1.13 Main Steam Doghouses - 905 - - - - - 136 1,041 - - 1,041 - - - - - - 10,075 - 3b.1.1.14 Misc Structures - New Additions - 107 - - - - - 16 123 - - 123 - - - - - - 1,368 - 3b.1.1.15 Miscellaneous Structures (common) - 4,984 - - - - - 748 5,732 - - 5,732 - - - - - - 74,828 - 3b.1.1.16 Monitor Tank Building (common) - 369 - - - - - 55 424 - - 424 - - - - - - 6,276 - 3b.1.1.17 Nuc.Sevice Water Struct/Piping (common) - 1,102 - - - - - 165 1,267 - - 1,267 - - - - - - 7,798 - 3b.1.1.18 RMC Bldg - New Structure - 116 - - - - - 17 134 - - 134 - - - - - - 1,478 - 3b.1.1.19 Service Building (common) - 980 - - - - - 147 1,127 - - 1,127 - - - - - - 18,025 - 3b.1.1.20 Standby Shutdown Facility (common) - 57 - - - - - 9 65 - - 65 - - - - - - 954 - 3b.1.1.21 Steam Generator Drain Tank Bldg (common) - 50 - - - - - 7 57 - - 57 - - - - - - 896 - 3b.1.1.22 Turbine Building - 2,800 - - - - - 420 3,220 - - 3,220 - - - - - - 47,944 - 3b.1.1.23 Turbine Pedestal - 693 - - - - - 104 796 - - 796 - - - - - - 7,683 - 3b.1.1.24 Upper Head Injection Tank Building - 44 - - - - - 7 50 - - 50 - - - - - - 633 - 3b.1.1.25 Waste Solidification Facility (common) - 56 - - - - - 8 65 - - 65 - - - - - - 800 -

TLG Services, Inc.






Demolition of Remaining Site Buildings (continued)3b.1.1.26 Fuel Building - 824 - - - - - 124 947 - - 947 - - - - - - 11,073 - 3b.1.1 Totals - 22,619 - - - - - 3,393 26,012 - - 26,012 - - - - - - 324,179 -

Site Closeout Activities3b.1.2 BackFill Site - 13,358 - - - - - 2,004 15,362 - - 15,362 - - - - - - 23,118 - 3b.1.3 Grade & landscape site - 304 - - - - - 46 349 - - 349 - - - - - - 631 - 3b.1.4 Final report to NRC - - - - - - 84 13 96 96 - - - - - - - - - 1,114 3b.1 Subtotal Period 3b Activity Costs - 36,281 - - - - 84 5,455 41,820 96 - 41,724 - - - - - - 347,928 1,114

Period 3b Additional Costs3b.2.1 Concrete Crushing - 977 - - - - 6 148 1,131 - - 1,131 - - - - - - 4,716 - 3b.2.2 Landfill Post Closure Maintenance - - - - - - 66 10 76 - - 76 - - - - - - - - 3b.2 Subtotal Period 3b Additional Costs - 977 - - - - 72 157 1,207 - - 1,207 - - - - - - 4,716 -


Period 3b Period-Dependent Costs3b.4.1 Insurance - - - - - - 859 86 944 - 944 - - - - - - - - - 3b.4.2 Property taxes - - - - - - 41 4 45 - 45 - - - - - - - - - 3b.4.3 Heavy equipment rental - 5,027 - - - - - 754 5,781 - - 5,781 - - - - - - - - 3b.4.4 Plant energy budget - - - - - - 121 18 139 - - 139 - - - - - - - - 3b.4.5 NRC ISFSI Fees - - - - - - 429 43 472 - 472 - - - - - - - - - 3b.4.6 Emergency Planning Fees - - - - - - 1,007 101 1,108 - 1,108 - - - - - - - - - 3b.4.7 ISFSI Operating Costs - - - - - - 184 28 211 - 211 - - - - - - - - - 3b.4.8 Security Staff Cost - - - - - - 2,128 319 2,447 - 2,105 343 - - - - - - - 58,067 3b.4.9 Utility Staff Cost - - - - - - 8,899 1,335 10,234 (0) 1,228 9,006 - - - - - - - 142,347 3b.4 Subtotal Period 3b Period-Dependent Costs - 5,027 - - - - 13,668 2,688 21,383 (0) 6,114 15,270 - - - - - - - 200,414

3b.0 TOTAL PERIOD 3b COST - 42,536 - - - - 14,708 8,470 65,714 96 6,114 59,504 - - - - - - 352,643 201,528

PERIOD 3c - Fuel Storage Operations/Shipping



Period 3c Collateral Costs3c.3.1 Spent Fuel Capital and Transfer - - - - - - 5,438 816 6,253 - 6,253 - - - - - - - - - 3c.3 Subtotal Period 3c Collateral Costs - - - - - - 5,438 816 6,253 - 6,253 - - - - - - - - -

Period 3c Period-Dependent Costs3c.4.1 Insurance - - - - - - 5,311 531 5,843 - 5,843 - - - - - - - - - 3c.4.2 Property taxes - - - - - - 508 51 559 - 559 - - - - - - - - - 3c.4.4 NRC ISFSI Fees - - - - - - 3,742 374 4,116 - 4,116 - - - - - - - - - 3c.4.5 Emergency Planning Fees - - - - - - 12,465 1,246 13,711 - 13,711 - - - - - - - - - 3c.4.6 ISFSI Operating Costs - - - - - - 1,138 171 1,308 - 1,308 - - - - - - - - - 3c.4.7 Corporate A&G - - - - - - 858 129 987 - 987 - - - - - - - - - 3c.4.8 Site O&M - - - - - - 32 5 37 - 37 - - - - - - - - - 3c.4.9 Security Staff Cost - - - - - - 22,007 3,301 25,308 - 25,308 - - - - - - - - 574,560 3c.4.10 Utility Staff Cost - - - - - - 9,031 1,355 10,385 - 10,385 - - - - - - - - 143,640 3c.4 Subtotal Period 3c Period-Dependent Costs - - - - - - 55,092 7,162 62,254 - 62,254 - - - - - - - - 718,200

3c.0 TOTAL PERIOD 3c COST - - - - - - 60,940 8,040 68,980 - 68,508 472 - - - - - - - 718,200

TLG Services, Inc.






PERIOD 3d - GTCC shipping

Period 3d Direct Decommissioning Activities

Nuclear Steam Supply System Removal3d.1.1.1 Vessel & Internals GTCC Disposal - - 875 - - 14,307 - 2,234 17,415 17,415 - - - - - - 2,499 500,800 - - 3d.1.1 Totals - - 875 - - 14,307 - 2,234 17,415 17,415 - - - - - - 2,499 500,800 - - 3d.1 Subtotal Period 3d Activity Costs - - 875 - - 14,307 - 2,234 17,415 17,415 - - - - - - 2,499 500,800 - -

Period 3d Period-Dependent Costs3d.4.1 Insurance - - - - - - 20 2 22 - 22 - - - - - - - - - 3d.4.2 Property taxes - - - - - - 2 0 2 - 2 - - - - - - - - - 3d.4.4 NRC ISFSI Fees - - - - - - 10 1 11 - 11 - - - - - - - - - 3d.4.5 Emergency Planning Fees - - - - - - 47 5 52 - 52 - - - - - - - - - 3d.4.6 ISFSI Operating Costs - - - - - - 4 1 5 - 5 - - - - - - - - - 3d.4.7 Corporate A&G - - - - - - 3 0 4 - 4 - - - - - - - - - 3d.4.8 Security Staff Cost - - - - - - 83 12 95 - 95 - - - - - - - - 2,160 3d.4.9 Utility Staff Cost - - - - - - 34 5 39 - 39 - - - - - - - - 540 3d.4 Subtotal Period 3d Period-Dependent Costs - - - - - - 203 26 229 - 229 - - - - - - - - 2,700

3d.0 TOTAL PERIOD 3d COST - - 875 - - 14,307 203 2,260 17,645 17,415 229 - - - - - 2,499 500,800 - 2,700

PERIOD 3e - ISFSI Decontamination

Period 3e Direct Decommissioning Activities

Period 3e Additional Costs3e.2.1 Decommissioning of ISFSI - 357 236 403 - 2,438 1,779 1,303 6,516 6,516 - - - 10,462 - - - 699,382 13,466 1,872 3e.2 Subtotal Period 3e Additional Costs - 357 236 403 - 2,438 1,779 1,303 6,516 6,516 - - - 10,462 - - - 699,382 13,466 1,872

Period 3e Period-Dependent Costs3e.4.1 Insurance - - - - - - 82 20 102 102 - - - - - - - - - - 3e.4.2 Property taxes - - - - - - 17 4 21 21 - - - - - - - - - - 3e.4.3 Heavy equipment rental - 284 - - - - - 71 355 355 - - - - - - - - - - 3e.4.4 Plant energy budget - - - - - - 25 6 31 31 - - - - - - - - - - 3e.4.5 Corporate A&G - - - - - - 23 6 29 29 - - - - - - - - - - 3e.4.6 Site O&M - - - - - - 1 0 1 1 - - - - - - - - - - 3e.4.7 Security Staff Cost - - - - - - 198 50 248 248 - - - - - - - - - 5,096 3e.4.8 Utility Staff Cost - - - - - - 246 61 307 307 - - - - - - - - - 3,866 3e.4 Subtotal Period 3e Period-Dependent Costs - 284 - - - - 591 219 1,094 1,094 - - - - - - - - - 8,961

3e.0 TOTAL PERIOD 3e COST - 641 236 403 - 2,438 2,370 1,522 7,610 7,610 - - - 10,462 - - - 699,382 13,466 10,833

PERIOD 3f - ISFSI Site Restoration

Period 3f Direct Decommissioning Activities

Period 3f Additional Costs3f.2.1 Demolition of ISFSI - 902 - - - - 54 143 1,100 - - 1,100 - - - - - - 1,533 160 3f.2 Subtotal Period 3f Additional Costs - 902 - - - - 54 143 1,100 - - 1,100 - - - - - - 1,533 160

Period 3f Collateral Costs3f.3.1 Small tool allowance - 15 - - - - - 2 17 - - 17 - - - - - - - - 3f.3 Subtotal Period 3f Collateral Costs - 15 - - - - - 2 17 - - 17 - - - - - - - -

Period 3f Period-Dependent Costs3f.4.1 Insurance - - - - - - 40 4 44 - - 44 - - - - - - - - 3f.4.2 Property taxes - - - - - - 8 1 9 - - 9 - - - - - - - - 3f.4.3 Heavy equipment rental - 114 - - - - - 17 131 - - 131 - - - - - - - - 3f.4.4 Plant energy budget - - - - - - 12 2 14 - - 14 - - - - - - - - 3f.4.5 Corporate A&G - - - - - - 9 1 11 - - 11 - - - - - - - - 3f.4.6 Security Staff Cost - - - - - - 98 15 113 - - 113 - - - - - - - 2,527 3f.4.7 Utility Staff Cost - - - - - - 103 15 118 - - 118 - - - - - - - 1,569 3f.4 Subtotal Period 3f Period-Dependent Costs - 114 - - - - 272 55 441 - - 441 - - - - - - - 4,096

3f.0 TOTAL PERIOD 3f COST - 1,031 - - - - 326 201 1,557 - - 1,557 - - - - - - 1,533 4,256

TLG Services, Inc.






PERIOD 3 TOTALS - 44,207 1,111 403 - 16,745 78,547 20,493 161,506 25,121 74,851 61,533 - 10,462 - - 2,499 1,200,182 367,642 937,517

TOTAL COST TO DECOMMISSION 11,233 118,973 22,602 9,610 26,948 52,390 402,857 116,180 760,793 571,010 110,736 79,047 274,669 149,728 1,714 344 2,499 22,636,550 1,679,809 4,474,194










TLG Services, Inc.

Catawba Nuclear Station Document D03-1671-001, Rev. 0 Decommissioning Cost Analysis Appendix D, Page 1 of 24

TLG Services, Inc.

APPENDIX D

DETAILED COST ANALYSIS

SAFSTOR

Table Page

D-1 Unit 1, SAFSTOR Decommissioning Cost Estimate ......................................... 2 D-2 Unit 2, SAFSTOR Decommissioning Cost Estimate ....................................... 13


Document D03-1671-001, Rev. 0Appendix D, Page 2 of 24

Table D-1Catawba Nuclear Station, Unit 1

SAFSTOR Decommissioning Cost Estimate(thousands of 2013 dollars)




1a.1.1 SAFSTOR site characterization survey - - - - - - 380 114 494 494 - - - - - - - - - - 1a.1.2 Prepare preliminary decommissioning cost - - - - - - 70 10 80 80 - - - - - - - - - 928 1a.1.3 Notification of Cessation of Operations a 1a.1.4 Remove fuel & source material n/a1a.1.5 Notification of Permanent Defueling a 1a.1.6 Deactivate plant systems & process waste a 1a.1.7 Prepare and submit PSDAR - - - - - - 107 16 123 123 - - - - - - - - - 1,428 1a.1.8 Review plant dwgs & specs. - - - - - - 70 10 80 80 - - - - - - - - - 928 1a.1.9 Perform detailed rad survey a 1a.1.10 Estimate by-product inventory - - - - - - 54 8 62 62 - - - - - - - - - 714 1a.1.11 End product description - - - - - - 54 8 62 62 - - - - - - - - - 714 1a.1.12 Detailed by-product inventory - - - - - - 80 12 92 92 - - - - - - - - - 1,071 1a.1.13 Define major work sequence - - - - - - 54 8 62 62 - - - - - - - - - 714 1a.1.14 Perform SER and EA - - - - - - 166 25 191 191 - - - - - - - - - 2,213 1a.1.15 Perform Site-Specific Cost Study - - - - - - 268 40 308 308 - - - - - - - - - 3,570

Activity Specifications1a.1.16.1 Prepare plant and facilities for SAFSTOR - - - - - - 264 40 303 303 - - - - - - - - - 3,513 1a.1.16.2 Plant systems - - - - - - 223 33 257 257 - - - - - - - - - 2,975 1a.1.16.3 Plant structures and buildings - - - - - - 167 25 192 192 - - - - - - - - - 2,228 1a.1.16.4 Waste management - - - - - - 107 16 123 123 - - - - - - - - - 1,428 1a.1.16.5 Facility and site dormancy - - - - - - 107 16 123 123 - - - - - - - - - 1,428 1a.1.16 Total - - - - - - 869 130 999 999 - - - - - - - - - 11,572

Detailed Work Procedures1a.1.17.1 Plant systems - - - - - - 63 10 73 73 - - - - - - - - - 845 1a.1.17.2 Facility closeout & dormancy - - - - - - 64 10 74 74 - - - - - - - - - 857 1a.1.17 Total - - - - - - 128 19 147 147 - - - - - - - - - 1,702

1a.1.18 Procure vacuum drying system - - - - - - 5 1 6 6 - - - - - - - - - 71 1a.1.19 Drain/de-energize non-cont. systems a 1a.1.20 Drain & dry NSSS a 1a.1.21 Drain/de-energize contaminated systems a 1a.1.22 Decon/secure contaminated systems a 1a.1 Subtotal Period 1a Activity Costs - - - - - - 2,303 403 2,706 2,706 - - - - - - - - - 25,625


Period 1a Period-Dependent Costs1a.4.1 Insurance - - - - - - 1,233 123 1,356 1,356 - - - - - - - - - - 1a.4.2 Property taxes - - - - - - 7,150 715 7,865 7,865 - - - - - - - - - - 1a.4.3 Health physics supplies - 470 - - - - - 118 588 588 - - - - - - - - - - 1a.4.4 Heavy equipment rental - 563 - - - - - 84 647 647 - - - - - - - - - - 1a.4.5 Disposal of DAW generated - - 13 2 - 29 - 9 52 52 - - - 593 - - - 11,865 19 - 1a.4.6 Plant energy budget - - - - - - 735 110 845 845 - - - - - - - - - - 1a.4.7 NRC Fees - - - - - - 1,164 116 1,280 1,280 - - - - - - - - - - 1a.4.8 Emergency Planning Fees - - - - - - 611 61 672 - 672 - - - - - - - - - 1a.4.9 FEMA Fees - - - - - - 350 52 402 - 402 - - - - - - - - - 1a.4.10 Spent Fuel Pool O&M - - - - - - 783 117 900 - 900 - - - - - - - - - 1a.4.11 Corporate A&G - - - - - - 2,362 354 2,717 2,717 - - - - - - - - - - 1a.4.12 Site O&M - - - - - - 226 34 260 260 - - - - - - - - - - 1a.4.13 Security Staff Cost - - - - - - 3,303 495 3,798 3,798 - - - - - - - - - 102,075 1a.4.14 Utility Staff Cost - - - - - - 23,144 3,472 26,616 26,616 - - - - - - - - - 395,243 1a.4 Subtotal Period 1a Period-Dependent Costs - 1,033 13 2 - 29 41,060 5,862 47,999 46,025 1,974 - - 593 - - - 11,865 19 497,318

1a.0 TOTAL PERIOD 1a COST - 1,033 13 2 - 29 44,518 6,438 52,032 48,731 3,302 - - 593 - - - 11,865 19 522,943

TLG Services, Inc.






PERIOD 1b - SAFSTOR Limited DECON Activities


Decontamination of Site Buildings1b.1.1.1 Reactor 948 - - - - - - 474 1,422 1,422 - - - - - - - - 21,905 - 1b.1.1.2 Auxiliary Building 499 - - - - - - 250 749 749 - - - - - - - - 12,347 - 1b.1.1.3 Containment Mechanical Equipment 22 - - - - - - 11 33 33 - - - - - - - - 530 - 1b.1.1.4 Fuel Building 777 - - - - - - 389 1,166 1,166 - - - - - - - - 16,577 - 1b.1.1.5 Retired Steam Generator Facility 32 - - - - - - 16 48 48 - - - - - - - - 768 - 1b.1.1 Totals 2,278 - - - - - - 1,139 3,417 3,417 - - - - - - - - 52,127 -

1b.1 Subtotal Period 1b Activity Costs 2,278 - - - - - - 1,139 3,417 3,417 - - - - - - - - 52,127 -

Period 1b Additional Costs1b.2.1 Spent fuel pool isolation - - - - - - 10,561 1,584 12,145 12,145 - - - - - - - - - - 1b.2 Subtotal Period 1b Additional Costs - - - - - - 10,561 1,584 12,145 12,145 - - - - - - - - - -

Period 1b Collateral Costs1b.3.1 Decon equipment 924 - - - - - - 139 1,062 1,062 - - - - - - - - - - 1b.3.2 Process decommissioning water waste 114 - 50 266 - 300 - 177 907 907 - - - 719 - - - 43,154 140 - 1b.3.4 Small tool allowance - 39 - - - - - 6 45 45 - - - - - - - - - - 1b.3.5 Spent Fuel Capital and Transfer - - - - - - 359 54 412 - 412 - - - - - - - - - 1b.3 Subtotal Period 1b Collateral Costs 1,038 39 50 266 - 300 359 375 2,427 2,014 412 - - 719 - - - 43,154 140 -

Period 1b Period-Dependent Costs1b.4.1 Decon supplies 821 - - - - - - 205 1,026 1,026 - - - - - - - - - - 1b.4.2 Insurance - - - - - - 311 31 342 342 - - - - - - - - - - 1b.4.3 Property taxes - - - - - - 1,380 138 1,518 1,518 - - - - - - - - - - 1b.4.4 Health physics supplies - 351 - - - - - 88 439 439 - - - - - - - - - - 1b.4.5 Heavy equipment rental - 142 - - - - - 21 163 163 - - - - - - - - - - 1b.4.6 Disposal of DAW generated - - 12 2 - 26 - 8 48 48 - - - 543 - - - 10,854 18 - 1b.4.7 Plant energy budget - - - - - - 185 28 213 213 - - - - - - - - - - 1b.4.8 NRC Fees - - - - - - 173 17 190 190 - - - - - - - - - - 1b.4.9 Emergency Planning Fees - - - - - - 154 15 169 - 169 - - - - - - - - - 1b.4.10 FEMA Fees - - - - - - 88 13 101 - 101 - - - - - - - - - 1b.4.11 Spent Fuel Pool O&M - - - - - - 197 30 227 - 227 - - - - - - - - - 1b.4.12 Corporate A&G - - - - - - 595 89 685 685 - - - - - - - - - - 1b.4.13 Site O&M - - - - - - 57 9 66 66 - - - - - - - - - - 1b.4.14 Security Staff Cost - - - - - - 833 125 957 957 - - - - - - - - - 25,728 1b.4.15 Utility Staff Cost - - - - - - 5,834 875 6,709 6,709 - - - - - - - - - 99,623 1b.4 Subtotal Period 1b Period-Dependent Costs 821 493 12 2 - 26 9,806 1,692 12,853 12,355 498 - - 543 - - - 10,854 18 125,351

1b.0 TOTAL PERIOD 1b COST 4,137 532 62 268 - 326 20,726 4,791 30,841 29,931 910 - - 1,262 - - - 54,008 52,285 125,351

PERIOD 1c - Preparations for SAFSTOR Dormancy


1c.1.1 Prepare support equipment for storage - 418 - - - - - 63 480 480 - - - - - - - - 3,000 - 1c.1.2 Install containment pressure equal. lines - 33 - - - - - 5 38 38 - - - - - - - - 700 - 1c.1.3 Interim survey prior to dormancy - - - - - - 733 220 953 953 - - - - - - - - 14,124 - 1c.1.4 Secure building accesses a 1c.1.5 Prepare & submit interim report - - - - - - 31 5 36 36 - - - - - - - - - 416

1c.1 Subtotal Period 1c Activity Costs - 451 - - - - 764 292 1,507 1,507 - - - - - - - - 17,824 416

Period 1c Collateral Costs1c.3.1 Process decommissioning water waste 174 - 77 408 - 460 - 271 1,391 1,391 - - - 1,103 - - - 66,194 215 - 1c.3.3 Small tool allowance - 3 - - - - - 0 4 4 - - - - - - - - - - 1c.3.4 Spent Fuel Capital and Transfer - - - - - - 378 57 435 - 435 - - - - - - - - - 1c.3 Subtotal Period 1c Collateral Costs 174 3 77 408 - 460 378 328 1,829 1,394 435 - - 1,103 - - - 66,194 215 -

Period 1c Period-Dependent Costs1c.4.1 Insurance - - - - - - 311 31 342 342 - - - - - - - - - - 1c.4.2 Property taxes - - - - - - 1,204 120 1,325 1,325 - - - - - - - - - - 1c.4.3 Health physics supplies - 199 - - - - - 50 249 249 - - - - - - - - - -

TLG Services, Inc.






Period 1c Period-Dependent Costs (continued)1c.4.4 Heavy equipment rental - 142 - - - - - 21 163 163 - - - - - - - - - - 1c.4.5 Disposal of DAW generated - - 3 0 - 7 - 2 13 13 - - - 150 - - - 2,991 5 - 1c.4.6 Plant energy budget - - - - - - 185 28 213 213 - - - - - - - - - - 1c.4.7 NRC Fees - - - - - - 173 17 190 190 - - - - - - - - - - 1c.4.8 Emergency Planning Fees - - - - - - 154 15 169 - 169 - - - - - - - - - 1c.4.9 FEMA Fees - - - - - - 88 13 101 - 101 - - - - - - - - - 1c.4.10 Spent Fuel Pool O&M - - - - - - 197 30 227 - 227 - - - - - - - - - 1c.4.11 Corporate A&G - - - - - - 595 89 685 685 - - - - - - - - - - 1c.4.12 Site O&M - - - - - - 57 9 66 66 - - - - - - - - - - 1c.4.13 Security Staff Cost - - - - - - 833 125 957 957 - - - - - - - - - 25,728 1c.4.14 Utility Staff Cost - - - - - - 5,834 875 6,709 6,709 - - - - - - - - - 99,623 1c.4 Subtotal Period 1c Period-Dependent Costs - 341 3 0 - 7 9,631 1,426 11,408 10,911 498 - - 150 - - - 2,991 5 125,351

1c.0 TOTAL PERIOD 1c COST 174 794 80 409 - 467 10,773 2,046 14,744 13,812 932 - - 1,253 - - - 69,185 18,044 125,768

PERIOD 1 TOTALS 4,311 2,360 155 679 - 823 76,017 13,275 97,618 92,474 5,144 - - 3,108 - - - 135,058 70,348 774,062

PERIOD 2a - SAFSTOR Dormancy with Wet Spent Fuel Storage

Period 2a Direct Decommissioning Activities2a.1.1 Quarterly Inspection a 2a.1.2 Semi-annual environmental survey a 2a.1.3 Prepare reports a 2a.1.4 Bituminous roof replacement - - - - - - 409 61 471 471 - - - - - - - - - - 2a.1.5 Maintenance supplies - - - - - - 1,183 296 1,478 1,478 - - - - - - - - - - 2a.1 Subtotal Period 2a Activity Costs - - - - - - 1,592 357 1,949 1,949 - - - - - - - - - -

Period 2a Collateral Costs2a.3.1 Spent Fuel Capital and Transfer - - - - - - 13,104 1,966 15,070 - 15,070 - - - - - - - - - 2a.3 Subtotal Period 2a Collateral Costs - - - - - - 13,104 1,966 15,070 - 15,070 - - - - - - - - -

Period 2a Period-Dependent Costs2a.4.1 Insurance - - - - - - 4,869 487 5,356 4,777 578 - - - - - - - - - 2a.4.2 Property taxes - - - - - - 19,552 1,955 21,508 235 21,273 - - - - - - - - - 2a.4.3 Health physics supplies - 1,585 - - - - - 396 1,981 1,981 - - - - - - - - - - 2a.4.4 Disposal of DAW generated - - 40 6 - 91 - 28 165 165 - - - 1,865 - - - 37,291 61 - 2a.4.5 Plant energy budget - - - - - - 1,260 189 1,449 724 724 - - - - - - - - - 2a.4.6 NRC Fees - - - - - - 2,527 253 2,780 2,780 - - - - - - - - - - 2a.4.7 Emergency Planning Fees - - - - - - 5,238 524 5,762 - 5,762 - - - - - - - - - 2a.4.8 Spent Fuel Pool O&M - - - - - - 6,712 1,007 7,719 - 7,719 - - - - - - - - - 2a.4.9 Corporate A&G - - - - - - 3,100 465 3,565 784 2,781 - - - - - - - - - 2a.4.10 Site O&M - - - - - - 986 148 1,134 249 885 - - - - - - - - - 2a.4.11 Security Staff Cost - - - - - - 17,726 2,659 20,385 5,779 14,607 - - - - - - - - 523,157 2a.4.12 Utility Staff Cost - - - - - - 31,450 4,718 36,168 7,253 28,915 - - - - - - - - 518,686 2a.4 Subtotal Period 2a Period-Dependent Costs - 1,585 40 6 - 91 93,421 12,828 107,971 24,727 83,244 - - 1,865 - - - 37,291 61 1,041,843

2a.0 TOTAL PERIOD 2a COST - 1,585 40 6 - 91 108,118 15,150 124,990 26,676 98,314 - - 1,865 - - - 37,291 61 1,041,843

PERIOD 2b - SAFSTOR Dormancy with Dry Spent Fuel Storage

Period 2b Direct Decommissioning Activities2b.1.1 Quarterly Inspection a 2b.1.2 Semi-annual environmental survey a 2b.1.3 Prepare reports a 2b.1.4 Bituminous roof replacement - - - - - - 621 93 714 714 - - - - - - - - - - 2b.1.5 Maintenance supplies - - - - - - 1,794 448 2,242 2,242 - - - - - - - - - - 2b.1 Subtotal Period 2b Activity Costs - - - - - - 2,415 542 2,956 2,956 - - - - - - - - - -

Period 2b Collateral Costs2b.3.1 Spent Fuel Capital and Transfer - - - - - - 5,442 816 6,258 - 6,258 - - - - - - - - - 2b.3 Subtotal Period 2b Collateral Costs - - - - - - 5,442 816 6,258 - 6,258 - - - - - - - - -

Period 2b Period-Dependent Costs2b.4.1 Insurance - - - - - - 6,772 677 7,449 7,247 202 - - - - - - - - - 2b.4.2 Property taxes - - - - - - 324 32 357 357 - - - - - - - - - - 2b.4.3 Health physics supplies - 1,157 - - - - - 289 1,446 1,446 - - - - - - - - - -

TLG Services, Inc.






Period 2b Period-Dependent Costs (continued)2b.4.4 Disposal of DAW generated - - 29 4 - 66 - 20 119 119 - - - 1,344 - - - 26,874 44 - 2b.4.5 Plant energy budget - - - - - - 956 143 1,099 1,099 - - - - - - - - - - 2b.4.6 NRC Fees - - - - - - 3,664 366 4,030 4,030 - - - - - - - - - - 2b.4.7 Emergency Planning Fees - - - - - - 7,946 795 8,741 - 8,741 - - - - - - - - - 2b.4.8 Corporate A&G - - - - - - 1,622 243 1,865 1,189 676 - - - - - - - - - 2b.4.9 Site O&M - - - - - - 516 77 593 378 215 - - - - - - - - - 2b.4.10 Security Staff Cost - - - - - - 14,029 2,104 16,133 8,766 7,367 - - - - - - - - 366,274 2b.4.11 Utility Staff Cost - - - - - - 15,687 2,353 18,041 11,002 7,038 - - - - - - - - 271,314 2b.4 Subtotal Period 2b Period-Dependent Costs - 1,157 29 4 - 66 51,516 7,101 59,873 35,633 24,240 - - 1,344 - - - 26,874 44 637,589

2b.0 TOTAL PERIOD 2b COST - 1,157 29 4 - 66 59,373 8,459 69,088 38,589 30,499 - - 1,344 - - - 26,874 44 637,589

PERIOD 2c - SAFSTOR Dormancy without Spent Fuel Storage

Period 2c Direct Decommissioning Activities2c.1.1 Quarterly Inspection a 2c.1.2 Semi-annual environmental survey a 2c.1.3 Prepare reports a 2c.1.4 Bituminous roof replacement - - - - - - 1,485 223 1,708 1,708 - - - - - - - - - - 2c.1.5 Maintenance supplies - - - - - - 4,290 1,073 5,363 5,363 - - - - - - - - - - 2c.1 Subtotal Period 2c Activity Costs - - - - - - 5,775 1,295 7,071 7,071 - - - - - - - - - -

Period 2c Period-Dependent Costs2c.4.1 Insurance - - - - - - 15,755 1,576 17,331 17,331 - - - - - - - - - - 2c.4.2 Property taxes - - - - - - 775 78 853 853 - - - - - - - - - - 2c.4.3 Health physics supplies - 2,681 - - - - - 670 3,351 3,351 - - - - - - - - - - 2c.4.4 Disposal of DAW generated - - 66 10 - 150 - 46 272 272 - - - 3,078 - - - 61,556 100 - 2c.4.5 Plant energy budget - - - - - - 2,285 343 2,628 2,628 - - - - - - - - - - 2c.4.6 NRC Fees - - - - - - 8,086 809 8,895 8,895 - - - - - - - - - - 2c.4.7 Corporate A&G - - - - - - 2,472 371 2,843 2,843 - - - - - - - - - - 2c.4.8 Site O&M - - - - - - 786 118 904 904 - - - - - - - - - - 2c.4.9 Security Staff Cost - - - - - - 18,229 2,734 20,964 20,964 - - - - - - - - - 486,643 2c.4.10 Utility Staff Cost - - - - - - 22,880 3,432 26,312 26,312 - - - - - - - - - 413,971 2c.4 Subtotal Period 2c Period-Dependent Costs - 2,681 66 10 - 150 71,270 10,176 84,353 84,353 - - - 3,078 - - - 61,556 100 900,614

2c.0 TOTAL PERIOD 2c COST - 2,681 66 10 - 150 77,045 11,471 91,423 91,423 - - - 3,078 - - - 61,556 100 900,614

PERIOD 2 TOTALS - 5,422 135 21 - 307 244,536 35,080 285,501 156,688 128,813 - - 6,286 - - - 125,721 205 2,580,045

PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy

Period 3a Direct Decommissioning Activities3a.1.1 Prepare preliminary decommissioning cost - - - - - - 70 10 80 80 - - - - - - - - - 928 3a.1.2 Review plant dwgs & specs. - - - - - - 247 37 284 284 - - - - - - - - - 3,284 3a.1.3 Perform detailed rad survey a 3a.1.4 End product description - - - - - - 54 8 62 62 - - - - - - - - - 714 3a.1.5 Detailed by-product inventory - - - - - - 70 10 80 80 - - - - - - - - - 928 3a.1.6 Define major work sequence - - - - - - 402 60 462 462 - - - - - - - - - 5,355 3a.1.7 Perform SER and EA - - - - - - 166 25 191 191 - - - - - - - - - 2,213 3a.1.8 Perform Site-Specific Cost Study - - - - - - 268 40 308 308 - - - - - - - - - 3,570 3a.1.9 Prepare/submit License Termination Plan - - - - - - 220 33 252 252 - - - - - - - - - 2,925 3a.1.10 Receive NRC approval of termination plan a


3a.1.11.1 Re-activate plant & temporary facilities - - - - - - 395 59 454 409 - 45 - - - - - - - 5,262 3a.1.11.2 Plant systems - - - - - - 223 33 257 231 - 26 - - - - - - - 2,975 3a.1.11.3 Reactor internals - - - - - - 381 57 438 438 - - - - - - - - - 5,069 3a.1.11.4 Reactor vessel - - - - - - 348 52 401 401 - - - - - - - - - 4,641 3a.1.11.5 Biological shield - - - - - - 27 4 31 31 - - - - - - - - - 357 3a.1.11.6 Steam generators - - - - - - 167 25 192 192 - - - - - - - - - 2,228 3a.1.11.7 Reinforced concrete - - - - - - 86 13 99 49 - 49 - - - - - - - 1,142 3a.1.11.8 Main Turbine - - - - - - 21 3 25 - - 25 - - - - - - - 286 3a.1.11.9 Main Condensers - - - - - - 21 3 25 - - 25 - - - - - - - 286 3a.1.11.10 Plant structures & buildings - - - - - - 167 25 192 96 - 96 - - - - - - - 2,228 3a.1.11.11 Waste management - - - - - - 247 37 284 284 - - - - - - - - - 3,284

TLG Services, Inc.






Activity Specifications (continued)3a.1.11.12 Facility & site closeout - - - - - - 48 7 55 28 - 28 - - - - - - - 643 3a.1.11 Total - - - - - - 2,132 320 2,452 2,158 - 294 - - - - - - - 28,401


Period 3a Additional Costs3a.2.1 Site Characterization - - - - - - 2,778 833 3,612 3,612 - - - - - - - - 19,100 7,852 3a.2 Subtotal Period 3a Additional Costs - - - - - - 2,778 833 3,612 3,612 - - - - - - - - 19,100 7,852

Period 3a Period-Dependent Costs3a.4.1 Insurance - - - - - - 506 51 557 557 - - - - - - - - - - 3a.4.2 Property taxes - - - - - - 25 2 27 27 - - - - - - - - - - 3a.4.3 Health physics supplies - 409 - - - - - 102 512 512 - - - - - - - - - - 3a.4.4 Heavy equipment rental - 563 - - - - - 84 647 647 - - - - - - - - - - 3a.4.5 Disposal of DAW generated - - 11 2 - 24 - 7 44 44 - - - 497 - - - 9,950 16 - 3a.4.6 Plant energy budget - - - - - - 735 110 845 845 - - - - - - - - - - 3a.4.7 NRC Fees - - - - - - 381 38 419 419 - - - - - - - - - - 3a.4.8 Corporate A&G - - - - - - 1,371 206 1,577 1,577 - - - - - - - - - - 3a.4.9 Site O&M - - - - - - 135 20 155 155 - - - - - - - - - - 3a.4.10 Security Staff Cost - - - - - - 942 141 1,084 1,084 - - - - - - - - - 35,728 3a.4.11 Utility Staff Cost - - - - - - 13,358 2,004 15,362 15,362 - - - - - - - - - 229,429 3a.4 Subtotal Period 3a Period-Dependent Costs - 972 11 2 - 24 17,454 2,767 21,229 21,229 - - - 497 - - - 9,950 16 265,157

3a.0 TOTAL PERIOD 3a COST - 972 11 2 - 24 29,228 4,949 35,186 34,893 - 294 - 497 - - - 9,950 19,116 324,919



Detailed Work Procedures3b.1.1.1 Plant systems - - - - - - 334 50 384 345 - 38 - - - - - - - 3,379 3b.1.1.2 Reactor internals - - - - - - 176 26 203 203 - - - - - - - - - 1,785 3b.1.1.3 Remaining buildings - - - - - - 95 14 109 27 - 82 - - - - - - - 964 3b.1.1.4 CRD cooling assembly - - - - - - 70 11 81 81 - - - - - - - - - 714 3b.1.1.5 CRD housings & ICI tubes - - - - - - 70 11 81 81 - - - - - - - - - 714 3b.1.1.6 Incore instrumentation - - - - - - 70 11 81 81 - - - - - - - - - 714 3b.1.1.7 Reactor vessel - - - - - - 256 38 294 294 - - - - - - - - - 2,592 3b.1.1.8 Facility closeout - - - - - - 85 13 97 49 - 49 - - - - - - - 857 3b.1.1.9 Missile shields - - - - - - 32 5 36 36 - - - - - - - - - 321 3b.1.1.10 Biological shield - - - - - - 85 13 97 97 - - - - - - - - - 857 3b.1.1.11 Steam generators - - - - - - 324 49 373 373 - - - - - - - - - 3,284 3b.1.1.12 Reinforced concrete - - - - - - 70 11 81 41 - 41 - - - - - - - 714 3b.1.1.13 Main Turbine - - - - - - 110 16 126 - - 126 - - - - - - - 1,114 3b.1.1.14 Main Condensers - - - - - - 110 16 126 - - 126 - - - - - - - 1,114 3b.1.1.15 Auxiliary building - - - - - - 192 29 221 199 - 22 - - - - - - - 1,949 3b.1.1.16 Reactor building - - - - - - 192 29 221 199 - 22 - - - - - - - 1,949 3b.1.1 Total - - - - - - 2,272 341 2,613 2,106 - 507 - - - - - - - 23,022 3b.1 Subtotal Period 3b Activity Costs - - - - - - 2,272 341 2,613 2,106 - 507 - - - - - - - 23,022

Period 3b Collateral Costs3b.3.1 Decon equipment 924 - - - - - - 139 1,062 1,062 - - - - - - - - - - 3b.3.2 Staff relocation expenses - - - - - - 1,130 169 1,299 1,299 - - - - - - - - - - 3b.3.3 Pipe cutting equipment - 1,100 - - - - - 165 1,265 1,265 - - - - - - - - - - 3b.3 Subtotal Period 3b Collateral Costs 924 1,100 - - - - 1,130 473 3,627 3,627 - - - - - - - - - -

Period 3b Period-Dependent Costs3b.4.1 Decon supplies 29 - - - - - - 7 36 36 - - - - - - - - - - 3b.4.2 Insurance - - - - - - 289 29 318 318 - - - - - - - - - - 3b.4.3 Property taxes - - - - - - 13 1 14 14 - - - - - - - - - - 3b.4.4 Health physics supplies - 225 - - - - - 56 281 281 - - - - - - - - - -

TLG Services, Inc.






Period 3b Period-Dependent Costs (continued)3b.4.5 Heavy equipment rental - 287 - - - - - 43 330 330 - - - - - - - - - - 3b.4.6 Disposal of DAW generated - - 6 1 - 14 - 4 25 25 - - - 279 - - - 5,580 9 - 3b.4.7 Plant energy budget - - - - - - 374 56 431 431 - - - - - - - - - - 3b.4.8 NRC Fees - - - - - - 194 19 214 214 - - - - - - - - - - 3b.4.9 Corporate A&G - - - - - - 962 144 1,107 1,107 - - - - - - - - - - 3b.4.10 Site O&M - - - - - - 95 14 109 109 - - - - - - - - - - 3b.4.11 Security Staff Cost - - - - - - 480 72 552 552 - - - - - - - - - 18,207 3b.4.12 Utility Staff Cost - - - - - - 9,644 1,447 11,090 11,090 - - - - - - - - - 161,023 3b.4 Subtotal Period 3b Period-Dependent Costs 29 512 6 1 - 14 12,052 1,893 14,506 14,506 - - - 279 - - - 5,580 9 179,230

3b.0 TOTAL PERIOD 3b COST 952 1,612 6 1 - 14 15,454 2,707 20,745 20,239 - 507 - 279 - - - 5,580 9 202,251

PERIOD 3 TOTALS 952 2,584 17 3 - 38 44,682 7,657 55,932 55,132 - 800 - 776 - - - 15,530 19,125 527,170



Nuclear Steam Supply System Removal4a.1.1.1 Reactor Coolant Piping 40 189 27 25 174 275 - 169 900 900 - - 637 674 - - - 147,794 5,317 - 4a.1.1.2 Pressurizer Relief Tank 4 16 6 5 37 54 - 26 148 148 - - 136 136 - - - 30,174 492 - 4a.1.1.3 Reactor Coolant Pumps & Motors 16 68 72 197 - 1,263 - 378 1,994 1,994 - - - 4,511 - - - 807,600 2,700 80 4a.1.1.4 Pressurizer 10 47 328 84 - 1,155 - 351 1,975 1,975 - - - 4,126 - - - 55,804 1,578 750 4a.1.1.5 Steam Generators 65 3,001 2,253 1,220 3,037 6,746 - 3,333 19,655 19,655 - - 39,289 24,101 - - - 3,402,733 20,508 1,500 4a.1.1.6 Retired Steam Generator Units - - 2,253 1,220 3,037 6,746 - 2,550 15,807 15,807 - - 39,289 24,101 - - - 3,402,733 10,800 1,500 4a.1.1.7 CRDMs/ICIs/Service Structure Removal 29 108 353 86 166 272 - 182 1,196 1,196 - - 1,823 3,621 - - - 143,697 2,924 - 4a.1.1.8 Reactor Vessel Internals 51 2,513 9,348 1,036 - 3,137 244 6,111 22,440 22,440 - - - 2,867 125 344 - 334,226 23,417 1,069 4a.1.1.9 Vessel & Internals GTCC Disposal - - - - - 14,307 - 2,146 16,453 16,453 - - - - - - 2,499 500,800 - - 4a.1.1.10 Reactor Vessel - 4,663 1,572 492 - 2,614 244 5,357 14,942 14,942 - - - 9,340 - - - 950,567 23,417 1,069 4a.1.1 Totals 214 10,605 16,213 4,365 6,450 36,570 488 20,604 95,509 95,509 - - 81,174 73,478 125 344 2,499 9,776,129 91,153 5,967

Removal of Major Equipment4a.1.2 Main Turbine/Generator - 349 273 31 734 - - 229 1,617 1,617 - - 4,974 - - - - 298,467 8,374 - 4a.1.3 Main Condensers - 1,190 165 26 848 - - 445 2,672 2,672 - - 7,657 - - - - 344,574 29,249 -

Cascading Costs from Clean Building Demolition4a.1.4.1 Reactor - 339 - - - - - 51 389 389 - - - - - - - - 4,509 - 4a.1.4.2 AB - Fw Pump/Switchgear Area - 23 - - - - - 3 26 26 - - - - - - - - 299 - 4a.1.4.3 Auxiliary Building - 182 - - - - - 27 210 210 - - - - - - - - 2,376 - 4a.1.4.4 Containment Mechanical Equipment - 6 - - - - - 1 7 7 - - - - - - - - 105 - 4a.1.4.5 Fuel Building - 89 - - - - - 13 103 103 - - - - - - - - 1,173 - 4a.1.4.6 Main Steam Doghouses - 100 - - - - - 15 115 115 - - - - - - - - 1,109 - 4a.1.4.7 Turbine Building - 294 - - - - - 44 339 339 - - - - - - - - 4,856 - 4a.1.4.8 Upper Head Injection Tank Building - 5 - - - - - 1 6 6 - - - - - - - - 70 - 4a.1.4 Totals - 1,038 - - - - - 156 1,194 1,194 - - - - - - - - 14,497 -

Disposal of Plant Systems4a.1.5.1 Aux Bldg Chilled Water - 89 2 3 109 - - 39 243 243 - - 1,094 - - - - 44,411 1,896 - 4a.1.5.2 Auxiliary Feedwater - 247 16 31 1,018 - - 221 1,532 1,532 - - 10,186 - - - - 413,660 5,567 - 4a.1.5.3 Auxiliary Steam - 13 - - - - - 2 15 - - 15 - - - - - - 386 - 4a.1.5.4 Auxiliary Steam RCA - 106 2 4 147 - - 49 309 309 - - 1,467 - - - - 59,568 2,289 - 4a.1.5.5 CCW Intake Screen Backwash - 5 - - - - - 1 6 - - 6 - - - - - - 144 - 4a.1.5.6 CO2 Gen Purge - 8 - - - - - 1 10 - - 10 - - - - - - 251 - 4a.1.5.7 Condensate - 368 - - - - - 55 424 - - 424 - - - - - - 10,255 - 4a.1.5.8 Condensate Storage - 65 - - - - - 10 74 - - 74 - - - - - - 1,737 - 4a.1.5.9 Condenser Cleaning - 40 - - - - - 6 46 - - 46 - - - - - - 1,125 - 4a.1.5.10 Condenser Steam Air Ejector - 34 - - - - - 5 39 - - 39 - - - - - - 988 - 4a.1.5.11 Containment Spray/Valve Inj Water - 234 5 10 339 - - 111 700 700 - - 3,389 - - - - 137,648 5,088 - 4a.1.5.12 Convent LP Service Water - 95 - - - - - 14 109 - - 109 - - - - - - 2,691 - 4a.1.5.13 Conventional Chemical Addition - 8 - - - - - 1 10 - - 10 - - - - - - 238 - 4a.1.5.14 Conventional Chemical Addition RCA - 15 0 0 11 - - 5 31 31 - - 109 - - - - 4,424 293 - 4a.1.5.15 DG Engine Cooling Water - 19 - - - - - 3 22 - - 22 - - - - - - 542 - 4a.1.5.16 DG Engine Fuel Oil - 67 - - - - - 10 77 - - 77 - - - - - - 1,753 - 4a.1.5.17 DG Engine Lube Oil - 29 - - - - - 4 33 - - 33 - - - - - - 829 - 4a.1.5.18 DG Engine Starting Air - 35 - - - - - 5 41 - - 41 - - - - - - 1,012 - 4a.1.5.19 DG Room Sump Pump - 6 - - - - - 1 7 - - 7 - - - - - - 175 -

TLG Services, Inc.






Disposal of Plant Systems (continued)4a.1.5.20 FDWP Condensate Seal - 22 - - - - - 3 25 - - 25 - - - - - - 632 - 4a.1.5.21 Feedwater - 54 - - - - - 8 62 - - 62 - - - - - - 1,525 - 4a.1.5.22 Feedwater Lube & Hydraulic Oil - 14 - - - - - 2 16 - - 16 - - - - - - 415 - 4a.1.5.23 Feedwater Pump Turbine Steam Seal - 3 - - - - - 0 3 - - 3 - - - - - - 80 - 4a.1.5.24 Feedwater RCA - 85 4 8 274 - - 64 436 436 - - 2,742 - - - - 111,348 1,971 - 4a.1.5.25 Generator Hydrogen - 7 - - - - - 1 8 - - 8 - - - - - - 217 - 4a.1.5.26 Generator Seal Oil - 10 - - - - - 2 12 - - 12 - - - - - - 311 - 4a.1.5.27 Heater Bleed Steam - 35 - - - - - 5 40 - - 40 - - - - - - 999 - 4a.1.5.28 Heater Drains - 135 - - - - - 20 155 - - 155 - - - - - - 3,850 - 4a.1.5.29 Heater Relief Valve - 20 - - - - - 3 23 - - 23 - - - - - - 525 - 4a.1.5.30 Heater Vent - 18 - - - - - 3 21 - - 21 - - - - - - 559 - 4a.1.5.31 MN Turbine Lube Oil & Purification - 40 - - - - - 6 46 - - 46 - - - - - - 1,130 - 4a.1.5.32 Main Steam - 15 - - - - - 2 18 - - 18 - - - - - - 450 - 4a.1.5.33 Main Steam Bypass to Condenser - 27 - - - - - 4 31 - - 31 - - - - - - 784 - 4a.1.5.34 Main Steam Leakoff & Steam Seal - 9 - - - - - 1 10 - - 10 - - - - - - 249 - 4a.1.5.35 Main Steam RCA - 29 1 2 59 - - 16 107 107 - - 594 - - - - 24,127 614 - 4a.1.5.36 Main Steam Vent - 130 4 8 252 - - 72 465 465 - - 2,525 - - - - 102,559 2,942 - 4a.1.5.37 Miscellaneous Equipment - 1 - - - - - 0 1 - - 1 - - - - - - 18 - 4a.1.5.38 Moisture Separator Reheater Bld Steam - 5 - - - - - 1 6 - - 6 - - - - - - 156 - 4a.1.5.39 Moisture Separator Reheater Drain - 152 - - - - - 23 175 - - 175 - - - - - - 4,233 - 4a.1.5.40 SG Wet Layup Recirculation - 21 0 1 17 - - 8 47 47 - - 174 - - - - 7,060 429 - 4a.1.5.41 SM Supply to Aux Equipment - 26 - - - - - 4 30 - - 30 - - - - - - 762 - 4a.1.5.42 SM Supply to Aux Equipment RCA - 10 0 0 10 - - 4 25 25 - - 100 - - - - 4,077 216 - 4a.1.5.43 Standby Shutdown Diesel - 3 - - - - - 0 3 - - 3 - - - - - - 84 - 4a.1.5.44 Steam Generator Blowdown Recycle - 282 13 26 849 - - 203 1,372 1,372 - - 8,495 - - - - 345,002 6,591 - 4a.1.5.45 Steam Supply to FW Pump Turbine - 26 - - - - - 4 29 - - 29 - - - - - - 743 - 4a.1.5.46 Turbine Crossover - 3 - - - - - 1 4 - - 4 - - - - - - 102 - 4a.1.5.47 Turbine Exhaust - 2 - - - - - 0 2 - - 2 - - - - - - 64 - 4a.1.5.48 Turbine Hydraulic Oil - 10 - - - - - 2 12 - - 12 - - - - - - 298 - 4a.1.5 Totals - 2,679 48 93 3,085 - - 1,008 6,913 5,268 - 1,645 30,876 - - - - 1,253,884 68,209 -

4a.1.6 Scaffolding in support of decommissioning - 748 16 4 77 14 - 204 1,064 1,064 - - 694 61 - - - 35,257 22,909 -

4a.1 Subtotal Period 4a Activity Costs 214 16,609 16,716 4,519 11,193 36,584 488 22,646 108,969 107,325 - 1,645 125,375 73,539 125 344 2,499 11,708,310 234,393 5,967


Period 4a Collateral Costs4a.3.1 Process decommissioning water waste 3 - 3 17 - 19 - 9 50 50 - - - 45 - - - 2,683 9 - 4a.3.3 Small tool allowance - 180 - - - - - 27 207 187 - 21 - - - - - - - - 4a.3 Subtotal Period 4a Collateral Costs 3 180 3 17 - 19 - 36 257 237 - 21 - 45 - - - 2,683 9 -

Period 4a Period-Dependent Costs4a.4.1 Decon supplies 72 - - - - - - 18 89 89 - - - - - - - - - - 4a.4.2 Insurance - - - - - - 720 72 792 792 - - - - - - - - - - 4a.4.3 Property taxes - - - - - - 32 3 35 31 - 3 - - - - - - - - 4a.4.4 Health physics supplies - 1,745 - - - - - 436 2,182 2,182 - - - - - - - - - - 4a.4.5 Heavy equipment rental - 2,734 - - - - - 410 3,144 3,144 - - - - - - - - - - 4a.4.6 Disposal of DAW generated - - 78 12 - 178 - 54 322 322 - - - 3,641 - - - 72,818 119 - 4a.4.7 Plant energy budget - - - - - - 885 133 1,018 1,018 - - - - - - - - - - 4a.4.8 NRC Fees - - - - - - 762 76 839 839 - - - - - - - - - - 4a.4.9 Liquid Radwaste Processing Equipment/Services - - - - - - 504 76 579 579 - - - - - - - - - - 4a.4.10 Corporate A&G - - - - - - 2,791 419 3,209 3,209 - - - - - - - - - - 4a.4.11 Site O&M - - - - - - 257 39 296 296 - - - - - - - - - - 4a.4.12 Security Staff Cost - - - - - - 1,377 207 1,584 1,584 - - - - - - - - - 55,560 4a.4.13 Utility Staff Cost - - - - - - 27,922 4,188 32,110 32,110 - - - - - - - - - 466,969 4a.4 Subtotal Period 4a Period-Dependent Costs 72 4,479 78 12 - 178 35,250 6,130 46,199 46,196 - 3 - 3,641 - - - 72,818 119 522,529

4a.0 TOTAL PERIOD 4a COST 289 21,268 16,797 4,548 11,193 36,780 37,026 29,199 157,100 155,431 - 1,669 125,375 77,225 125 344 2,499 11,783,810 260,888 528,496


Period 4b Direct Decommissioning Activities4b.1.1 Remove spent fuel racks 329 36 167 90 - 885 - 425 1,932 1,932 - - - 3,751 - - - 247,922 1,033 -

TLG Services, Inc.






Disposal of Plant Systems4b.1.2.1 Annulus Ventilation - 33 2 4 130 - - 29 197 197 - - 1,299 - - - - 52,733 723 - 4b.1.2.2 Aux & RB Heating Water - 479 6 12 398 - - 182 1,077 1,077 - - 3,980 - - - - 161,630 10,059 - 4b.1.2.3 Aux Bldg Ventilation - 172 8 15 510 - - 122 827 827 - - 5,100 - - - - 207,126 3,969 - 4b.1.2.4 Boron Recycle - 371 27 32 416 190 - 210 1,246 1,246 - - 4,160 810 - - - 222,231 8,657 - 4b.1.2.5 Boron Thermal Regeneration - 263 27 31 194 244 - 163 922 922 - - 1,946 1,033 - - - 147,402 6,149 - 4b.1.2.6 Chemical & Volume Control - 631 155 156 515 1,388 - 621 3,465 3,465 - - 5,153 5,879 - - - 598,038 14,739 - 4b.1.2.7 Component Cooling - 98 - - - - - 15 113 - - 113 - - - - - - 2,823 - 4b.1.2.8 Component Cooling RCA - 172 5 10 341 - - 96 624 624 - - 3,413 - - - - 138,588 3,584 - 4b.1.2.9 Condenser Circulating Water - 98 - - - - - 15 113 - - 113 - - - - - - 2,771 - 4b.1.2.10 Cont Air Release & Addition - 38 1 1 43 - - 16 100 100 - - 435 - - - - 17,669 898 - 4b.1.2.11 Cont Air Return Ex & H2 Skimmer - 95 2 5 149 - - 47 297 297 - - 1,488 - - - - 60,418 2,252 - 4b.1.2.12 Cont CRD, & ICI Room Vent - 82 9 14 318 43 - 82 547 547 - - 3,184 182 - - - 141,365 1,958 - 4b.1.2.13 Cont Water Sample & Purge - 9 0 0 3 - - 3 14 14 - - 28 - - - - 1,154 217 - 4b.1.2.14 Containment Chilled Water - 26 - - - - - 4 30 - - 30 - - - - - - 712 - 4b.1.2.15 Containment Chilled Water RCA - 74 2 4 141 - - 41 262 262 - - 1,407 - - - - 57,124 1,665 - 4b.1.2.16 Containment Purge Ventilation - 160 9 18 587 - - 132 906 906 - - 5,875 - - - - 238,572 3,796 - 4b.1.2.17 Conventional Sampling - 338 30 24 74 220 - 157 844 844 - - 745 927 - - - 91,773 7,906 - 4b.1.2.18 Diesel Bldg Ventilation - 9 - - - - - 1 10 - - 10 - - - - - - 254 - 4b.1.2.19 Electrical (clean) - 2,432 - - - - - 365 2,797 - - 2,797 - - - - - - 64,849 - 4b.1.2.20 Electrical (contaminated) - 638 13 22 565 50 - 261 1,549 1,549 - - 5,653 213 - - - 243,638 14,599 - 4b.1.2.21 Electrical (contaminated) RCA - 4,421 85 162 5,353 - - 1,941 11,962 11,962 - - 53,582 - - - - 2,175,984 97,394 - 4b.1.2.22 Equipment Decon - 31 1 1 37 - - 13 83 83 - - 368 - - - - 14,936 716 - 4b.1.2.23 FHB Ventilation - 65 5 10 317 - - 66 463 463 - - 3,177 - - - - 129,020 1,448 - 4b.1.2.24 Fire Protection - 37 - - - - - 5 42 - - 42 - - - - - - 1,045 - 4b.1.2.25 Fire Protection RCA - 155 5 9 287 - - 83 538 538 - - 2,869 - - - - 116,495 3,515 - 4b.1.2.26 Ice Condenser Refrigeration - 502 13 26 851 - - 258 1,651 1,651 - - 8,522 - - - - 346,098 11,241 - 4b.1.2.27 Instrument Air - 203 - - - - - 30 233 - - 233 - - - - - - 6,048 - 4b.1.2.28 Instrument Air RCA - 728 9 17 566 - - 270 1,590 1,590 - - 5,663 - - - - 229,971 15,129 - 4b.1.2.29 Liquid Waste Recycle - 838 103 103 357 913 - 517 2,831 2,831 - - 3,572 3,879 - - - 400,911 19,355 - 4b.1.2.30 Miscellaneous Ventilation - 46 - - - - - 7 52 - - 52 - - - - - - 1,469 - 4b.1.2.31 Nuclear Sampling - 273 22 17 45 154 - 118 630 630 - - 450 651 - - - 61,495 6,541 - 4b.1.2.32 Nuclear Service Water - 67 - - - - - 10 77 - - 77 - - - - - - 1,898 - 4b.1.2.33 Nuclear Service Water Pump Vent - 1 - - - - - 0 1 - - 1 - - - - - - 31 - 4b.1.2.34 Nuclear Service Water RCA - 519 18 35 1,164 - - 311 2,048 2,048 - - 11,651 - - - - 473,134 11,611 - 4b.1.2.35 Reactor Coolant - 112 29 36 155 311 - 137 781 781 - - 1,550 1,319 - - - 150,136 2,759 - 4b.1.2.36 Refueling Water - 297 8 16 529 - - 157 1,007 1,007 - - 5,296 - - - - 215,058 7,072 - 4b.1.2.37 Residual Heat Removal - 141 28 29 82 262 - 120 662 662 - - 824 1,109 - - - 106,875 3,325 - 4b.1.2.38 Safety Injection - 395 54 65 810 398 - 335 2,057 2,057 - - 8,112 1,687 - - - 441,009 9,227 - 4b.1.2.39 Spent Fuel Cooling - 199 18 19 129 153 - 112 629 629 - - 1,286 645 - - - 94,963 4,622 - 4b.1.2.40 Turbine Building Ventilation - 101 - - - - - 15 116 - - 116 - - - - - - 3,108 - 4b.1.2 Totals - 15,346 693 894 15,064 4,327 - 7,070 43,394 39,810 - 3,584 150,785 18,334 - - - 7,335,545 360,133 -

4b.1.3 Scaffolding in support of decommissioning - 1,122 25 6 115 22 - 306 1,595 1,595 - - 1,040 92 - - - 52,885 34,364 -

Decontamination of Site Buildings4b.1.4.1 Reactor 1,031 705 42 264 949 463 - 994 4,448 4,448 - - 9,498 6,886 - - - 974,130 37,169 - 4b.1.4.2 Auxiliary Building 468 160 7 67 94 112 - 327 1,236 1,236 - - 943 1,842 - - - 196,089 14,420 - 4b.1.4.3 Containment Mechanical Equipment 20 14 1 3 12 5 - 17 72 72 - - 122 77 - - - 11,289 781 - 4b.1.4.4 Fuel Building 701 747 10 24 339 51 - 606 2,479 2,479 - - 3,393 480 - - - 176,541 32,981 - 4b.1.4.5 Retired Steam Generator Facility 32 2 0 1 - 1 - 17 53 53 - - - 21 - - - 1,800 809 - 4b.1.4 Totals 2,253 1,629 59 359 1,394 633 - 1,961 8,288 8,288 - - 13,955 9,306 - - - 1,359,848 86,159 -

4b.1 Subtotal Period 4b Activity Costs 2,582 18,132 944 1,349 16,573 5,867 - 9,762 55,209 51,625 - 3,584 165,780 31,483 - - - 8,996,200 481,689 -

Period 4b Additional Costs4b.2.1 License Termination Survey Planning - - - - - - 830 249 1,079 1,079 - - - - - - - - - 6,240 4b.2.2 Remedial Action Surveys - - - - - - 1,313 394 1,707 1,707 - - - - - - - - 26,880 - 4b.2 Subtotal Period 4b Additional Costs - - - - - - 2,143 643 2,785 2,785 - - - - - - - - 26,880 6,240

Period 4b Collateral Costs4b.3.1 Process decommissioning water waste 11 - 13 71 - 80 - 38 213 213 - - - 191 - - - 11,453 37 - 4b.3.3 Small tool allowance - 334 - - - - - 50 384 384 - - - - - - - - - - 4b.3.4 Decommissioning Equipment Disposition - - 141 37 664 125 - 151 1,118 1,118 - - 6,000 529 - - - 304,968 88 - 4b.3 Subtotal Period 4b Collateral Costs 11 334 155 108 664 204 - 238 1,715 1,715 - - 6,000 720 - - - 316,421 125 -

TLG Services, Inc.






Period 4b Period-Dependent Costs4b.4.1 Decon supplies 879 - - - - - - 220 1,099 1,099 - - - - - - - - - - 4b.4.2 Insurance - - - - - - 734 73 808 808 - - - - - - - - - - 4b.4.3 Property taxes - - - - - - 32 3 35 35 - - - - - - - - - - 4b.4.4 Health physics supplies - 2,834 - - - - - 708 3,542 3,542 - - - - - - - - - - 4b.4.5 Heavy equipment rental - 2,759 - - - - - 414 3,173 3,173 - - - - - - - - - - 4b.4.6 Disposal of DAW generated - - 133 20 - 302 - 92 547 547 - - - 6,189 - - - 123,775 202 - 4b.4.7 Plant energy budget - - - - - - 713 107 819 819 - - - - - - - - - - 4b.4.8 NRC Fees - - - - - - 777 78 855 855 - - - - - - - - - - 4b.4.9 Liquid Radwaste Processing Equipment/Services - - - - - - 513 77 590 590 - - - - - - - - - - 4b.4.10 Corporate A&G - - - - - - 2,402 360 2,762 2,762 - - - - - - - - - - 4b.4.11 Site O&M - - - - - - 221 33 254 254 - - - - - - - - - - 4b.4.12 Security Staff Cost - - - - - - 1,404 211 1,615 1,615 - - - - - - - - - 56,640 4b.4.13 Utility Staff Cost - - - - - - 24,165 3,625 27,790 27,790 - - - - - - - - - 401,874 4b.4 Subtotal Period 4b Period-Dependent Costs 879 5,593 133 20 - 302 30,962 6,001 43,891 43,891 - - - 6,189 - - - 123,775 202 458,514

4b.0 TOTAL PERIOD 4b COST 3,473 24,059 1,232 1,477 17,237 6,373 33,105 16,644 103,601 100,016 - 3,584 171,780 38,392 - - - 9,436,396 508,896 464,754

PERIOD 4e - Delay before License Termination

Period 4e Period-Dependent Costs4e.4.2 Property taxes - - - - - - 25 3 28 28 - - - - - - - - - - 4e.4.3 Health physics supplies - 86 - - - - - 21 107 107 - - - - - - - - - - 4e.4.4 Disposal of DAW generated - - 2 0 - 5 - 1 9 9 - - - 97 - - - 1,946 3 - 4e.4.5 Plant energy budget - - - - - - 150 22 172 172 - - - - - - - - - - 4e.4.6 NRC Fees - - - - - - 265 26 291 291 - - - - - - - - - - 4e.4.7 Corporate A&G - - - - - - 44 7 51 51 - - - - - - - - - - 4e.4.8 Site O&M - - - - - - 4 1 5 5 - - - - - - - - - - 4e.4.9 Security Staff Cost - - - - - - 4 1 5 5 - - - - - - - - - 3,189 4e.4.10 Utility Staff Cost - - - - - - 392 59 450 450 - - - - - - - - - 7,440 4e.4 Subtotal Period 4e Period-Dependent Costs - 86 2 0 - 5 884 141 1,118 1,118 - - - 97 - - - 1,946 3 10,629

4e.0 TOTAL PERIOD 4e COST - 86 2 0 - 5 884 141 1,118 1,118 - - - 97 - - - 1,946 3 10,629





Period 4f Period-Dependent Costs4f.4.2 Property taxes - - - - - - 19 2 21 21 - - - - - - - - - - 4f.4.3 Health physics supplies - 777 - - - - - 194 971 971 - - - - - - - - - - 4f.4.4 Disposal of DAW generated - - 7 1 - 16 - 5 29 29 - - - 330 - - - 6,603 11 - 4f.4.5 Plant energy budget - - - - - - 111 17 127 127 - - - - - - - - - - 4f.4.6 NRC Fees - - - - - - 453 45 499 499 - - - - - - - - - - 4f.4.7 Corporate A&G - - - - - - 571 86 656 656 - - - - - - - - - - 4f.4.8 Site O&M - - - - - - 53 8 61 61 - - - - - - - - - - 4f.4.9 Security Staff Cost - - - - - - 337 51 388 388 - - - - - - - - - 11,786 4f.4.10 Utility Staff Cost - - - - - - 6,142 921 7,063 7,063 - - - - - - - - - 95,464 4f.4 Subtotal Period 4f Period-Dependent Costs - 777 7 1 - 16 7,685 1,328 9,815 9,815 - - - 330 - - - 6,603 11 107,250

4f.0 TOTAL PERIOD 4f COST - 777 7 1 - 16 17,014 3,957 21,773 21,773 - - - 330 - - - 6,603 182,964 110,370

PERIOD 4 TOTALS 3,762 46,191 18,038 6,026 28,431 43,175 88,028 49,941 283,591 278,338 - 5,253 297,155 116,044 125 344 2,499 21,228,760 952,751 1,114,249

TLG Services, Inc.








Demolition of Remaining Site Buildings5b.1.1.1 Reactor - 3,053 - - - - - 458 3,511 - - 3,511 - - - - - - 40,693 - 5b.1.1.2 AB - Fw Pump/Switchgear Area - 208 - - - - - 31 239 - - 239 - - - - - - 2,750 - 5b.1.1.3 Auxiliary Building - 1,647 - - - - - 247 1,895 - - 1,895 - - - - - - 21,564 - 5b.1.1.4 Containment Mechanical Equipment - 59 - - - - - 9 67 - - 67 - - - - - - 1,085 - 5b.1.1.5 Cooling Towers (3) - 2,246 - - - - - 337 2,583 - - 2,583 - - - - - - 34,180 - 5b.1.1.6 Diesel Generator Building - 332 - - - - - 50 382 - - 382 - - - - - - 4,152 - 5b.1.1.7 Fuel Building - 824 - - - - - 124 947 - - 947 - - - - - - 11,073 - 5b.1.1.8 Main Steam Doghouses - 905 - - - - - 136 1,041 - - 1,041 - - - - - - 10,075 - 5b.1.1.9 Retired Steam Generator Facility - 338 - - - - - 51 389 - - 389 - - - - - - 4,660 - 5b.1.1.10 Turbine Building - 2,800 - - - - - 420 3,220 - - 3,220 - - - - - - 47,939 - 5b.1.1.11 Turbine Pedestal - 693 - - - - - 104 796 - - 796 - - - - - - 7,683 - 5b.1.1.12 Upper Head Injection Tank Building - 44 - - - - - 7 50 - - 50 - - - - - - 633 - 5b.1.1 Totals - 13,148 - - - - - 1,972 15,120 - - 15,120 - - - - - - 186,487 -

Site Closeout Activities5b.1.2 Grade & landscape site - 203 - - - - - 30 233 - - 233 - - - - - - 420 - 5b.1.3 Final report to NRC - - - - - - 110 16 126 126 - - - - - - - - - 1,114 5b.1 Subtotal Period 5b Activity Costs - 13,350 - - - - 110 2,019 15,479 126 - 15,353 - - - - - - 186,907 1,114

Period 5b Additional Costs5b.2.1 Concrete Crushing - 553 - - - - 3 83 640 - - 640 - - - - - - 2,669 - 5b.2 Subtotal Period 5b Additional Costs - 553 - - - - 3 83 640 - - 640 - - - - - - 2,669 -


Period 5b Period-Dependent Costs5b.4.2 Property taxes - - - - - - 41 4 45 - - 45 - - - - - - - - 5b.4.3 Heavy equipment rental - 5,027 - - - - - 754 5,781 - - 5,781 - - - - - - - - 5b.4.4 Plant energy budget - - - - - - 121 18 139 - - 139 - - - - - - - - 5b.4.5 Security Staff Cost - - - - - - 684 103 787 - - 787 - - - - - - - 22,807 5b.4.6 Utility Staff Cost - - - - - - 8,169 1,225 9,395 - - 9,395 - - - - - - - 130,720 5b.4 Subtotal Period 5b Period-Dependent Costs - 5,027 - - - - 9,016 2,104 16,148 - - 16,148 - - - - - - - 153,527

5b.0 TOTAL PERIOD 5b COST - 19,067 - - - - 9,930 4,348 33,345 126 - 33,219 - - - - - - 189,577 154,641

PERIOD 5 TOTALS - 19,067 - - - - 9,930 4,348 33,345 126 - 33,219 - - - - - - 189,577 154,641

TOTAL COST TO DECOMMISSION 9,025 75,623 18,344 6,728 28,431 44,342 463,193 110,300 755,987 582,758 133,957 39,272 297,155 126,214 125 344 2,499 21,505,060 1,232,006 5,150,167

TLG Services, Inc.















TLG Services, Inc.





Costs run: Mon, Dec 2, 2013 at 16:08:48 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial / Utility andActivity DECCER Version 2010.09.09i Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term. Management Restoration Volume Class A Class B Class C GTCC Processed Craft ContractorIndex Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs. Manhours Manhours



1a.1.1 SAFSTOR site characterization survey - - - - - - 380 114 494 494 - - - - - - - - - - 1a.1.2 Prepare preliminary decommissioning cost - - - - - - 70 10 80 80 - - - - - - - - - 928 1a.1.3 Notification of Cessation of Operations a 1a.1.4 Remove fuel & source material n/a1a.1.5 Notification of Permanent Defueling a 1a.1.6 Deactivate plant systems & process waste a 1a.1.7 Prepare and submit PSDAR - - - - - - 107 16 123 123 - - - - - - - - - 1,428 1a.1.8 Review plant dwgs & specs. - - - - - - 70 10 80 80 - - - - - - - - - 928 1a.1.9 Perform detailed rad survey a 1a.1.10 Estimate by-product inventory - - - - - - 54 8 62 62 - - - - - - - - - 714 1a.1.11 End product description - - - - - - 54 8 62 62 - - - - - - - - - 714 1a.1.12 Detailed by-product inventory - - - - - - 80 12 92 92 - - - - - - - - - 1,071 1a.1.13 Define major work sequence - - - - - - 54 8 62 62 - - - - - - - - - 714 1a.1.14 Perform SER and EA - - - - - - 166 25 191 191 - - - - - - - - - 2,213 1a.1.15 Perform Site-Specific Cost Study - - - - - - 268 40 308 308 - - - - - - - - - 3,570

Activity Specifications1a.1.16.1 Prepare plant and facilities for SAFSTOR - - - - - - 264 40 303 303 - - - - - - - - - 3,513 1a.1.16.2 Plant systems - - - - - - 223 33 257 257 - - - - - - - - - 2,975 1a.1.16.3 Plant structures and buildings - - - - - - 167 25 192 192 - - - - - - - - - 2,228 1a.1.16.4 Waste management - - - - - - 107 16 123 123 - - - - - - - - - 1,428 1a.1.16.5 Facility and site dormancy - - - - - - 107 16 123 123 - - - - - - - - - 1,428 1a.1.16 Total - - - - - - 869 130 999 999 - - - - - - - - - 11,572

Detailed Work Procedures1a.1.17.1 Plant systems - - - - - - 63 10 73 73 - - - - - - - - - 845 1a.1.17.2 Facility closeout & dormancy - - - - - - 64 10 74 74 - - - - - - - - - 857 1a.1.17 Total - - - - - - 128 19 147 147 - - - - - - - - - 1,702

1a.1.18 Procure vacuum drying system - - - - - - 5 1 6 6 - - - - - - - - - 71 1a.1.19 Drain/de-energize non-cont. systems a 1a.1.20 Drain & dry NSSS a 1a.1.21 Drain/de-energize contaminated systems a 1a.1.22 Decon/secure contaminated systems a 1a.1 Subtotal Period 1a Activity Costs - - - - - - 2,303 403 2,706 2,706 - - - - - - - - - 25,625

Period 1a Additional Costs1a.2.1 Landfill and Firing Range Closure - - - - - - 1,144 172 1,315 - - 1,315 - - - - - - - - 1a.2 Subtotal Period 1a Additional Costs - - - - - - 1,144 172 1,315 - - 1,315 - - - - - - - -


Period 1a Period-Dependent Costs1a.4.1 Insurance - - - - - - 1,233 123 1,356 1,356 - - - - - - - - - - 1a.4.2 Property taxes - - - - - - 7,150 715 7,865 7,865 - - - - - - - - - - 1a.4.3 Health physics supplies - 470 - - - - - 118 588 588 - - - - - - - - - - 1a.4.4 Heavy equipment rental - 563 - - - - - 84 647 647 - - - - - - - - - - 1a.4.5 Disposal of DAW generated - - 13 2 - 29 - 9 52 52 - - - 593 - - - 11,865 19 - 1a.4.6 Plant energy budget - - - - - - 735 110 845 845 - - - - - - - - - - 1a.4.7 NRC Fees - - - - - - 826 83 908 908 - - - - - - - - - - 1a.4.8 Emergency Planning Fees - - - - - - 611 61 672 - 672 - - - - - - - - - 1a.4.9 FEMA Fees - - - - - - 350 52 402 - 402 - - - - - - - - - 1a.4.10 Spent Fuel Pool O&M - - - - - - 783 117 900 - 900 - - - - - - - - - 1a.4.11 ISFSI Operating Costs - - - - - - 111 17 128 - 128 - - - - - - - - - 1a.4.12 Corporate A&G - - - - - - 2,362 354 2,717 2,717 - - - - - - - - - - 1a.4.13 Site O&M - - - - - - 226 34 260 260 - - - - - - - - - - 1a.4.14 Security Staff Cost - - - - - - 3,303 495 3,798 3,798 - - - - - - - - - 102,075 1a.4.15 Utility Staff Cost - - - - - - 23,144 3,472 26,616 26,616 - - - - - - - - - 395,243 1a.4 Subtotal Period 1a Period-Dependent Costs - 1,033 13 2 - 29 40,834 5,845 47,755 45,652 2,103 - - 593 - - - 11,865 19 497,318

1a.0 TOTAL PERIOD 1a COST - 1,033 13 2 - 29 45,435 6,592 53,104 48,358 3,430 1,315 - 593 - - - 11,865 19 522,943

TLG Services, Inc.






PERIOD 1b - SAFSTOR Limited DECON Activities


Decontamination of Site Buildings1b.1.1.1 Reactor 948 - - - - - - 474 1,422 1,422 - - - - - - - - 21,904 - 1b.1.1.2 Auxiliary Building 488 - - - - - - 244 732 732 - - - - - - - - 12,088 - 1b.1.1.3 Auxiliary Service Building (common) 31 - - - - - - 16 47 47 - - - - - - - - 771 - 1b.1.1.4 Containment Mechanical Equipment 22 - - - - - - 11 33 33 - - - - - - - - 530 - 1b.1.1.5 Contaminated Materials Warehouse(common) 61 - - - - - - 30 91 91 - - - - - - - - 1,472 - 1b.1.1.6 Monitor Tank Building (common) 77 - - - - - - 38 115 115 - - - - - - - - 1,872 - 1b.1.1.7 Waste Solidification Facility (common) 12 - - - - - - 6 18 18 - - - - - - - - 291 - 1b.1.1.8 Fuel Building 698 - - - - - - 349 1,047 1,047 - - - - - - - - 14,857 - 1b.1.1 Totals 2,336 - - - - - - 1,168 3,504 3,504 - - - - - - - - 53,786 -

1b.1 Subtotal Period 1b Activity Costs 2,336 - - - - - - 1,168 3,504 3,504 - - - - - - - - 53,786 -

Period 1b Additional Costs1b.2.1 Spent fuel pool isolation - - - - - - 7,040 1,056 8,096 8,096 - - - - - - - - - - 1b.2.2 Landfill Post Closure Maintenance - - - - - - 10 2 12 - - 12 - - - - - - - - 1b.2.3 Misc Waste Disposal - - 2 4 16 - - 3 25 25 - - 118 - - - - 7,404 101 - 1b.2 Subtotal Period 1b Additional Costs - - 2 4 16 - 7,051 1,061 8,133 8,121 - 12 118 - - - - 7,404 101 -

Period 1b Collateral Costs1b.3.1 Decon equipment 924 - - - - - - 139 1,062 1,062 - - - - - - - - - - 1b.3.2 Process decommissioning water waste 116 - 51 271 - 305 - 180 924 924 - - - 732 - - - 43,948 143 - 1b.3.4 Small tool allowance - 40 - - - - - 6 46 46 - - - - - - - - - - 1b.3.5 Spent Fuel Capital and Transfer - - - - - - 359 54 412 - 412 - - - - - - - - - 1b.3 Subtotal Period 1b Collateral Costs 1,040 40 51 271 - 305 359 378 2,444 2,032 412 - - 732 - - - 43,948 143 -

Period 1b Period-Dependent Costs1b.4.1 Decon supplies 901 - - - - - - 225 1,127 1,127 - - - - - - - - - - 1b.4.2 Insurance - - - - - - 311 31 342 342 - - - - - - - - - - 1b.4.3 Property taxes - - - - - - 1,380 138 1,518 1,518 - - - - - - - - - - 1b.4.4 Health physics supplies - 359 - - - - - 90 449 449 - - - - - - - - - - 1b.4.5 Heavy equipment rental - 142 - - - - - 21 163 163 - - - - - - - - - - 1b.4.6 Disposal of DAW generated - - 13 2 - 29 - 9 52 52 - - - 589 - - - 11,779 19 - 1b.4.7 Plant energy budget - - - - - - 185 28 213 213 - - - - - - - - - - 1b.4.8 NRC Fees - - - - - - 118 12 129 129 - - - - - - - - - - 1b.4.9 Emergency Planning Fees - - - - - - 154 15 169 - 169 - - - - - - - - - 1b.4.10 FEMA Fees - - - - - - 88 13 101 - 101 - - - - - - - - - 1b.4.11 Spent Fuel Pool O&M - - - - - - 197 30 227 - 227 - - - - - - - - - 1b.4.12 ISFSI Operating Costs - - - - - - 28 4 32 - 32 - - - - - - - - - 1b.4.13 Corporate A&G - - - - - - 595 89 685 685 - - - - - - - - - - 1b.4.14 Site O&M - - - - - - 57 9 66 66 - - - - - - - - - - 1b.4.15 Security Staff Cost - - - - - - 833 125 957 957 - - - - - - - - - 25,728 1b.4.16 Utility Staff Cost - - - - - - 5,834 875 6,709 6,709 - - - - - - - - - 99,623 1b.4 Subtotal Period 1b Period-Dependent Costs 901 501 13 2 - 29 9,779 1,714 12,939 12,409 530 - - 589 - - - 11,779 19 125,351

1b.0 TOTAL PERIOD 1b COST 4,277 541 66 277 16 334 17,189 4,321 27,020 26,066 942 12 118 1,321 - - - 63,131 54,049 125,351

PERIOD 1c - Preparations for SAFSTOR Dormancy


1c.1.1 Prepare support equipment for storage - 418 - - - - - 63 480 480 - - - - - - - - 3,000 - 1c.1.2 Install containment pressure equal. lines - 33 - - - - - 5 38 38 - - - - - - - - 700 - 1c.1.3 Interim survey prior to dormancy - - - - - - 733 220 953 953 - - - - - - - - 14,124 - 1c.1.4 Secure building accesses a 1c.1.5 Prepare & submit interim report - - - - - - 31 5 36 36 - - - - - - - - - 416

1c.1 Subtotal Period 1c Activity Costs - 451 - - - - 764 292 1,507 1,507 - - - - - - - - 17,824 416


TLG Services, Inc.






Period 1c Collateral Costs1c.3.1 Process decommissioning water waste 174 - 77 408 - 460 - 271 1,391 1,391 - - - 1,103 - - - 66,194 215 - 1c.3.3 Small tool allowance - 3 - - - - - 0 4 4 - - - - - - - - - - 1c.3.4 Spent Fuel Capital and Transfer - - - - - - 378 57 435 - 435 - - - - - - - - - 1c.3 Subtotal Period 1c Collateral Costs 174 3 77 408 - 460 378 328 1,829 1,394 435 - - 1,103 - - - 66,194 215 -

Period 1c Period-Dependent Costs1c.4.1 Insurance - - - - - - 311 31 342 342 - - - - - - - - - - 1c.4.2 Property taxes - - - - - - 1,204 120 1,325 1,325 - - - - - - - - - - 1c.4.3 Health physics supplies - 199 - - - - - 50 249 249 - - - - - - - - - - 1c.4.4 Heavy equipment rental - 142 - - - - - 21 163 163 - - - - - - - - - - 1c.4.5 Disposal of DAW generated - - 3 0 - 7 - 2 13 13 - - - 150 - - - 2,991 5 - 1c.4.6 Plant energy budget - - - - - - 185 28 213 213 - - - - - - - - - - 1c.4.7 NRC Fees - - - - - - 118 12 129 129 - - - - - - - - - - 1c.4.8 Emergency Planning Fees - - - - - - 154 15 169 - 169 - - - - - - - - - 1c.4.9 FEMA Fees - - - - - - 88 13 101 - 101 - - - - - - - - - 1c.4.10 Spent Fuel Pool O&M - - - - - - 197 30 227 - 227 - - - - - - - - - 1c.4.11 ISFSI Operating Costs - - - - - - 28 4 32 - 32 - - - - - - - - - 1c.4.12 Corporate A&G - - - - - - 595 89 685 685 - - - - - - - - - - 1c.4.13 Site O&M - - - - - - 57 9 66 66 - - - - - - - - - - 1c.4.14 Security Staff Cost - - - - - - 833 125 957 957 - - - - - - - - - 25,728 1c.4.15 Utility Staff Cost - - - - - - 5,834 875 6,709 6,709 - - - - - - - - - 99,623 1c.4 Subtotal Period 1c Period-Dependent Costs - 341 3 0 - 7 9,604 1,424 11,380 10,850 530 - - 150 - - - 2,991 5 125,351

1c.0 TOTAL PERIOD 1c COST 174 794 80 409 - 467 10,756 2,046 14,728 13,751 965 12 - 1,253 - - - 69,185 18,044 125,768

PERIOD 1 TOTALS 4,452 2,368 159 688 16 830 73,380 12,960 94,852 88,176 5,337 1,339 118 3,167 - - - 144,181 72,113 774,062

PERIOD 2a - SAFSTOR Dormancy with Wet Spent Fuel Storage

Period 2a Direct Decommissioning Activities2a.1.1 Quarterly Inspection a 2a.1.2 Semi-annual environmental survey a 2a.1.3 Prepare reports a 2a.1.4 Bituminous roof replacement - - - - - - 1,056 158 1,215 1,215 - - - - - - - - - - 2a.1.5 Maintenance supplies - - - - - - 1,183 296 1,478 1,478 - - - - - - - - - - 2a.1 Subtotal Period 2a Activity Costs - - - - - - 2,239 454 2,693 2,693 - - - - - - - - - -

Period 2a Additional Costs2a.2.1 Landfill Post Closure Maintenance - - - - - - 345 52 397 - - 397 - - - - - - - - 2a.2 Subtotal Period 2a Additional Costs - - - - - - 345 52 397 - - 397 - - - - - - - -

Period 2a Collateral Costs2a.3.1 Spent Fuel Capital and Transfer - - - - - - 13,104 1,966 15,070 - 15,070 - - - - - - - - - 2a.3 Subtotal Period 2a Collateral Costs - - - - - - 13,104 1,966 15,070 - 15,070 - - - - - - - - -

Period 2a Period-Dependent Costs2a.4.1 Insurance - - - - - - 4,869 487 5,356 4,777 578 - - - - - - - - - 2a.4.2 Property taxes - - - - - - 19,552 1,955 21,508 235 21,273 - - - - - - - - - 2a.4.3 Health physics supplies - 1,585 - - - - - 396 1,981 1,981 - - - - - - - - - - 2a.4.4 Disposal of DAW generated - - 40 6 - 91 - 28 165 165 - - - 1,865 - - - 37,291 61 - 2a.4.5 Plant energy budget - - - - - - 1,260 189 1,449 724 724 - - - - - - - - - 2a.4.6 NRC Fees - - - - - - 2,330 233 2,563 2,563 - - - - - - - - - - 2a.4.7 Emergency Planning Fees - - - - - - 5,238 524 5,762 - 5,762 - - - - - - - - - 2a.4.8 Spent Fuel Pool O&M - - - - - - 6,712 1,007 7,719 - 7,719 - - - - - - - - - 2a.4.9 ISFSI Operating Costs - - - - - - 956 143 1,100 - 1,100 - - - - - - - - - 2a.4.10 Corporate A&G - - - - - - 3,100 465 3,565 784 2,781 - - - - - - - - - 2a.4.11 Site O&M - - - - - - 986 148 1,134 249 885 - - - - - - - - - 2a.4.12 Security Staff Cost - - - - - - 17,726 2,659 20,385 5,779 14,607 - - - - - - - - 523,157 2a.4.13 Utility Staff Cost - - - - - - 31,450 4,718 36,168 7,253 28,915 - - - - - - - - 518,686 2a.4 Subtotal Period 2a Period-Dependent Costs - 1,585 40 6 - 91 94,180 12,951 108,854 24,510 84,343 - - 1,865 - - - 37,291 61 1,041,843

2a.0 TOTAL PERIOD 2a COST - 1,585 40 6 - 91 109,869 15,423 127,014 27,203 99,414 397 - 1,865 - - - 37,291 61 1,041,843

TLG Services, Inc.






PERIOD 2b - SAFSTOR Dormancy with Dry Spent Fuel Storage

Period 2b Direct Decommissioning Activities2b.1.1 Quarterly Inspection a 2b.1.2 Semi-annual environmental survey a 2b.1.3 Prepare reports a 2b.1.4 Bituminous roof replacement - - - - - - 1,603 240 1,843 1,843 - - - - - - - - - - 2b.1.5 Maintenance supplies - - - - - - 1,794 448 2,242 2,242 - - - - - - - - - - 2b.1 Subtotal Period 2b Activity Costs - - - - - - 3,397 689 4,085 4,085 - - - - - - - - - -

Period 2b Additional Costs2b.2.1 Landfill Post Closure Maintenance - - - - - - 400 60 460 - - 460 - - - - - - - - 2b.2 Subtotal Period 2b Additional Costs - - - - - - 400 60 460 - - 460 - - - - - - - -

Period 2b Collateral Costs2b.3.1 Spent Fuel Capital and Transfer - - - - - - 5,442 816 6,258 - 6,258 - - - - - - - - - 2b.3 Subtotal Period 2b Collateral Costs - - - - - - 5,442 816 6,258 - 6,258 - - - - - - - - -

Period 2b Period-Dependent Costs2b.4.1 Insurance - - - - - - 6,772 677 7,449 7,247 202 - - - - - - - - - 2b.4.2 Property taxes - - - - - - 324 32 357 357 - - - - - - - - - - 2b.4.3 Health physics supplies - 1,157 - - - - - 289 1,446 1,446 - - - - - - - - - - 2b.4.4 Disposal of DAW generated - - 29 4 - 66 - 20 119 119 - - - 1,344 - - - 26,874 44 - 2b.4.5 Plant energy budget - - - - - - 956 143 1,099 1,099 - - - - - - - - - - 2b.4.6 NRC Fees - - - - - - 3,408 341 3,748 3,748 - - - - - - - - - - 2b.4.7 Emergency Planning Fees - - - - - - 7,946 795 8,741 - 8,741 - - - - - - - - - 2b.4.8 ISFSI Operating Costs - - - - - - 1,450 218 1,668 - 1,668 - - - - - - - - - 2b.4.9 Corporate A&G - - - - - - 1,622 243 1,865 1,189 676 - - - - - - - - - 2b.4.10 Site O&M - - - - - - 516 77 593 378 215 - - - - - - - - - 2b.4.11 Security Staff Cost - - - - - - 14,029 2,104 16,133 8,766 7,367 - - - - - - - - 366,274 2b.4.12 Utility Staff Cost - - - - - - 15,687 2,353 18,041 11,002 7,038 - - - - - - - - 271,314 2b.4 Subtotal Period 2b Period-Dependent Costs - 1,157 29 4 - 66 52,710 7,293 61,259 35,351 25,908 - - 1,344 - - - 26,874 44 637,589

2b.0 TOTAL PERIOD 2b COST - 1,157 29 4 - 66 61,948 8,858 72,063 39,436 32,166 460 - 1,344 - - - 26,874 44 637,589

PERIOD 2c - SAFSTOR Dormancy without Spent Fuel Storage

Period 2c Direct Decommissioning Activities2c.1.1 Quarterly Inspection a 2c.1.2 Semi-annual environmental survey a 2c.1.3 Prepare reports a 2c.1.4 Bituminous roof replacement - - - - - - 3,959 594 4,552 4,552 - - - - - - - - - - 2c.1.5 Maintenance supplies - - - - - - 4,431 1,108 5,539 5,539 - - - - - - - - - - 2c.1 Subtotal Period 2c Activity Costs - - - - - - 8,390 1,702 10,091 10,091 - - - - - - - - - -

Period 2c Period-Dependent Costs2c.4.1 Insurance - - - - - - 16,273 1,627 17,900 17,900 - - - - - - - - - - 2c.4.2 Property taxes - - - - - - 801 80 881 881 - - - - - - - - - - 2c.4.3 Health physics supplies - 2,769 - - - - - 692 3,461 3,461 - - - - - - - - - - 2c.4.4 Disposal of DAW generated - - 68 11 - 155 - 47 281 281 - - - 3,179 - - - 63,578 104 - 2c.4.5 Plant energy budget - - - - - - 2,361 354 2,715 2,715 - - - - - - - - - - 2c.4.6 NRC Fees - - - - - - 8,118 812 8,930 8,930 - - - - - - - - - - 2c.4.7 Corporate A&G - - - - - - 2,553 383 2,936 2,936 - - - - - - - - - - 2c.4.8 Site O&M - - - - - - 812 122 934 934 - - - - - - - - - - 2c.4.9 Security Staff Cost - - - - - - 18,828 2,824 21,652 21,652 - - - - - - - - - 502,629 2c.4.10 Utility Staff Cost - - - - - - 23,632 3,545 27,177 27,177 - - - - - - - - - 427,569 2c.4 Subtotal Period 2c Period-Dependent Costs - 2,769 68 11 - 155 73,378 10,486 86,867 86,867 - - - 3,179 - - - 63,578 104 930,198

2c.0 TOTAL PERIOD 2c COST - 2,769 68 11 - 155 81,767 12,188 96,958 96,958 - - - 3,179 - - - 63,578 104 930,198

PERIOD 2 TOTALS - 5,510 137 21 - 312 253,585 36,469 296,035 163,597 131,580 857 - 6,387 - - - 127,743 208 2,609,629

TLG Services, Inc.






PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy

Period 3a Direct Decommissioning Activities3a.1.1 Prepare preliminary decommissioning cost - - - - - - 70 10 80 80 - - - - - - - - - 928 3a.1.2 Review plant dwgs & specs. - - - - - - 247 37 284 284 - - - - - - - - - 3,284 3a.1.3 Perform detailed rad survey a 3a.1.4 End product description - - - - - - 54 8 62 62 - - - - - - - - - 714 3a.1.5 Detailed by-product inventory - - - - - - 70 10 80 80 - - - - - - - - - 928 3a.1.6 Define major work sequence - - - - - - 402 60 462 462 - - - - - - - - - 5,355 3a.1.7 Perform SER and EA - - - - - - 166 25 191 191 - - - - - - - - - 2,213 3a.1.8 Perform Site-Specific Cost Study - - - - - - 268 40 308 308 - - - - - - - - - 3,570 3a.1.9 Prepare/submit License Termination Plan - - - - - - 220 33 252 252 - - - - - - - - - 2,925 3a.1.10 Receive NRC approval of termination plan a


3a.1.11.1 Re-activate plant & temporary facilities - - - - - - 395 59 454 409 - 45 - - - - - - - 5,262 3a.1.11.2 Plant systems - - - - - - 223 33 257 231 - 26 - - - - - - - 2,975 3a.1.11.3 Reactor internals - - - - - - 381 57 438 438 - - - - - - - - - 5,069 3a.1.11.4 Reactor vessel - - - - - - 348 52 401 401 - - - - - - - - - 4,641 3a.1.11.5 Biological shield - - - - - - 27 4 31 31 - - - - - - - - - 357 3a.1.11.6 Steam generators - - - - - - 167 25 192 192 - - - - - - - - - 2,228 3a.1.11.7 Reinforced concrete - - - - - - 86 13 99 49 - 49 - - - - - - - 1,142 3a.1.11.8 Main Turbine - - - - - - 21 3 25 - - 25 - - - - - - - 286 3a.1.11.9 Main Condensers - - - - - - 21 3 25 - - 25 - - - - - - - 286 3a.1.11.10 Plant structures & buildings - - - - - - 167 25 192 96 - 96 - - - - - - - 2,228 3a.1.11.11 Waste management - - - - - - 247 37 284 284 - - - - - - - - - 3,284 3a.1.11.12 Facility & site closeout - - - - - - 48 7 55 28 - 28 - - - - - - - 643 3a.1.11 Total - - - - - - 2,132 320 2,452 2,158 - 294 - - - - - - - 28,401


Period 3a Additional Costs3a.2.1 Site Characterization - - - - - - 1,188 356 1,544 1,544 - - - - - - - - 8,167 3,357 3a.2 Subtotal Period 3a Additional Costs - - - - - - 1,188 356 1,544 1,544 - - - - - - - - 8,167 3,357

Period 3a Period-Dependent Costs3a.4.1 Insurance - - - - - - 506 51 557 557 - - - - - - - - - - 3a.4.2 Property taxes - - - - - - 25 2 27 27 - - - - - - - - - - 3a.4.3 Health physics supplies - 409 - - - - - 102 512 512 - - - - - - - - - - 3a.4.4 Heavy equipment rental - 563 - - - - - 84 647 647 - - - - - - - - - - 3a.4.5 Disposal of DAW generated - - 11 2 - 24 - 7 44 44 - - - 497 - - - 9,950 16 - 3a.4.6 Plant energy budget - - - - - - 735 110 845 845 - - - - - - - - - - 3a.4.7 NRC Fees - - - - - - 337 34 370 370 - - - - - - - - - - 3a.4.8 Corporate A&G - - - - - - 1,371 206 1,577 1,577 - - - - - - - - - - 3a.4.9 Site O&M - - - - - - 135 20 155 155 - - - - - - - - - - 3a.4.10 Security Staff Cost - - - - - - 942 141 1,084 1,084 - - - - - - - - - 35,728 3a.4.11 Utility Staff Cost - - - - - - 13,358 2,004 15,362 15,362 - - - - - - - - - 229,429 3a.4 Subtotal Period 3a Period-Dependent Costs - 972 11 2 - 24 17,409 2,762 21,180 21,180 - - - 497 - - - 9,950 16 265,157

3a.0 TOTAL PERIOD 3a COST - 972 11 2 - 24 27,593 4,468 33,070 32,776 - 294 - 497 - - - 9,950 8,183 320,424



Detailed Work Procedures3b.1.1.1 Plant systems - - - - - - 334 50 384 345 - 38 - - - - - - - 3,379 3b.1.1.2 Reactor internals - - - - - - 176 26 203 203 - - - - - - - - - 1,785 3b.1.1.3 Remaining buildings - - - - - - 95 14 109 27 - 82 - - - - - - - 964 3b.1.1.4 CRD cooling assembly - - - - - - 70 11 81 81 - - - - - - - - - 714

TLG Services, Inc.






Detailed Work Procedures (continued)3b.1.1.5 CRD housings & ICI tubes - - - - - - 70 11 81 81 - - - - - - - - - 714 3b.1.1.6 Incore instrumentation - - - - - - 70 11 81 81 - - - - - - - - - 714 3b.1.1.7 Reactor vessel - - - - - - 256 38 294 294 - - - - - - - - - 2,592 3b.1.1.8 Facility closeout - - - - - - 85 13 97 49 - 49 - - - - - - - 857 3b.1.1.9 Missile shields - - - - - - 32 5 36 36 - - - - - - - - - 321 3b.1.1.10 Biological shield - - - - - - 85 13 97 97 - - - - - - - - - 857 3b.1.1.11 Steam generators - - - - - - 324 49 373 373 - - - - - - - - - 3,284 3b.1.1.12 Reinforced concrete - - - - - - 70 11 81 41 - 41 - - - - - - - 714 3b.1.1.13 Main Turbine - - - - - - 110 16 126 - - 126 - - - - - - - 1,114 3b.1.1.14 Main Condensers - - - - - - 110 16 126 - - 126 - - - - - - - 1,114 3b.1.1.15 Auxiliary building - - - - - - 192 29 221 199 - 22 - - - - - - - 1,949 3b.1.1.16 Reactor building - - - - - - 192 29 221 199 - 22 - - - - - - - 1,949 3b.1.1 Total - - - - - - 2,272 341 2,613 2,106 - 507 - - - - - - - 23,022 3b.1 Subtotal Period 3b Activity Costs - - - - - - 2,272 341 2,613 2,106 - 507 - - - - - - - 23,022

Period 3b Collateral Costs3b.3.1 Decon equipment 924 - - - - - - 139 1,062 1,062 - - - - - - - - - - 3b.3.2 Staff relocation expenses - - - - - - 1,130 169 1,299 1,299 - - - - - - - - - - 3b.3.3 Pipe cutting equipment - 1,100 - - - - - 165 1,265 1,265 - - - - - - - - - - 3b.3 Subtotal Period 3b Collateral Costs 924 1,100 - - - - 1,130 473 3,627 3,627 - - - - - - - - - -

Period 3b Period-Dependent Costs3b.4.1 Decon supplies 29 - - - - - - 7 36 36 - - - - - - - - - - 3b.4.2 Insurance - - - - - - 289 29 318 318 - - - - - - - - - - 3b.4.3 Property taxes - - - - - - 13 1 14 14 - - - - - - - - - - 3b.4.4 Health physics supplies - 225 - - - - - 56 281 281 - - - - - - - - - - 3b.4.5 Heavy equipment rental - 287 - - - - - 43 330 330 - - - - - - - - - - 3b.4.6 Disposal of DAW generated - - 6 1 - 14 - 4 25 25 - - - 279 - - - 5,580 9 - 3b.4.7 Plant energy budget - - - - - - 374 56 431 431 - - - - - - - - - - 3b.4.8 NRC Fees - - - - - - 172 17 189 189 - - - - - - - - - - 3b.4.9 Corporate A&G - - - - - - 962 144 1,107 1,107 - - - - - - - - - - 3b.4.10 Site O&M - - - - - - 95 14 109 109 - - - - - - - - - - 3b.4.11 Security Staff Cost - - - - - - 480 72 552 552 - - - - - - - - - 18,207 3b.4.12 Utility Staff Cost - - - - - - 9,644 1,447 11,090 11,090 - - - - - - - - - 161,023 3b.4 Subtotal Period 3b Period-Dependent Costs 29 512 6 1 - 14 12,029 1,891 14,481 14,481 - - - 279 - - - 5,580 9 179,230

3b.0 TOTAL PERIOD 3b COST 952 1,612 6 1 - 14 15,431 2,705 20,720 20,214 - 507 - 279 - - - 5,580 9 202,251

PERIOD 3 TOTALS 952 2,584 17 3 - 38 43,024 7,173 53,790 52,990 - 800 - 776 - - - 15,530 8,192 522,675



Nuclear Steam Supply System Removal4a.1.1.1 Reactor Coolant Piping 40 189 27 25 174 275 - 169 900 900 - - 637 674 - - - 147,794 5,317 - 4a.1.1.2 Pressurizer Relief Tank 4 16 6 5 37 54 - 26 148 148 - - 136 136 - - - 30,174 492 - 4a.1.1.3 Reactor Coolant Pumps & Motors 16 68 72 197 - 1,263 - 378 1,994 1,994 - - - 4,511 - - - 807,600 2,700 80 4a.1.1.4 Pressurizer 10 47 328 84 - 1,155 - 351 1,975 1,975 - - - 4,126 - - - 55,804 1,578 750 4a.1.1.5 Steam Generators 65 3,001 2,253 1,220 3,037 6,746 - 3,333 19,655 19,655 - - 39,289 24,101 - - - 3,402,733 20,508 1,500 4a.1.1.6 CRDMs/ICIs/Service Structure Removal 29 108 353 86 166 272 - 182 1,196 1,196 - - 1,823 3,621 - - - 143,697 2,924 - 4a.1.1.7 Reactor Vessel Internals 51 2,513 9,348 1,036 - 3,137 244 6,111 22,439 22,439 - - - 2,867 125 344 - 334,226 23,417 1,069 4a.1.1.8 Vessel & Internals GTCC Disposal - - - - - 14,307 - 2,146 16,453 16,453 - - - - - - 2,499 500,800 - - 4a.1.1.9 Reactor Vessel - 4,663 1,572 492 - 2,614 244 5,357 14,942 14,942 - - - 9,340 - - - 950,584 23,417 1,069 4a.1.1 Totals 214 10,605 13,960 3,144 3,414 29,823 488 18,053 79,701 79,701 - - 41,885 49,377 125 344 2,499 6,373,412 80,353 4,467

Removal of Major Equipment4a.1.2 Main Turbine/Generator - 349 273 31 734 - - 229 1,617 1,617 - - 4,974 - - - - 298,467 8,374 - 4a.1.3 Main Condensers - 1,190 165 26 848 - - 445 2,672 2,672 - - 7,657 - - - - 344,574 29,249 -

Cascading Costs from Clean Building Demolition4a.1.4.1 Reactor - 508 - - - - - 76 584 584 - - - - - - - - 6,763 - 4a.1.4.2 AB - Battery & Cable Room (common) - 22 - - - - - 3 25 25 - - - - - - - - 295 - 4a.1.4.3 AB - FW Pump/Switchgear Area - 23 - - - - - 3 26 26 - - - - - - - - 299 - 4a.1.4.4 Auxiliary Building - 185 - - - - - 28 213 213 - - - - - - - - 2,409 - 4a.1.4.5 Auxiliary Service Building (common) - 101 - - - - - 15 116 116 - - - - - - - - 1,276 -

TLG Services, Inc.






Cascading Costs from Clean Building Demolition (continued)4a.1.4.6 Containment Mechanical Equipment - 6 - - - - - 1 7 7 - - - - - - - - 105 - 4a.1.4.7 Contaminated Materials Warehouse(common) - 23 - - - - - 3 26 26 - - - - - - - - 405 - 4a.1.4.8 Main Steam Doghouses - 100 - - - - - 15 115 115 - - - - - - - - 1,109 - 4a.1.4.9 Service Building (common) - 96 - - - - - 14 111 111 - - - - - - - - 1,607 - 4a.1.4.10 Turbine Building - 294 - - - - - 44 339 339 - - - - - - - - 4,856 - 4a.1.4.11 Upper Head Injection Tank Building - 5 - - - - - 1 6 6 - - - - - - - - 70 - 4a.1.4.12 Waste Solidification Facility (common) - 6 - - - - - 1 7 7 - - - - - - - - 78 - 4a.1.4.13 Fuel Building - 89 - - - - - 13 103 103 - - - - - - - - 1,173 - 4a.1.4 Totals - 1,458 - - - - - 219 1,677 1,677 - - - - - - - - 20,445 -

Disposal of Plant Systems4a.1.5.1 Aux Bldg Chilled Water - 89 2 3 109 - - 39 243 243 - - 1,094 - - - - 44,411 1,896 - 4a.1.5.2 Aux Bldg Rad Area Chilled Water (shared) - 119 3 5 166 - - 56 348 348 - - 1,663 - - - - 67,525 2,503 - 4a.1.5.3 Auxiliary Feedwater - 247 16 31 1,018 - - 221 1,532 1,532 - - 10,186 - - - - 413,660 5,567 - 4a.1.5.4 Auxiliary Steam - 19 - - - - - 3 22 - - 22 - - - - - - 564 - 4a.1.5.5 Auxiliary Steam RCA - 85 2 4 118 - - 40 248 248 - - 1,180 - - - - 47,930 1,840 - 4a.1.5.6 CCW Intake Screen Backwash - 5 - - - - - 1 6 - - 6 - - - - - - 142 - 4a.1.5.7 CO2 Gen Purge - 8 - - - - - 1 10 - - 10 - - - - - - 251 - 4a.1.5.8 Condensate - 369 - - - - - 55 424 - - 424 - - - - - - 10,260 - 4a.1.5.9 Condensate Storage - 75 - - - - - 11 86 - - 86 - - - - - - 2,003 - 4a.1.5.10 Condenser Cleaning - 40 - - - - - 6 46 - - 46 - - - - - - 1,125 - 4a.1.5.11 Condenser Steam Air Ejector - 34 - - - - - 5 40 - - 40 - - - - - - 996 - 4a.1.5.12 Containment Spray/Valve Inj Water - 234 5 10 339 - - 111 700 700 - - 3,389 - - - - 137,648 5,088 - 4a.1.5.13 Convent LP Service Water - 95 - - - - - 14 109 - - 109 - - - - - - 2,702 - 4a.1.5.14 Conventional Chemical Addition - 8 - - - - - 1 10 - - 10 - - - - - - 238 - 4a.1.5.15 Conventional Chemical Addition RCA - 15 0 0 11 - - 5 31 31 - - 109 - - - - 4,424 293 - 4a.1.5.16 Cooling Tower Water Treatment (shared) - 77 - - - - - 12 89 - - 89 - - - - - - 2,137 - 4a.1.5.17 DG Engine Cooling Water - 19 - - - - - 3 22 - - 22 - - - - - - 542 - 4a.1.5.18 DG Engine Fuel Oil - 67 - - - - - 10 77 - - 77 - - - - - - 1,753 - 4a.1.5.19 DG Engine Lube Oil - 36 - - - - - 5 41 - - 41 - - - - - - 998 - 4a.1.5.20 DG Engine Starting Air - 35 - - - - - 5 41 - - 41 - - - - - - 1,012 - 4a.1.5.21 DG Room Sump Pump - 6 - - - - - 1 7 - - 7 - - - - - - 175 - 4a.1.5.22 FDWP Condensate Seal - 22 - - - - - 3 25 - - 25 - - - - - - 632 - 4a.1.5.23 Feedwater - 54 - - - - - 8 62 - - 62 - - - - - - 1,527 - 4a.1.5.24 Feedwater Lube & Hydraulic Oil - 14 - - - - - 2 16 - - 16 - - - - - - 417 - 4a.1.5.25 Feedwater Pump Turbine Steam Seal - 3 - - - - - 0 3 - - 3 - - - - - - 80 - 4a.1.5.26 Feedwater RCA - 85 4 8 274 - - 64 436 436 - - 2,742 - - - - 111,348 1,971 - 4a.1.5.27 Generator Hydrogen - 7 - - - - - 1 8 - - 8 - - - - - - 217 - 4a.1.5.28 Generator Seal Oil - 11 - - - - - 2 12 - - 12 - - - - - - 312 - 4a.1.5.29 Heater Bleed Steam - 35 - - - - - 5 40 - - 40 - - - - - - 1,006 - 4a.1.5.30 Heater Drains - 135 - - - - - 20 155 - - 155 - - - - - - 3,866 - 4a.1.5.31 Heater Relief Valve - 20 - - - - - 3 23 - - 23 - - - - - - 525 - 4a.1.5.32 Heater Vent - 18 - - - - - 3 21 - - 21 - - - - - - 559 - 4a.1.5.33 Hydrogen Blanket & Bulk Storage (shared) - 15 - - - - - 2 17 - - 17 - - - - - - 436 - 4a.1.5.34 MN Turbine Lube Oil & Purification - 40 - - - - - 6 46 - - 46 - - - - - - 1,132 - 4a.1.5.35 Main Steam - 15 - - - - - 2 18 - - 18 - - - - - - 450 - 4a.1.5.36 Main Steam Bypass to Condenser - 27 - - - - - 4 31 - - 31 - - - - - - 784 - 4a.1.5.37 Main Steam Leakoff & Steam Seal - 9 - - - - - 1 10 - - 10 - - - - - - 249 - 4a.1.5.38 Main Steam RCA - 29 1 2 59 - - 16 107 107 - - 594 - - - - 24,127 614 - 4a.1.5.39 Main Steam Vent - 130 4 8 252 - - 72 465 465 - - 2,525 - - - - 102,559 2,942 - 4a.1.5.40 Main Vacuum (shared) - 11 - - - - - 2 12 - - 12 - - - - - - 291 - 4a.1.5.41 Makeup Demineralized Water (shared) - 108 - - - - - 16 124 - - 124 - - - - - - 3,097 - 4a.1.5.42 Miscellaneous Equipment - 1 - - - - - 0 1 - - 1 - - - - - - 18 - 4a.1.5.43 Moisture Separator Reheater Bld Steam - 5 - - - - - 1 6 - - 6 - - - - - - 156 - 4a.1.5.44 Moisture Separator Reheater Drain - 152 - - - - - 23 175 - - 175 - - - - - - 4,238 - 4a.1.5.45 Nitrogen (shared) - 13 - - - - - 2 15 - - 15 - - - - - - 402 - 4a.1.5.46 Recirculated Cooling Water (shared) - 138 - - - - - 21 159 - - 159 - - - - - - 3,964 - 4a.1.5.47 SG Wet Layup Recirculation - 21 0 1 17 - - 8 47 47 - - 174 - - - - 7,060 429 - 4a.1.5.48 SM Supply to Aux Equipment - 26 - - - - - 4 30 - - 30 - - - - - - 762 - 4a.1.5.49 SM Supply to Aux Equipment RCA - 10 0 0 10 - - 4 25 25 - - 100 - - - - 4,077 216 - 4a.1.5.50 Standby Shutdown Diesel - 6 - - - - - 1 7 - - 7 - - - - - - 158 - 4a.1.5.51 Steam Generator Blowdown Recycle - 283 13 26 850 - - 203 1,375 1,375 - - 8,510 - - - - 345,600 6,607 - 4a.1.5.52 Steam Supply to FW Pump Turbine - 26 - - - - - 4 29 - - 29 - - - - - - 743 - 4a.1.5.53 Turbine Crossover - 3 - - - - - 1 4 - - 4 - - - - - - 102 - 4a.1.5.54 Turbine Exhaust - 2 - - - - - 0 2 - - 2 - - - - - - 64 - 4a.1.5.55 Turbine Hydraulic Oil - 10 - - - - - 2 12 - - 12 - - - - - - 298 -

TLG Services, Inc.






Disposal of Plant Systems (continued)4a.1.5.56 Vacuum Priming (shared) - 18 - - - - - 3 21 - - 21 - - - - - - 519 - 4a.1.5 Totals - 3,186 50 98 3,224 - - 1,116 7,673 5,559 - 2,115 32,267 - - - - 1,310,369 81,872 -

4a.1.6 Scaffolding in support of decommissioning - 3,131 21 5 100 19 - 805 4,080 4,080 - - 901 79 - - - 45,817 32,820 -

4a.1 Subtotal Period 4a Activity Costs 214 19,919 14,469 3,304 8,319 29,842 488 20,867 97,422 95,307 - 2,115 87,684 49,456 125 344 2,499 8,372,639 253,114 4,467


Period 4a Collateral Costs4a.3.1 Process decommissioning water waste 3 - 3 17 - 19 - 9 50 50 - - - 45 - - - 2,715 9 - 4a.3.3 Small tool allowance - 199 - - - - - 30 228 205 - 23 - - - - - - - - 4a.3 Subtotal Period 4a Collateral Costs 3 199 3 17 - 19 - 39 279 256 - 23 - 45 - - - 2,715 9 -

Period 4a Period-Dependent Costs4a.4.1 Decon supplies 71 - - - - - - 18 89 89 - - - - - - - - - - 4a.4.2 Insurance - - - - - - 719 72 790 790 - - - - - - - - - - 4a.4.3 Property taxes - - - - - - 32 3 35 31 - 3 - - - - - - - - 4a.4.4 Health physics supplies - 1,827 - - - - - 457 2,284 2,284 - - - - - - - - - - 4a.4.5 Heavy equipment rental - 2,728 - - - - - 409 3,137 3,137 - - - - - - - - - - 4a.4.6 Disposal of DAW generated - - 79 12 - 179 - 54 324 324 - - - 3,658 - - - 73,161 119 - 4a.4.7 Plant energy budget - - - - - - 883 133 1,016 1,016 - - - - - - - - - - 4a.4.8 NRC Fees - - - - - - 533 53 586 586 - - - - - - - - - - 4a.4.9 Liquid Radwaste Processing Equipment/Services - - - - - - 503 75 578 578 - - - - - - - - - - 4a.4.10 Corporate A&G - - - - - - 2,785 418 3,203 3,203 - - - - - - - - - - 4a.4.11 Site O&M - - - - - - 256 38 294 294 - - - - - - - - - - 4a.4.12 Security Staff Cost - - - - - - 1,374 206 1,581 1,581 - - - - - - - - - 55,440 4a.4.13 Utility Staff Cost - - - - - - 27,861 4,179 32,041 32,041 - - - - - - - - - 465,960 4a.4 Subtotal Period 4a Period-Dependent Costs 71 4,555 79 12 - 179 34,945 6,116 45,957 45,954 - 3 - 3,658 - - - 73,161 119 521,400

4a.0 TOTAL PERIOD 4a COST 288 24,672 14,551 3,333 8,319 30,039 36,718 27,407 145,328 143,187 - 2,141 87,684 53,159 125 344 2,499 8,448,514 279,553 525,867


Period 4b Direct Decommissioning Activities4b.1.1 Remove spent fuel racks 329 36 167 90 - 885 - 425 1,932 1,932 - - - 3,751 - - - 247,922 1,033 -

Disposal of Plant Systems4b.1.2.1 Admin Bldg Chilled Water (shared) - 14 - - - - - 2 17 - - 17 - - - - - - 416 - 4b.1.2.2 Admin Bldg Ventilation (shared) - 6 - - - - - 1 7 - - 7 - - - - - - 181 - 4b.1.2.3 Annulus Ventilation - 33 2 4 130 - - 29 197 197 - - 1,299 - - - - 52,733 723 - 4b.1.2.4 Aux & RB Heating Water - 479 6 12 398 - - 182 1,077 1,077 - - 3,982 - - - - 161,718 10,064 - 4b.1.2.5 Aux Bldg Ventilation - 172 8 15 511 - - 123 829 829 - - 5,113 - - - - 207,636 3,978 - 4b.1.2.6 Boron Recycle - 371 27 32 416 190 - 210 1,246 1,246 - - 4,161 811 - - - 222,327 8,665 - 4b.1.2.7 Boron Thermal Regeneration - 263 40 42 113 383 - 189 1,029 1,029 - - 1,132 1,619 - - - 153,131 6,169 - 4b.1.2.8 Breathing Air (shared) - 154 2 3 104 - - 55 316 316 - - 1,037 - - - - 42,110 3,483 - 4b.1.2.9 Chemical & Volume Control - 635 155 157 520 1,392 - 624 3,483 3,483 - - 5,204 5,898 - - - 601,372 14,828 - 4b.1.2.10 Comp Room Chilled Water (shared) - 46 - - - - - 7 53 - - 53 - - - - - - 1,295 - 4b.1.2.11 Component Cooling - 108 - - - - - 16 124 - - 124 - - - - - - 3,092 - 4b.1.2.12 Component Cooling RCA - 153 5 9 306 - - 86 560 560 - - 3,066 - - - - 124,493 3,199 - 4b.1.2.13 Computer Air Cond. (shared) - 25 2 4 130 - - 27 188 188 - - 1,296 - - - - 52,647 510 - 4b.1.2.14 Condenser Circulating Water - 98 - - - - - 15 113 - - 113 - - - - - - 2,781 - 4b.1.2.15 Cont Air Release & Addition - 38 1 1 43 - - 16 100 100 - - 435 - - - - 17,669 898 - 4b.1.2.16 Cont Air Return Ex & H2 Skimmer - 95 2 5 149 - - 47 297 297 - - 1,488 - - - - 60,418 2,252 - 4b.1.2.17 Cont CRD, & ICI Room Vent - 82 9 14 318 43 - 82 547 547 - - 3,184 182 - - - 141,365 1,958 - 4b.1.2.18 Cont Water Sample & Purge - 9 0 0 3 - - 3 14 14 - - 28 - - - - 1,154 217 - 4b.1.2.19 Containment Chilled Water - 26 - - - - - 4 30 - - 30 - - - - - - 712 - 4b.1.2.20 Containment Chilled Water RCA - 74 2 4 141 - - 41 262 262 - - 1,407 - - - - 57,124 1,665 - 4b.1.2.21 Containment Purge Ventilation - 162 9 18 589 - - 132 911 911 - - 5,899 - - - - 239,572 3,827 - 4b.1.2.22 Control Area Chilled Water (shared) - 314 6 12 396 - - 140 870 870 - - 3,969 - - - - 161,176 6,751 - 4b.1.2.23 Control Area HVAC (shared) - 72 6 12 383 - - 78 551 551 - - 3,834 - - - - 155,703 1,662 - 4b.1.2.24 Conventional Sampling - 338 30 24 74 220 - 157 844 844 - - 745 927 - - - 91,773 7,906 - 4b.1.2.25 Conventional Waste Mont & Treat (shared) - 90 - - - - - 13 103 - - 103 - - - - - - 2,469 - 4b.1.2.26 Convntl Waste Mont & Treat (shared) RCA - 227 6 12 390 - - 118 753 753 - - 3,901 - - - - 158,411 5,082 -

TLG Services, Inc.






Disposal of Plant Systems (continued)4b.1.2.27 Diesel Bldg Ventilation - 9 - - - - - 1 10 - - 10 - - - - - - 254 - 4b.1.2.28 Drinking Water (shared) - 48 - - - - - 7 55 - - 55 - - - - - - 1,400 - 4b.1.2.29 Electrical (clean) - 2,774 - - - - - 416 3,190 - - 3,190 - - - - - - 73,972 - 4b.1.2.30 Electrical (contaminated) - 847 17 30 756 67 - 348 2,064 2,064 - - 7,563 285 - - - 325,996 19,386 - 4b.1.2.31 Electrical (contaminated) RCA - 5,861 113 216 7,143 - - 2,581 15,915 15,915 - - 71,504 - - - - 2,903,830 129,195 - 4b.1.2.32 Equipment Decon - 31 1 1 37 - - 13 83 83 - - 368 - - - - 14,936 716 - 4b.1.2.33 FHB Ventilation - 65 5 10 317 - - 66 463 463 - - 3,177 - - - - 129,020 1,448 - 4b.1.2.34 Filtered Water (shared) - 68 - - - - - 10 79 - - 79 - - - - - - 1,811 - 4b.1.2.35 Filtered Water (shared) RCA - 29 1 1 41 - - 14 85 85 - - 412 - - - - 16,721 637 - 4b.1.2.36 Fire Protection - 45 - - - - - 7 51 - - 51 - - - - - - 1,274 - 4b.1.2.37 Fire Protection (shared) - 413 - - - - - 62 475 - - 475 - - - - - - 11,816 - 4b.1.2.38 Fire Protection RCA - 128 4 7 238 - - 69 447 447 - - 2,383 - - - - 96,755 2,919 - 4b.1.2.39 Gaseous Waste Management (shared) - 253 22 22 228 146 - 139 810 810 - - 2,285 618 - - - 133,671 5,794 - 4b.1.2.40 Groundwater Drainage (shared) - 22 - - - - - 3 25 - - 25 - - - - - - 591 - 4b.1.2.41 Heating Boiler Feedwater (shared) - 52 - - - - - 8 60 - - 60 - - - - - - 1,454 - 4b.1.2.42 Ice Condenser Refrigeration - 502 13 26 851 - - 258 1,651 1,651 - - 8,522 - - - - 346,098 11,241 - 4b.1.2.43 Instrument Air - 203 - - - - - 30 234 - - 234 - - - - - - 6,051 - 4b.1.2.44 Instrument Air RCA - 728 9 17 566 - - 270 1,590 1,590 - - 5,663 - - - - 229,971 15,129 - 4b.1.2.45 Liquid Waste Recycle - 839 103 103 357 915 - 518 2,835 2,835 - - 3,575 3,886 - - - 401,497 19,364 - 4b.1.2.46 Miscellaneous Ventilation - 46 - - - - - 7 52 - - 52 - - - - - - 1,469 - 4b.1.2.47 Nuclear Prod Office Chilled Water (shrd) - 23 - - - - - 3 27 - - 27 - - - - - - 681 - 4b.1.2.48 Nuclear Sampling - 273 22 17 45 154 - 118 630 630 - - 450 651 - - - 61,495 6,541 - 4b.1.2.49 Nuclear Service Water - 67 - - - - - 10 77 - - 77 - - - - - - 1,898 - 4b.1.2.50 Nuclear Service Water Pump Vent - 1 - - - - - 0 1 - - 1 - - - - - - 31 - 4b.1.2.51 Nuclear Service Water RCA - 519 18 35 1,165 - - 312 2,050 2,050 - - 11,665 - - - - 473,732 11,623 - 4b.1.2.52 Nuclear Solid Waste Disposal (shared) - 249 30 31 154 257 - 157 878 878 - - 1,542 1,097 - - - 134,661 5,715 - 4b.1.2.53 Oxygen (shared) - 4 - - - - - 1 5 - - 5 - - - - - - 124 - 4b.1.2.54 Reactor Coolant - 112 29 36 155 311 - 137 781 781 - - 1,550 1,319 - - - 150,136 2,759 - 4b.1.2.55 Refueling Water - 297 8 16 529 - - 157 1,007 1,007 - - 5,296 - - - - 215,058 7,072 - 4b.1.2.56 Residual Heat Removal - 141 28 29 82 262 - 120 662 662 - - 824 1,109 - - - 106,875 3,325 - 4b.1.2.57 Safety Injection - 437 56 69 907 407 - 363 2,238 2,238 - - 9,075 1,723 - - - 482,416 10,269 - 4b.1.2.58 Sanitation & Waste Treatment (shared) - 31 - - - - - 5 35 - - 35 - - - - - - 887 - 4b.1.2.59 Service Bldg & Warehouse Vent (shared) - 49 - - - - - 7 56 - - 56 - - - - - - 1,508 - 4b.1.2.60 Service Bldg Chilled Water (shared) - 40 - - - - - 6 46 - - 46 - - - - - - 1,165 - 4b.1.2.61 Spent Fuel Cooling - 199 18 19 129 153 - 112 629 629 - - 1,287 646 - - - 95,060 4,629 - 4b.1.2.62 Station Air (shared) - 23 - - - - - 4 27 - - 27 - - - - - - 685 - 4b.1.2.63 Station Air (shared) RCA - 274 3 6 214 - - 102 599 599 - - 2,140 - - - - 86,897 5,628 - 4b.1.2.64 TB & Service Bldg Sump & Drains (shared) - 45 - - - - - 7 52 - - 52 - - - - - - 1,261 - 4b.1.2.65 Tech Support Center Vent (shared) - 5 - - - - - 1 6 - - 6 - - - - - - 145 - 4b.1.2.66 Turbine Building Ventilation - 101 - - - - - 15 116 - - 116 - - - - - - 3,108 - 4b.1.2 Totals - 19,937 819 1,072 19,027 4,901 - 8,861 54,616 49,491 - 5,125 190,459 20,772 - - - 9,107,356 469,757 -

4b.1.3 Scaffolding in support of decommissioning - 4,696 32 7 150 28 - 1,208 6,121 6,121 - - 1,352 119 - - - 68,726 49,230 -

Decontamination of Site Buildings4b.1.4.1 Reactor 1,031 705 42 264 949 463 - 994 4,448 4,448 - - 9,498 6,886 - - - 974,121 37,168 - 4b.1.4.2 Auxiliary Building 458 150 7 67 83 112 - 318 1,194 1,194 - - 833 1,840 - - - 191,777 13,949 - 4b.1.4.3 Auxiliary Service Building (common) 29 10 1 2 13 4 - 20 78 78 - - 126 59 - - - 9,732 907 - 4b.1.4.4 Containment Mechanical Equipment 20 14 1 3 12 5 - 17 72 72 - - 122 77 - - - 11,289 781 - 4b.1.4.5 Contaminated Materials Warehouse(common) 63 14 1 9 - 15 - 40 142 142 - - - 259 - - - 22,428 1,752 - 4b.1.4.6 Monitor Tank Building (common) 77 3 0 1 - 2 - 40 124 124 - - - 37 - - - 3,180 1,945 - 4b.1.4.7 RMC Bldg - New Structure 2 7 0 3 - 5 - 4 22 22 - - - 88 - - - 7,650 175 - 4b.1.4.8 Waste Solidification Facility (common) 12 8 0 2 9 4 - 11 46 46 - - 93 54 - - - 8,097 459 - 4b.1.4.9 Fuel Building 701 747 10 24 339 51 - 606 2,479 2,479 - - 3,393 480 - - - 176,541 32,981 - 4b.1.4 Totals 2,393 1,658 61 376 1,405 661 - 2,050 8,604 8,604 - - 14,065 9,780 - - - 1,404,816 90,118 -


Period 4b Additional Costs4b.2.1 License Termination Survey Planning - - - - - - 830 249 1,079 1,079 - - - - - - - - - 6,240 4b.2.2 RP Storage Tent Asphalt Disposal - 6 1 61 - 172 - 54 293 293 - - - 2,925 - - - 351,000 135 - 4b.2.3 Pond Closures - - - - - - 3,341 501 3,842 - - 3,842 - - - - - - 9,285 - 4b.2.4 Underground Services Excavation - 1,955 - - - - 835 419 3,209 - - 3,209 - - - - - - 14,000 - 4b.2.5 Decommissioning of ISFSI - 641 236 403 - 2,438 2,370 1,522 7,610 7,610 - - - 10,462 - - - 699,382 13,466 10,833 4b.2.6 Remedial Action Surveys - - - - - - 1,313 394 1,707 1,707 - - - - - - - - 26,880 - 4b.2 Subtotal Period 4b Additional Costs - 2,602 237 464 - 2,610 8,688 3,138 17,739 10,689 - 7,051 - 13,387 - - - 1,050,382 63,765 17,073

TLG Services, Inc.






Period 4b Collateral Costs4b.3.1 Process decommissioning water waste 12 - 14 73 - 82 - 39 219 219 - - - 197 - - - 11,806 38 - 4b.3.3 Small tool allowance - 430 - - - - - 64 494 494 - - - - - - - - - - 4b.3.4 Decommissioning Equipment Disposition - - 141 37 664 125 - 151 1,118 1,118 - - 6,000 529 - - - 304,968 88 - 4b.3 Subtotal Period 4b Collateral Costs 12 430 155 110 664 207 - 254 1,831 1,831 - - 6,000 726 - - - 316,774 127 -

Period 4b Period-Dependent Costs4b.4.1 Decon supplies 960 - - - - - - 240 1,200 1,200 - - - - - - - - - - 4b.4.2 Insurance - - - - - - 734 73 808 808 - - - - - - - - - - 4b.4.3 Property taxes - - - - - - 32 3 35 35 - - - - - - - - - - 4b.4.4 Health physics supplies - 3,525 - - - - - 881 4,406 4,406 - - - - - - - - - - 4b.4.5 Heavy equipment rental - 2,759 - - - - - 414 3,173 3,173 - - - - - - - - - - 4b.4.6 Disposal of DAW generated - - 159 24 - 361 - 110 654 654 - - - 7,391 - - - 147,820 241 - 4b.4.7 Plant energy budget - - - - - - 713 107 819 819 - - - - - - - - - - 4b.4.8 NRC Fees - - - - - - 544 54 599 599 - - - - - - - - - - 4b.4.9 Liquid Radwaste Processing Equipment/Services - - - - - - 513 77 590 590 - - - - - - - - - - 4b.4.10 Corporate A&G - - - - - - 2,402 360 2,762 2,762 - - - - - - - - - - 4b.4.11 Site O&M - - - - - - 221 33 254 254 - - - - - - - - - - 4b.4.12 Security Staff Cost - - - - - - 1,404 211 1,615 1,615 - - - - - - - - - 56,640 4b.4.13 Utility Staff Cost - - - - - - 24,165 3,625 27,790 27,790 - - - - - - - - - 401,874 4b.4 Subtotal Period 4b Period-Dependent Costs 960 6,284 159 24 - 361 30,729 6,189 44,706 44,706 - - - 7,391 - - - 147,820 241 458,514

4b.0 TOTAL PERIOD 4b COST 3,694 35,643 1,629 2,144 21,246 9,653 39,417 22,123 135,549 123,373 - 12,176 211,876 55,925 - - - 12,343,800 674,271 475,588





Period 4f Period-Dependent Costs4f.4.2 Property taxes - - - - - - 19 2 21 21 - - - - - - - - - - 4f.4.3 Health physics supplies - 844 - - - - - 211 1,055 1,055 - - - - - - - - - - 4f.4.4 Disposal of DAW generated - - 7 1 - 16 - 5 29 29 - - - 330 - - - 6,603 11 - 4f.4.5 Plant energy budget - - - - - - 111 17 127 127 - - - - - - - - - - 4f.4.6 NRC Fees - - - - - - 304 30 335 335 - - - - - - - - - - 4f.4.7 Corporate A&G - - - - - - 571 86 656 656 - - - - - - - - - - 4f.4.8 Site O&M - - - - - - 53 8 61 61 - - - - - - - - - - 4f.4.9 Security Staff Cost - - - - - - 337 51 388 388 - - - - - - - - - 11,786 4f.4.10 Utility Staff Cost - - - - - - 6,142 921 7,063 7,063 - - - - - - - - - 95,464 4f.4 Subtotal Period 4f Period-Dependent Costs - 844 7 1 - 16 7,536 1,330 9,734 9,734 - - - 330 - - - 6,603 11 107,250

4f.0 TOTAL PERIOD 4f COST - 844 7 1 - 16 17,872 4,261 23,002 23,002 - - - 330 - - - 6,603 207,446 110,370

PERIOD 4 TOTALS 3,983 61,159 16,187 5,478 29,565 39,708 94,008 53,792 303,879 289,562 - 14,317 299,560 109,415 125 344 2,499 20,798,910 1,161,270 1,111,825



Demolition of Remaining Site Buildings5b.1.1.1 Reactor - 2,883 - - - - - 432 3,316 - - 3,316 - - - - - - 38,439 - 5b.1.1.2 AB - Battery & Cable Room (common) - 204 - - - - - 31 235 - - 235 - - - - - - 2,772 - 5b.1.1.3 AB - FW Pump/Switchgear Area - 208 - - - - - 31 239 - - 239 - - - - - - 2,750 - 5b.1.1.4 Administration Building (common) - 246 - - - - - 37 283 - - 283 - - - - - - 4,366 - 5b.1.1.5 Auxiliary Building - 1,692 - - - - - 254 1,946 - - 1,946 - - - - - - 22,370 - 5b.1.1.6 Auxiliary Service Building (common) - 917 - - - - - 138 1,055 - - 1,055 - - - - - - 11,789 - 5b.1.1.7 Containment Mechanical Equipment - 59 - - - - - 9 67 - - 67 - - - - - - 1,085 -

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Demolition of Remaining Site Buildings (continued)5b.1.1.8 Contaminated Materials Warehouse(common) - 263 - - - - - 40 303 - - 303 - - - - - - 5,478 - 5b.1.1.9 Cooling Towers (3) - 2,246 - - - - - 337 2,583 - - 2,583 - - - - - - 34,180 - 5b.1.1.10 Diesel Generator Building - 332 - - - - - 50 382 - - 382 - - - - - - 4,152 - 5b.1.1.11 Lagoons & Yard Basins (common) - 202 - - - - - 30 232 - - 232 - - - - - - 3,401 - 5b.1.1.12 Low Pressure Service Water (common) - 280 - - - - - 42 322 - - 322 - - - - - - 3,570 - 5b.1.1.13 Main Steam Doghouses - 905 - - - - - 136 1,041 - - 1,041 - - - - - - 10,075 - 5b.1.1.14 Misc Structures - New Additions - 107 - - - - - 16 123 - - 123 - - - - - - 1,368 - 5b.1.1.15 Miscellaneous Structures (common) - 4,984 - - - - - 748 5,732 - - 5,732 - - - - - - 74,828 - 5b.1.1.16 Monitor Tank Building (common) - 369 - - - - - 55 424 - - 424 - - - - - - 6,276 - 5b.1.1.17 Nuc.Sevice Water Struct/Piping (common) - 1,102 - - - - - 165 1,267 - - 1,267 - - - - - - 7,798 - 5b.1.1.18 RMC Bldg - New Structure - 116 - - - - - 17 134 - - 134 - - - - - - 1,478 - 5b.1.1.19 Service Building (common) - 980 - - - - - 147 1,127 - - 1,127 - - - - - - 18,025 - 5b.1.1.20 Standby Shutdown Facility (common) - 57 - - - - - 9 65 - - 65 - - - - - - 954 - 5b.1.1.21 Steam Generator Drain Tank Bldg (common) - 50 - - - - - 7 57 - - 57 - - - - - - 896 - 5b.1.1.22 Turbine Building - 2,800 - - - - - 420 3,220 - - 3,220 - - - - - - 47,944 - 5b.1.1.23 Turbine Pedestal - 693 - - - - - 104 796 - - 796 - - - - - - 7,683 - 5b.1.1.24 Upper Head Injection Tank Building - 44 - - - - - 7 50 - - 50 - - - - - - 633 - 5b.1.1.25 Waste Solidification Facility (common) - 56 - - - - - 8 65 - - 65 - - - - - - 800 - 5b.1.1.26 Fuel Building - 824 - - - - - 124 947 - - 947 - - - - - - 11,073 - 5b.1.1 Totals - 22,619 - - - - - 3,393 26,012 - - 26,012 - - - - - - 324,179 -

Site Closeout Activities5b.1.2 BackFill Site - 13,358 - - - - - 2,004 15,362 - - 15,362 - - - - - - 23,118 - 5b.1.3 Grade & landscape site - 304 - - - - - 46 349 - - 349 - - - - - - 631 - 5b.1.4 Final report to NRC - - - - - - 110 16 126 126 - - - - - - - - - 1,114 5b.1 Subtotal Period 5b Activity Costs - 36,281 - - - - 110 5,459 41,850 126 - 41,724 - - - - - - 347,928 1,114

Period 5b Additional Costs5b.2.1 Concrete Crushing - 977 - - - - 6 148 1,131 - - 1,131 - - - - - - 4,716 - 5b.2.2 Demolition of ISFSI - 902 - - - - 54 143 1,100 - - 1,100 - - - - - - 1,533 160 5b.2 Subtotal Period 5b Additional Costs - 1,880 - - - - 60 291 2,231 - - 2,231 - - - - - - 6,249 160


Period 5b Period-Dependent Costs5b.4.2 Property taxes - - - - - - 41 4 45 - - 45 - - - - - - - - 5b.4.3 Heavy equipment rental - 5,027 - - - - - 754 5,781 - - 5,781 - - - - - - - - 5b.4.4 Plant energy budget - - - - - - 121 18 139 - - 139 - - - - - - - - 5b.4.5 Security Staff Cost - - - - - - 684 103 787 - - 787 - - - - - - - 22,807 5b.4.6 Utility Staff Cost - - - - - - 8,169 1,225 9,395 - - 9,395 - - - - - - - 130,720 5b.4 Subtotal Period 5b Period-Dependent Costs - 5,027 - - - - 9,016 2,104 16,148 - - 16,148 - - - - - - - 153,527

5b.0 TOTAL PERIOD 5b COST - 43,450 - - - - 9,987 8,014 61,451 126 - 61,324 - - - - - - 354,177 154,801

PERIOD 5 TOTALS - 43,450 - - - - 9,987 8,014 61,451 126 - 61,324 - - - - - - 354,177 154,801

TOTAL COST TO DECOMMISSION 9,387 115,071 16,500 6,189 29,581 40,888 473,984 118,408 810,007 594,452 136,917 78,638 299,679 119,746 125 344 2,499 21,086,370 1,595,959 5,172,993

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Catawba Nuclear Station Document D03-1671-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 1 of 2

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APPENDIX E

ISFSI DECOMMISSIONING COST SUMMARY


Document D03-1671-001, Rev. 0Appendix E, Page 2 of 2

Activity Description

Removal Costs

Packaging Costs

Transport Costs

LLRW Disposal

Costs

Other Costs

Total Costs

Burial VolumeClass A

(cubic feet)

Craft Manhours

Oversight and

Contractor Manhours

Hours

Decommissioning ContractorPlanning (characterization, specs and procedures) - - - - 232.7 232.7 - - 1,096 Decontamination (activated liner removal) 356.8 236.1 403.0 2,438.5 - 3,434.4 10,462 3,294 License Termination (radiological surveys) - - - - 1,138.9 1,138.9 - 10,172 - NRC and NRC Contractor Fees and Costs - - - - 406.9 406.9 - - 776

Subtotal 356.8 236.1 403.0 2,438.5 1,778.5 5,212.9 10,462.0 13,466 1,872

Supporting CostsInsurance - - - - 81.6 81.6 Property taxes - - - - 16.8 16.8 Heavy equipment rental 283.8 - - - - 283.8 Plant energy budget - - - - 24.8 24.8 Corporate A&G - - - - 23.1 23.1 Site O&M - - - - 1.0 1.0 Security Staff Cost - - - - 198.3 198.3 5,096 Oversight Staff Cost - - - - 245.8 245.8 3,866

Subtotal 283.8 - - - 591.2 875.0 - - 8,961

Total (w/o contingency) 640.6 236.1 403.0 2,438.5 2,369.7 6,087.9 10,462 13,466 10,833

Total (w/25% contingency) 800.8 295.1 503.8 3,048.1 2,962.2 7,609.9

Table E Catawba Nuclear Station

ISFSI Decommissioning Cost Estimate(thousands of 2013 dollars)

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Decommissioning Cost Analysis for the Catawba Nuclear Station