RS-09-114, Site-Specific Safstor Decommissioning Cost Estimate

Site-Specific Safstor Decommissioning Cost Estimate

ML092400244
Person / Time
Site:	LaSalle
Issue date:	08/27/2009
From:	Simpson P Exelon Generation Co, Exelon Nuclear
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
RS-09-114 E16-1555-012, Rev. 0
Download: ML092400244 (182)

Text

Exelon Nuclear 4300 Wintield Road Warrenville, lL 60555 Nuclear 10 CFR 50.75(f)(1)

August 27,2009 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 LaSalle County Station, Units 1 and 2 Facility Operating License Nos. NPF-11 and NPF-18 NRC Docket Nos. 50-373 and 50-374

Subject:

Submittal of LaSalle County Station Site-Specific SAFSTOR Decommissioning Cost Estimate

Reference:

Letter from Keith R. Jury (Exelon Generation Company) to U.S. NRC, "Decommissioning Funding Assurance Plan," dated July 29, 2009 In the referenced letter, Exelon Generation Company, LLC (EGC) committed to provide a site-specific SAFSTOR Decommissioning Cost Estimate (DCE) for LaSalle County Station, (LCS), Units 1 and 2. The DCE is provided as Attachment 1, and, in accordance with 10 CFR 50.75(b)(1), is greater than the amount specified in 10 CFR 50.75(c) for both Unit 1 and Unit 2. The DCE has been performed assuming that LCS Units 1 and 2 are granted license extension, since it is intended to reflect the most likely decommissioning scenario for LCS. However, this determination of the minimum funding requirement does not credit the additional 20-year license renewal period. shows the radiological decommissioning (license termination) cash flow based on the DCE in Attachment 1, assuming the SAFSTOR scenario, and does not include the costs of dismantling non-radiological systems and structures or the cost of managing and storing spent fuel onsite. EGC has not made a final determination of the decommissioning approach for LCS. For the purpose of choosing a decommissioning option to demonstrate adequacy of funding to meet regulatory requirements, the SAFSTOR option has been selected. EGC may choose a different decommissioning option in the future, recognizing that the chosen option must meet NRC requirements for decommissioning funding.

August 27,2009 U.S. Nuclear Regulatory Commission Page 2 The costs presented in Attachment 2 occur 20 years earlier than those in the Attachment 1 DCE to model the current license expiration date. No credit is taken for license renewal. The cash flow analysis assumes a 2% annual real rate of return on trust fund dollars until plant shutdown and on remaining trust fund dollars through the decommissioning period. The site-specific estimate is based on a period of safe storage specifically described in the Attachment 1 DCE. The Attachment 1 DCE presents the results in 2009 dollars. These results are escalated to July 31, 2009 by using the latest site-specific escalation factor, which is re-calculated on an annual basis.

For LCS Units 1 and 2, the decommissioning funding assurance is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(l)(i). There are no additional amounts to be collected from ratepayers for LCS, nor are there any contracts relied upon to pursuant to 10 CFR 50.75(e)(l)(v). presents the calculation of radiological decommissioning funding assurance. The Tables in Attachment 3 compare the funding assurance, calculated using the NRC generic formula, as recently published by the NRC, to the funding assurance calculated using the site-specific DCE methodology, as allowed by 10 CFR 50.75(e)(l)(i). Based on the site-specific methodology, and July 31, 2009 trust fund values, LCS, Units 1 and 2 meet all NRC radiological decommissioning funding assurance requirements.

There are no new regulatory commitments contained in this letter.

If you have any questions about this letter, please contact Patrick Simpson at (630) 657-2823.

Patrick R. Simpson V

Manager - Licensing Exelon Generation Company, LLC Attachments: 1. LaSalle County Station, Units 1 and 2, Decommissioning Cost Estimate

2. LaSalle County Station, Units 1 and 2, Radiological Decommissioning Projected SAFSTOR Cash Flow

3. LaSalle County Station, Units 1 and 2, NRC Funding Assurance Calculations

ATTACHMENT 1 LaSalle County Station, Units 1 and 2 Decommissioning Cost Estimate

Document E16-1555-012, Rev. 0 DECOMMISSIONING COST ANALYSIS for the LaSALLE COUNTY STATION UNITS 1 AND 2 prepared for Exelon Generation Company LLC prepared by TLG Services, Inc.

Bridgewater, Connecticut June 2009

LaSalle County Station Decommissioning Cost Analysis APPROVALS Document E16-1555-012, Rev. 0 Page ii ofxviii Project Ma,nager Project Engineer Technical Manager Quality Assurance Manager (acting)

TLG Services, Inc.

0' -Qs-zoo9 Date u/r£1 Date

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TABLE OF CONTENTS SECTION PAGE EXECUTIVE

SUMMARY

.............................................................................vii-xviii

1.

INTRODUCTION...................................................................................................1-1 1.1 Objectives of Study...........................................................................................1-1 1.2 Site Description.................................................................................................1-1 1.3 Regulatory Guidance........................................................................................1-2 1.3.1 Nuclear Waste Policy Act......................................................................1-4 1.3.2 Low-Level Radioactive Waste Acts......................................................1-6 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....................................................................2-8 2.1.4 ISFSI Operations and Decommissioning............................................2-9 2.2 SAFSTOR and DELAYED DECON................................................................2-9 2.2.1 Period 1 - Preparations.......................................................................2-10 2.2.2 Period 2 - Dormancy............................................................................2-11 2.2.3 Periods 3 and 4 - Delayed Decommissioning.....................................2-12 2.2.4 Period 5 - Site Restoration..................................................................2-13

3.

COST ESTIMATE...................................................................................................3-1 3.1 Basis of Estimate..............................................................................................3-1 3.2 Methodology......................................................................................................3-1 3.3 Impact of Decommissioning Multiple Reactor Units.....................................3-3 3.4 Financial Components of the Cost Model.......................................................3-4 3.4.1 Contingency...........................................................................................3-4 3.4.2 Financial Risk........................................................................................3-7 3.5 Site-Specific Considerations.............................................................................3-8 3.5.1 Spent Fuel Management.......................................................................3-8 3.5.2 Reactor Vessel and Internal Components.........................................3-11 3.5.3 Primary System Components.............................................................3-12 3.5.4 Main Turbine and Condenser.............................................................3-12 3.5.5 Transportation Methods.....................................................................3-13 3.5.6 Low-Level Radioactive Waste Disposal.............................................3-13 3.5.7 Site Conditions Following Decommissioning....................................3-15

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TABLE OF CONTENTS (continued)

SECTION PAGE 3.6 Assumptions....................................................................................................3-15 3.6.1 Estimating Basis.................................................................................3-15 3.6.2 Labor Costs..........................................................................................3-16 3.6.3 Design Conditions................................................................................3-16 3.6.4 General.................................................................................................3-17 3.7 Cost Estimate Summary...............................................................................3-19

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 Summary of Decommissioning Cost Elements, DECON............................... xvi Summary of Decommissioning Cost Elements, Delayed DECON................ xvii Summary of Decommissioning Cost Elements, SAFSTOR..........................xviii 3.1a Schedule of Total Annual Expenditures, DECON Unit 1............................ 3-20 3.1b Schedule of Total Annual Expenditures, DECON Unit 2............................ 3-21 3.2a Schedule of Total Annual Expenditures, Delayed DECON Unit 1.............. 3-22 3.2b Schedule of Total Annual Expenditures, Delayed DECON Unit 2.............. 3-23 3.3a Schedule of Total Annual Expenditures, SAFSTOR Unit 1......................... 3-24 3.3b Schedule of Total Annual Expenditures, SAFSTOR Unit 2......................... 3-27 5.1 Decommissioning Waste Summary, DECON................................................. 5-3 5.2 Decommissioning Waste Summary, Delayed DECON................................... 5-4 5.3 Decommissioning Waste Summary, SAFSTOR.............................................. 5-5 6.1 Summary of Decommissioning Cost Elements, DECON............................... 6-4 6.2 Summary of Decommissioning Cost Elements, Delayed DECON................. 6-5 6.3 Summary of Decommissioning Cost Elements, SAFSTOR............................ 6-6

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TABLE OF CONTENTS (continued)

SECTION PAGE FIGURES 4.1 DECON Activity Schedule................................................................................ 4-3 4.2 Decommissioning Timeline, DECON.............................................................. 4-6 4.3 Decommissioning Timeline, Delayed DECON................................................ 4-7 4.4 Decommissioning Timeline, SAFSTOR.......................................................... 4-8 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, Delayed DECON........................................................... D-1 E.

Detailed Cost Analysis, SAFSTOR...................................................................... E-1

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REVISION LOG No.

CRA No.

Date Item Revised Reason for Revision 0

06-08-2009 Original Issue

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EXECUTIVE

SUMMARY

This report presents estimates of the cost to decommission the LaSalle County Station (LaSalle County) for the identified decommissioning scenarios following a scheduled cessation of plant operations. The analysis relies upon site-specific, technical information, developed in an evaluation in 2004,[1] and updated to reflect current assumptions pertaining to the disposition of the nuclear units and relevant industry experience in undertaking such projects. The updated estimates are designed to provide Exelon Generation Company LLC (Exelon) with sufficient information to assess its financial obligations, as they pertains to the eventual decommissioning of the nuclear station.

The primary goal of the decommissioning is the removal and disposal of the contaminated systems and structures so that the plants operating licenses can be terminated. The analysis recognizes that spent fuel will be stored at the site in plants storage pools and/or in an independent spent fuel storage installation (ISFSI) until such time that it can be transferred to a Department of Energy (DOE) facility. Consequently, the estimates also include those costs to manage and subsequently decommission the fuel storage facilities.

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

The estimates incorporate a

minimum cooling period of approximately five and one-half years for the spent fuel in the storage pools at the cessation of operations. In the DECON and SAFSTOR scenarios, any residual fuel remaining in the pools after the cooling period is relocated to the ISFSI to await transfer to a DOE facility (the fuel is assumed to remain in the storage pools for the Delayed DECON scenario and transferred directly from the pools to DOE). The estimates also include the dismantling of non-essential structures and limited restoration of the site.

Alternatives and Regulations The Nuclear Regulatory Commission (NRC or Commission) provided initial decommissioning requirements in its rule adopted on June 27, 1988.[2] In this rule, 1

Decommissioning Cost Analysis for the LaSalle County Station, Document No. E16-1455-011, Rev.

0, TLG Services, Inc., January 2005 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, Federal Register Volume 53, Number 123 (p 24018 et seq.), June 27, 1988

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the NRC set forth financial criteria for decommissioning licensed nuclear power 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 property to be released for unrestricted use shortly after cessation of operations."[3]

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."[4]

Decommissioning is 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."[5] As with the SAFSTOR alternative, decommissioning is currently required to be completed within 60 years.

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 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 NRCs current priorities) at least until after the additional research studies are complete.

The Commission concurred with the staffs recommendation.

3 Ibid. Page FR24022, Column 3 4

Ibid.

5 Ibid. Page FR24023, Column 2

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In 1996, the NRC amended its decommissioning regulations to clarify ambiguities and codify procedures and terminology as a means of enhancing efficiency and uniformity in the decommissioning process.[6] 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 acceptable to the NRC staff for implementing the requirements of the 1996 amendments relating to the initial activities and major phases of the decommissioning process. The costs and schedules presented in this analysis follow the general guidance and processes described in the amended regulations. The format and content of the estimates is also consistent with the recommendations of Regulatory Guide 1.202, issued in February 2005.[7]

Decommissioning Scenarios The following scenarios were evaluated and are representative of the alternatives available to the owner. The scenarios assume that the units operate for 60 years, followed by a planned and scheduled shutdown.

1.

DECON: The first scenario assumes that the two units are promptly decommissioned as an integrated activity. Spent fuel that is not transferred directly to the DOE from the storage pools is relocated to the ISFSI so as to facilitate decontamination and dismantling activities within the reactor buildings. Spent fuel storage operations continue at the site, independent of decommissioning operations, until the transfer of the fuel to the DOE is complete, assumed for purposes of this study to be in the year 2055. At that time, the ISFSI is decommissioned and the site released for alternative use.

2.

Delayed DECON: In the second scenario, the units are prepared for an abbreviated period of safe-storage. The spent fuel resident in the reactor buildings storage pools, remains in the pools until it can be transferred to the DOE (i.e., the ISFSI is not used to off-load the pools following the cessation of operations). Spent fuel placed at the ISFSI during operations remains in storage until the pools are emptied at which time the ISFSI is also emptied.

Decommissioning is scheduled to commence once the transfer of the fuel to the DOE is complete (i.e., in the year 2055).

3.

SAFSTOR: The units are also placed into safe-storage in the third scenario.

However, decommissioning is deferred beyond the fuel storage period to the 6

U.S. Code of Federal Regulations, Title 10, Parts 2, 50, and 51, "Decommissioning of Nuclear Power Reactors," NRC, Federal Register Volume 61, (p 39278 et seq.), July 29, 1996 7

Standard Format and Content of Decommissioning Cost Estimates for Nuclear Power Reactors, Regulatory Guide 1.202, U.S. Nuclear Regulatory Commission, February 2005

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maximum extent permitted by the current regulations. Similar to the DECON alternative, the spent fuel that cannot be transferred directly to the DOE in the first five and one-half years is relocated to the ISFSI for interim storage.

The units remain in protective storage following the removal of spent fuel from the site. Decommissioning operations commence such that license termination is completed within the required 60-year period. As with the first two scenarios, decommissioning activities at the two units are sequenced and integrated so as to minimize the total duration of the physical dismantling process.

Methodology The methodology used to develop the estimates described within this document follows the basic approach originally presented in the cost estimating guidelines [8]

developed by the Atomic Industrial Forum (now Nuclear Energy Institute). This reference describes a unit factor method for determining decommissioning activity costs. The unit factors used in this analysis incorporate site-specific costs and the latest available information on worker productivity in decommissioning.

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 cost estimate.

Contingency Consistent with standard cost estimating practice, contingencies are applied to the decontamination and dismantling costs 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.[9] 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 8

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

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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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.

The use and role of contingency within decommissioning estimates is not a safety factor issue. Safety factors provide additional security and address situations that may never occur. Contingency funds, by contrast, are expected to be fully expended throughout the program. Inclusion of contingency is necessary to provide assurance that sufficient funding will be available to accomplish the intended tasks.

Low-Level Radioactive Waste Disposal The contaminated and activated material generated in the decontamination and dismantling of a commercial nuclear reactor is classified as low-level (radioactive) waste, although not all of the material is suitable for shallow-land disposal. With the passage of the Low-Level Radioactive Waste Policy Act in 1980,[10] and its Amendments of 1985,[11] the states became ultimately responsible for the disposition of low-level radioactive waste generated within their own borders.

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

EnergySolutions does not have a license to dispose of the more highly radioactive waste (Class B and C as defined by 10 CFR §61) generated in the decontamination and dismantling of the reactor vessel. In the interim (at least until new waste disposal options become available) and for purposes of this analysis, waste disposal costs for this material are based upon Exelons previously negotiated cost of disposal at the Barnwell site.

Material exceeding Class C limits (limited to material closest to the reactor core and comprising a small percentage of the total waste volume) is generally not suitable for shallow-land disposal. This material is packaged in the same multipurpose canisters used for spent fuel storage/transport and designated for geologic disposal.

10 Low-Level Radioactive Waste Policy Act of 1980, Public Law 96-573, 1980 11 Low-Level Radioactive Waste Policy Amendments Act of 1985, Public Law 99-240, 1986

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A significant portion of the metallic waste generated during decommissioning may only be potentially contaminated by radioactive materials. This waste can be surveyed 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 [12] (NWPA) in 1982, assigning the responsibility for disposal of the spent nuclear fuel created by the commercial nuclear generating plants to the DOE. Two permanent disposal facilities were envisioned, as well as an interim storage facility. To recover the cost, the legislation created a Nuclear Waste Fund through which money is collected from the sale of electricity generated by the power plants. The NWPA, along with the individual disposal contracts with the utilities, specified that the DOE was to begin accepting spent fuel by January 31, 1998.

Since the original legislation, the DOE has announced several delays in the program schedule. By January 1998, the DOE had failed to initiate the disposal of spent nuclear fuel and high level waste, as required by the NWPA and the utility contracts. As a result, utilities initiated legal action against the DOE. While legal actions continue, the DOE has no plans to receive spent fuel prior to completing the construction of its geologic repository.

Operation of DOEs yet-to-be constructed repository is contingent upon the review and approval of the facilitys license application by the NRC and the successful resolution of pending litigation. The DOE submitted its license application to the NRC on June 3, 2008, seeking authorization to construct the repository at Yucca Mountain, Nevada. The NRC formally docketed the DOEs license application on September 8, 2008, triggering a three-year deadline, with a possible one-year extension, set by Congress for the NRC to decide on whether to authorize construction.

12 Nuclear Waste Policy Act of 1982 and Amendments, U.S. Department of Energys Office of Civilian Radioactive Management, 1982

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Construction, if adequately funded, could take five to six years after the DOE receives authorization to proceed. For purposes of this analysis, Exelon has assumed that DOE would begin to receive commercial spent fuel in 2018.

Once the repository is operational, fuel acceptance will be prioritized and spent fuel assemblies will need to meet certain acceptance criteria, including heat output.

These conditions require that the fuel discharged upon the cessation of operations be actively cooled and stored for a minimum period at the generating site prior to transfer (a minimum of five years as defined in 10CFR§961 for standard fuel). As such, the NRC requires that licensees establish a program to manage and provide funding for the management of all irradiated fuel at the reactor until title of the fuel is transferred to the Secretary of Energy, pursuant to 10CFR§50.54(bb).[13] This funding requirement is fulfilled through inclusion of certain cost elements in the decommissioning estimates, for example, associated with the isolation and continued operation of the plants fuel storage pools and/or ISFSI.

At shutdown, the plants storage pools are expected to contain freshly discharged assemblies (from the most recent refueling cycles) as well as the final reactor core.

In the DECON and SAFSTOR scenarios the assemblies are packaged into multipurpose canisters for transfer to an existing ISFSI. A five and one-half year cooling period following the cessation of operations is provided for the final core to meet the conditions for dry storage.

Once the storage pools are emptied, the reactor buildings can be either decontaminated and dismantled or prepared for long-term storage. The ISFSI, which can be operated under the stations general license, will be expanded to accommodate the dry storage casks needed to off-load the wet storage pools. In the Delayed DECON scenario, the storage pools remain operational and used for the interim storage of the fuel. No additional dry storage capacity is assumed to be constructed for decommissioning. The transfer of spent fuel to DOE is performed first from the storage pools and is completed from the ISFSI.

The DOEs generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. With a large fleet of reactors, Exelon is able to re-assign allocations between its units to minimize on-site storage costs. Assuming spent fuel from the older units is given priority and with a maximum rate of transfer of 3,000 metric tons of uranium (MTU)/year), the assemblies residing in the LaSalle County storage pools at the time of shutdown would be scheduled for pickup in the years 2049 through 2055 (assuming the cessation of plant operations 13 U.S. Code of Federal Regulations, Title 10, Part 50, Domestic Licensing of Production and Utilization Facilities, Subpart 54 (bb), Conditions of Licenses

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in 2042 and 2043 for Units 1 and 2, respectively). This equates to 164 multi-purpose canisters (at 68 assemblies per canister).

Exelons strongly held position is that the DOE has a contractual obligation to accept LaSalle Countys fuel in a timely manner and consistent with its contract commitments. No assumption made in this study should be interpreted to be inconsistent with this claim. However, at this time, including the cost of storing spent fuel in this study is the most reasonable approach because it insures the availability of sufficient decommissioning funds at the end of the stations life if, contrary to its contractual obligation, the DOE has not performed.

Site Restoration The efficient removal of the contaminated materials at the site will result in damage to many of the site structures. Blasting, coring, drilling, and the other decontamination activities will substantially damage power block structures, potentially weakening the footings and structural supports. Prompt demolition once the license is terminated is clearly the most appropriate and cost-effective option. It is unreasonable to anticipate that these structures would be repaired and preserved after the radiological contamination is removed. The cost to dismantle site structures with a work force already mobilized is more efficient and less costly than if the process were deferred. Experience at shutdown generating stations has shown that plant facilities quickly degrade without maintenance, adding additional expense and creating potential hazards to the public and the demolition work force.

Consequently, this analysis assumes that non-essential site structures within the restricted access area are removed to a nominal depth of three feet below the local grade level wherever possible. The site is then graded and stabilized.

Summary The costs to decommission LaSalle County were evaluated for several decommissioning scenarios, incorporating the attributes of both the DECON and SAFSTOR decommissioning alternatives. Regardless of the timing of the decommissioning activities, the estimates assume the eventual removal of all the contaminated and activated plant components and structural materials, such that the facility operator may then have unrestricted use of the site with no further requirement for an operating license. Delayed decommissioning is initiated after the spent fuel has been removed from the site and 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 can be completed. Once the transfer is complete, the storage facilities are also decommissioned.

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The scenarios analyzed for the purpose of generating the estimates 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, D, and E. Cost summaries for the various scenarios are provided at the end of this section for the major cost components.

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SUMMARY

OF DECOMMISSIONING COST ELEMENTS DECON (thousands of 2009 dollars)

Cost Element Unit 1 Unit 2 Total Decontamination 19,620 23,201 42,821 Removal 119,520 144,680 264,200 Packaging 20,310 20,599 40,909 Transportation 12,225 13,067 25,293 Waste Disposal 79,110 81,244 160,354 Off-site Waste Processing 12,637 13,822 26,459 Program Management [1]

273,542 294,665 568,207 Spent Fuel Pool Isolation 11,143 7,429 18,572 Spent Fuel Management [2]

86,859 92,345 179,204 Insurance and Regulatory Fees 12,117 9,442 21,558 Energy 9,375 9,368 18,743 Characterization and Licensing Surveys 22,864 20,006 42,870 Property Taxes 13,808 12,893 26,701 Miscellaneous Equipment 6,449 6,443 12,892 Site O&M 1,501 1,261 2,762 Total [3]

701,080 750,464 1,451,544 Cost Element NRC License Termination 546,754 573,472 1,120,226 Spent Fuel Management 106,181 112,415 218,596 Site Restoration 48,145 64,578 112,723 Total [3]

701,080 750,464 1,451,544

[1]

Includes security and 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

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SUMMARY

OF DECOMMISSIONING COST ELEMENTS DELAYED DECON (thousands of 2009 dollars)

Cost Element Unit 1 Unit 2 Total Decontamination 21,930 26,550 48,480 Removal 113,775 138,744 252,519 Packaging 15,783 15,997 31,780 Transportation 8,035 8,586 16,621 Waste Disposal 43,290 44,773 88,063 Off-site Waste Processing 14,976 16,142 31,118 Program Management [1]

293,233 332,458 625,690 Spent Fuel Pool Isolation 11,143 7,429 18,572 Spent Fuel Management [2]

31,681 32,108 63,789 Insurance and Regulatory Fees 16,309 14,004 30,313 Energy 13,196 13,252 26,448 Characterization and Licensing Surveys 24,334 21,476 45,810 Property Taxes 21,418 20,917 42,334 Miscellaneous Equipment 9,564 10,897 20,461 Site O&M 3,125 2,886 6,011 Total [3]

641,791 706,219 1,348,009 Cost Element NRC License Termination 495,902 515,918 1,011,820 Spent Fuel Management 96,292 124,292 220,584 Site Restoration 49,597 66,009 115,606 Total [3]

641,791 706,219 1,348,009

[1]

Includes security and 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

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SUMMARY

OF DECOMMISSIONING COST ELEMENTS SAFSTOR (thousands of 2009 dollars)

Cost Element Unit 1 Unit 2 Total Decontamination 21,505 26,114 47,619 Removal 115,369 140,127 255,496 Packaging 14,538 14,748 29,285 Transportation 6,791 7,325 14,116 Waste Disposal 35,042 36,511 71,553 Off-site Waste Processing 15,058 16,224 31,282 Program Management [1]

379,941 353,240 733,181 Spent Fuel Pool Isolation 11,143 7,429 18,572 Spent Fuel Management [2]

85,776 91,261 177,037 Insurance and Regulatory Fees 41,049 38,140 79,189 Energy 18,589 18,491 37,080 Characterization and Licensing Surveys 24,334 21,476 45,810 Property Taxes 40,094 39,179 79,273 Miscellaneous Equipment 17,443 24,170 41,613 Site O&M 8,911 8,672 17,584 Total [3]

835,583 843,106 1,678,689 Cost Element NRC License Termination 665,300 652,162 1,317,462 Spent Fuel Management 120,674 124,923 245,597 Site Restoration 49,609 66,021 115,630 Total [3]

835,583 843,106 1,678,689

[1]

Includes security and 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

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1. INTRODUCTION This report presents estimates of the cost to decommission the LaSalle County Station (LaSalle County), for the scenarios described in Section 2, following a scheduled cessation of plant operations. The analysis relies upon site-specific, technical information from an earlier evaluation prepared in 2004,[1] updated to reflect current assumptions pertaining to the disposition of the nuclear units and relevant industry experience in undertaking such projects. The current estimates are designed to provide Exelon Generation Company LLC (Exelon), with sufficient information to assess their financial obligations, as they pertain to the eventual decommissioning of the nuclear units. It is not a detailed engineering document, but a financial analysis prepared in advance of the detailed engineering that will be required to carry out the decommissioning 1.1 OBJECTIVES OF STUDY The objectives of this study are to prepare comprehensive estimates of the cost to decommission LaSalle County, to provide a sequence or schedule for the associated activities, and to develop waste stream projections from the decontamination and dismantling activities. Operating licenses were issued on April 17, 1982 for Unit 1 and on December 16, 1983 for Unit 2. A sixty year operating lifetime has been assumed for the purpose of this study. As such, the cessation of operations would then be April 17, 2042 and December 16, 2043, for Units 1 and 2, respectively. These dates were used to schedule the decommissioning activities.

1.2 SITE DESCRIPTION LaSalle County is located approximately 55 miles southwest of Chicago, Illinois, and 20 miles west of the Dresden Nuclear Power Station. The station is comprised of two essentially identical boiling water reactors with supporting facilities.

The primary coolant system consists of a boiling water reactor system designed by General Electric. The reactor recirculation system is comprised of the reactor vessel and two recirculation pump loops external to the reactor vessel which provide the driving flow of water to the reactor vessel jet pumps. Each external loop contains one high-capacity, motor driven recirculation pump and three motor-operated gate valves for pump maintenance. The recirculation loops are part of the reactor coolant pressure boundary and are located inside the containment structure. The design reactor thermal power level is 3489

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Megawatts thermal (MWth).

The corresponding electrical output is approximately 1,154 Megawatts electric (MWe).

The containment system at LaSalle County is comprised of a primary containment and a secondary containment. Primary containment is a Mark II type containment, comprised of a steel dome head and post-tensioned concrete wall standing on a base mat of reinforced concrete. The inner surface of containment is lined with steel plate which acts as a leaktight membrane. The suppression system is of the over-and-under configuration. The drywell, in the form of a frustum of a cone, is located directly above the suppression chamber.

The suppression pool chamber is cylindrical and separated from the drywell by a reinforced concrete slab. The drywell is topped by an elliptical steel dome called the drywell head. The drywell atmosphere is vented into the suppression chamber through a series of downcomer pipes penetrating and supported by the drywell floor.

Heat produced in the reactor is converted to electrical energy by the power conversion system. A turbine-generator system converts the thermal energy of steam produced in the reactor into mechanical shaft power and then into electrical energy. The main turbine consists of one double-flow, high-pressure turbine and three double-flow, low-pressure turbines. The generator is driven at 1800 rpm and rated at 1300 MVA. The exhaust steam from the turbine is condensed and deaerated in the main condenser. The heat rejected to the main condenser is removed by the circulating water system.

The circulating water system provides the heat sink required for removal of waste heat in the power plants thermal cycle. The system has the principal function of removing heat by absorbing this energy in the main condenser. Water is withdrawn from the cooling lake via the intake pipes by the circulating water pumps. After passing through the plant condensers, the discharge is routed back to the cooling lake.

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

• Annotated references for citations in Sections 1-6 are provided in Section 7.

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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 plants systems, structures, and facilities are removed or decontaminated to levels that permit the site to be released for unrestricted use shortly after the cessation of plant operations.

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

The ENTOMB alternative has not been viewed as a viable option for power reactors due to the significant time required to isolate the long-lived radionuclides for decay to permissible levels. However, with recent rulemaking permitting the controlled release of a site, the NRC has re-evaluated this alternative.[4] The resulting feasibility study, based upon an assessment by Pacific Northwest National Laboratory, concluded that the method did have conditional merit for some, if not most, reactors. However, the staff also found that additional rulemaking would be needed before this option could be treated as a generic alternative. The NRC had considered rulemaking to alter the 60-year time for completing decommissioning and to clarify the use of engineered barriers for reactor entombments.[5] However, the NRCs staff has recommended that rulemaking be deferred, based upon several factors, e.g., no licensee has committed to pursuing the entombment option, the unresolved issues associated with the disposition of greater-than-Class C material (GTCC), and the NRCs current priorities, at least until after the additional

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research studies are complete. The Commission concurred with the staffs recommendation.

The NRC published amendments to its decommissioning regulations in 1996.[6]

When the regulations were originally adopted in 1988, it was assumed that the majority of licensees would decommission at the end of the facilitys 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 new amendments allow for greater public participation and better define the transition process from operations to decommissioning.

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

Submittal of these notices will entitle the licensee to a fee reduction and eliminate the obligation to follow certain requirements needed only during operation of the reactor. Within two years of submitting notice of permanent cessation of operations, the licensee is required to submit a Post-Shutdown Decommissioning Activities Report (PSDAR) to the NRC. The PSDAR describes the planned decommissioning activities, the associated sequence and

schedule, and an estimate of expected costs.

Prior to completing decommissioning, the licensee is required to submit applications to the NRC to terminate the license, which will include a License Termination Plan (LTP).

1.3.1 Nuclear Waste Policy Act Congress passed the Nuclear Waste Policy Act[7] (NWPA) in 1982, assigning the responsibility for disposal of the spent nuclear fuel created by the commercial nuclear generating plants to the DOE. Two permanent disposal facilities were envisioned, as well as an interim storage facility. To recover the cost, the legislation created a Nuclear Waste Fund through which money is collected from the sale of electricity generated by the power plants. NWPA, along with the individual disposal contracts with the utilities, specified that the DOE was to begin accepting spent fuel by January 31, 1998.

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Since the original legislation, the DOE has announced several delays in the program schedule. By January 1998, the DOE had failed to initiate the disposal of spent nuclear fuel and high level waste, as required by the NWPA and utility contracts. Delays continue and, as a result, generators have initiated legal action against the DOE in an attempt to resolve the impasse.[8]

Operation of DOEs yet-to-be constructed repository is contingent upon the review and approval of the facilitys license application by the NRC and the successful resolution of pending litigation. The DOE submitted its license application to the NRC on June 3, 2008, seeking authorization to construct the repository at Yucca Mountain, Nevada. The NRC formally docketed the DOEs license application on September 8, 2008, triggering a three-year deadline, with a possible one-year extension, set by Congress for the NRC to decide on whether to authorize construction.

Construction, if adequately funded, could take five to six years after the DOE receives authorization to proceed. For purposes of this analysis, Exelon has assumed that DOE would begin to receive commercial spent fuel in 2018.

Once the repository is operational, fuel acceptance will be prioritized and spent fuel assemblies will need to meet certain acceptance criteria, including heat output. These conditions require that the fuel discharged upon the cessation of operations be actively cooled and stored for a minimum period at the generating site prior to transfer (five years as defined in 10CFR§961 for standard fuel). As such, the NRC requires that licensees establish a program to manage and provide funding for the management of all irradiated fuel at the reactor until title of the fuel is transferred to the Secretary of Energy, pursuant to 10CFR§50.54(bb).[9]

This funding requirement is fulfilled through inclusion of certain cost elements in the decommissioning estimate, for example, associated with the isolation and continued operation of the spent fuel pools and ISFSI.

At shutdown, the fuel storage pools are expected to contain freshly discharged assemblies (from the most recent refueling cycles) as well as the final reactor core. Over the next five and one-half years the assemblies are packaged into multipurpose canisters for transfer to the repository or to the ISFSI. It is assumed that this period provides the necessary cooling for the final core to meet on site storage or DOEs transport system requirements for decay heat.

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An independent spent fuel storage installation (ISFSI) is being constructed to support plant operations. It is expected that this facility will also be available to support decommissioning operations. In two of the scenarios evaluated, the ISFSI is expanded to accommodate the inventory of spent fuel residing in the plants storage pools at the conclusion of the required cooling period. Once emptied, the reactor buildings can be either decontaminated and dismantled or prepared for long-term storage. In the Delayed DECON scenario, the storage pools remain operational and are used for the interim storage of the fuel, concurrent with the ISFSI operations.

The DOEs generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. For purposes of this analysis, the acceptance of commercial spent fuel by the DOE is expected to begin in 2018. Given this scenario and an anticipated rate of transfer, spent fuel is projected to remain at the LaSalle County site for approximately 12 years after the cessation of operations at Unit 2. Consequently, costs are included within the analysis for the continued operation of the storage pools and the expansion of the ISFSI, as required, and for the long-term caretaking of the spent fuel at the site until the year 2055.

Exelons strongly held position is that the DOE has a contractual obligation to accept LaSalle Countys fuel in a timely manner and consistent with its contract commitments. No assumption made in this study should be interpreted to be inconsistent with this claim. However, at this time, including the cost of storing spent fuel in this study is the most reasonable approach because it insures the availability of sufficient decommissioning funds at the end of the stations life if, contrary to its contractual obligation, the DOE has not performed.

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. Congress passed the Low-Level Radioactive Waste Policy Act in 1980,[10] declaring the states as being ultimately responsible for the disposition of low-level radioactive waste generated within their own borders. The federal law encouraged the formation of regional groups or compacts to implement this objective safely, efficiently, and economically, and set a target date of 1986 for implementation. After little progress, the Low-Level

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Radioactive Waste Policy Amendments Act of 1985,[11] extended the implementation schedule, with specific milestones and stiff sanctions for non-compliance. However, to date, no new compact facilities have been successfully sited, licensed, and constructed.

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

EnergySolutions does not have a license to dispose of the more highly radioactive waste (Class B and C as defined by 10 CFR §61) generated in the dismantling of the reactor vessel. In the interim (at least until new waste disposal options become available) and for purposes of this analysis, waste disposal costs for this material are based upon Exelons previously negotiated cost of disposal at the Barnwell site.

Material exceeding Class C limits (limited to material closest to the reactor core and comprising a small percentage of the total waste volume) is generally not suitable for shallow-land disposal. This material is packaged in the same multipurpose canisters used for spent fuel storage/transport and designated for geologic disposal.

A significant portion of the metallic waste generated during decommissioning may only be potentially contaminated by radioactive materials. This waste can be surveyed 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.

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1.3.3 Radiological Criteria for License Termination In 1997, the NRC published Subpart E, Radiological Criteria for License Termination,[12] amending 10 CFR §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 for LaSalle County assume that the site will be remediated to a residual level consistent with the NRC-prescribed level.

It should be noted that the NRC and the Environmental Protection Agency (EPA) differ on the amount of residual radioactivity considered acceptable in site remediation. The EPA has two limits that apply to radioactive materials. An EPA limit of 15 millirem per year is derived from criteria established by the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA or Superfund).[13]

An additional limit of 4 millirem per year, as defined in 40 CFR §141.16, is applied to drinking water.[14]

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)[15] 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

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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 LaSalle County for three variations of the approved decommissioning alternatives: DECON and SAFSTOR.

Although the scenarios differ with respect to technique, process, cost, and schedule, they attain the same result: the ultimate release of the site for unrestricted use.

The following scenarios were evaluated and are representative of the alternatives available to the owner. The scenarios assume that the units operate for 60 years, followed by a planned and scheduled shutdown.

1.

DECON: The first scenario assumes that the two units are promptly decommissioned as an integrated activity. Spent fuel that is not transferred directly to the DOE from the storage pools is relocated to the ISFSI so as to facilitate decontamination and dismantling activities within the reactor buildings. Spent fuel storage operations continue at the site, independent of decommissioning operations, until the transfer of the fuel to the DOE is complete, assumed for purposes of this study to be in the year 2055. At that time, the ISFSI is decommissioned and the site released for alternative use.

2.

Delayed DECON: In the second scenario, the units are prepared for an abbreviated period of safe-storage. The spent fuel resident in the reactor buildings storage pools, remains in the pools until it can be transferred to the DOE (i.e., the ISFSI is not used to off-load the pools following the cessation of operations). Spent fuel placed at the ISFSI during operations remains in storage until the pools are emptied at which time the ISFSI is also emptied.

Decommissioning is scheduled to commence once the transfer of the fuel to the DOE is complete (i.e., in the year 2055).

3.

SAFSTOR: The units are also placed into safe-storage in the third scenario.

However, decommissioning is deferred beyond the fuel storage period to the maximum extent permitted by the current regulations. Similar to the DECON alternative, the spent fuel that cannot be transferred directly to the DOE in the first five and one-half years is relocated to the ISFSI for interim storage.

The units remain in protective storage following the removal of spent fuel from the site. Decommissioning operations commence such that license termination is completed within the required 60-year period. As with the first two scenarios, decommissioning activities at the two units are sequenced and integrated so as to minimize the total duration of the physical dismantling process.

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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 facilitate de-activation and closure. During the first phase, notification is to be provided to the NRC certifying the permanent cessation of operations and the removal of fuel from the reactor vessel. The licensee would then be 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 LaSalle County 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

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



foreclose release of the site for possible unrestricted use,



significantly increase decommissioning costs,



cause any significant environmental impact, or



violate the terms of the licensees 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.

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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, and work packages and procedures, would be assembled to support the proposed decontamination and dismantling activities.

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



Characterization of the site and surrounding environs. This includes radiation surveys of work areas, major components (including the reactor vessel and its internals), internal piping, and primary 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. Decommissioning operations are scheduled around the fuel handling areas to optimize the overall project schedule. The fuel is transferred to the ISFSI as it decays to the point that it meets the heat load criteria of the containers. Consequently, it is assumed that the fuel pools remain operational for approximately five and one-half years following the cessation of operations.



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



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

2.1.2 Period 2 - Decommissioning Operations This period includes the physical decommissioning activities associated with the removal and disposal of contaminated and activated components and structures, including the successful termination of the

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10 CFR §50 operating license. Significant decommissioning activities in this phase include:



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



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



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



Procurement (lease or purchase) of shipping canisters, 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.



Transfer of the steam separator and dryer assemblies to the dryer-separator pool for segmentation. Segmentation by weight and activity maximizes the loading of the shielded transport casks. The operations are conducted under water using remotely operated tooling and contamination controls.



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



Disassembly, segmentation, and packaging of the core shroud and in-core guide tubes. Some of the material is expected to exceed Class C disposal requirements. As such, those segments are packaged in a modified fuel storage canister for geologic disposal.

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



Draining and decontamination of the reactor well and the permanent sealing of the spent fuel transfer gate. Install a shielded platform for segmentation of the reactor vessel. Cutting operations are performed in air using remotely operated equipment within a contamination control envelope, with the water level maintained just below the cut to minimize the working area dose rates. Sections are transferred to the dryer-separator pool for packaging and interim storage.



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



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



Demolition of the reactor shield activated concrete by controlled demolition.



Expansion of the ISFSI and transfer of the spent fuel from the storage pools to the ISFSI pad for interim storage. Spent fuel storage operations continue throughout the active decommissioning period.

Fuel transfer is expected to begin in 2049 and to be completed by the end of the year 2055.

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 meeting. 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

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health and safety (e.g., waste collection and treatment systems, electrical power and ventilation systems).



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



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



Surveys of the decontaminated areas of the containment structures.



Removal of the contaminated equipment and material from the turbine and radwaste buildings, and any other contaminated facility.

Use radiation and contamination control techniques until radiation surveys indicate that the structures can be released for unrestricted access and conventional demolition. This activity may necessitate the dismantling and disposition of most of the systems and components (both clean and contaminated) located within these buildings. This activity will facilitate surface decontamination and subsequent verification surveys required prior to obtaining release for demolition.



Removal of the remaining components, equipment, and plant services in support of the area release survey(s).



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 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).[16] 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

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complete, the results are provided to the NRC in a format that can be verified. The NRC then reviews and evaluates the information, performs an independent confirmation of radiological site conditions, and makes a determination on final termination of the license.

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

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

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

reactor, turbine and radwaste buildings.

Under certain circumstances, verifying that subsurface radionuclide concentrations meet NRC site release requirements will require removal of grade slabs and lower floors, potentially weakening footings and structural supports.

This removal activity will be necessary for those facilities and plant areas where historical records, when available, indicate the potential for radionuclides having been present in the soil, where system failures have been recorded, or where it is required to confirm that subsurface process and drain lines were not breached over the operating life of the station.

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

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

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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.

Concrete rubble produced by demolition activities is processed to remove rebar and miscellaneous embedments. The processed material is then used on site to backfill voids. Excess materials are trucked to an off-site area for disposal as construction debris.

2.1.4 ISFSI Operations and Decommissioning The ISFSI will continue to operate under the general license provisions of 10 CFR §72 following the termination of the §50 operating license.

Assuming the DOE starts accepting fuel in 2018, transfer of spent fuel from LaSalle County is anticipated to begin in 2049 and continue through the year 2055.

At the conclusion of the spent fuel transfer process, the ISFSI will be decommissioned. The Commission will terminate the §72 license when it determines that the remediation of the ISFSI has been performed in accordance with an ISFSI license termination plan and that the final radiation survey and associated documentation demonstrate that the facility is suitable for release. Once the requirements are satisfied, the NRC can terminate the license for the ISFSI.

The assumed design for the ISFSI is based upon the use of a multi-purpose canister and a concrete overpack for pad storage. For purposes of this cost analysis, it is assumed that once the inner canisters containing the spent fuel assemblies have been removed, any required decontamination performed, 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 will then be removed, and the area graded and landscaped to conform to the surrounding environment.

2.2 SAFSTOR and DELAYED DECON 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

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safely stored and subsequently decontaminated (deferred decontamination) to levels that permit release for unrestricted use." The facility is left intact (during the dormancy period), with structures maintained in a sound condition. Systems not required to operate in support of the spent fuel 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. Site preparations are also similar to those for the DECON alternative. However, with the exception of the required radiation surveys and site characterizations, the mobilization and preparation of site facilities is less extensive.

The following discussion is appropriate for both the SAFSTOR and Delayed DECON scenarios, the primary differences being in the length of the dormancy period. In the Delayed DECON scenario, the fuel remains in the reactor buildings storage pools until such time that the transfer to a DOE facility is complete. Decommissioning operations are assumed to begin once fuel is off site. By contrast, in the SAFSTOR scenario, the spent fuel is relocated to a newly constructed ISFSI. The plant remains in safe-storage after the fuel is removed from site. Decommissioning operations are initiated such that the license is terminated within the required 60-year time period.

2.2.1 Period 1 - Preparations Preparations for long-term storage include the planning for permanent defueling of the reactors, revision of technical specifications appropriate to the operating conditions and requirements, a characterization of the facility and major components, and the development of the PSDAR.

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



Isolation of the spent fuel storage services and fuel handling systems located in the reactor buildings 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.

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



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



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



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



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



Cleaning of the loose surface contamination from building access pathways.



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



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



Installing security and surveillance monitoring equipment and relocating security fence around secured structures, as required.

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

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

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An environmental surveillance program is carried out during the dormancy period to ensure that releases of radioactive material to the environment are prevented and/or detected and controlled. Appropriate emergency procedures are established and initiated for potential releases that exceed prescribed limits. The environmental surveillance program constitutes an abbreviated version of the program in effect during normal plant operations.

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

The transfer of the spent fuel to a DOE facility continues during this period until complete. Fuel is shipped exclusively from the ISFSI in the SAFSTOR scenario and from both the pools and the ISFSI in the Delayed DECON scenario.

After an optional period of storage (such that license terminations are accomplished within 60 years of final shutdown), it is required that the licensee submit applications to terminate the license, along with an LTP (described in Section 2.1.2), thereby initiating the third phase.

2.2.3 Periods 3 and 4 - Delayed Decommissioning Prior to the commencement of decommissioning operations, preparations are undertaken to reactivate site services and prepare for decommissioning. Preparations include engineering and planning, a detailed site characterization, and the assembly of a decommissioning management organization. Final planning for activities and the writing of activity specifications and detailed procedures are also initiated at this time.

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

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the availability of the fuel storage facilities located within the reactor buildings for decommissioning.

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

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

Although the initial radiation levels due to 60Co will decrease during the dormancy period, the internal components of the reactor vessel will still exhibit sufficiently high radiation dose rates to require remote sectioning under water due to the presence of long-lived radionuclides such as 94Nb, 59Ni, and 63Ni. Therefore, the dismantling procedures described for the DECON alternative would still be employed during deferred scenarios. Portions of the reactor 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.

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

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site facilities to a nominal depth of three feet below grade and limited restoration of the site.

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3. COST ESTIMATE The cost estimates prepared for decommissioning LaSalle County consider the unique features of the site, including the NSSS, power generation systems, support services, site buildings, and ancillary 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 ESTIMATE The estimates were developed with site-specific, technical information developed in an evaluation prepared for Exelon in 2004. The 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,"[17]

and the DOE "Decommissioning Handbook."[18]

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) were developed using local labor rates. The activity-dependent costs were 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 relied upon information available in the industry publication, "Building Construction Cost Data," published by R.S. Means.[19]

This analysis reflects lessons learned from TLGs 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

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Onofre-1 nuclear units have provided additional insight into the process, the regulatory aspects, and the technical challenges of decommissioning commercial nuclear units.

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.

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 were 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 40%



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 radiologically controlled areas.

The resulting man-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 are based upon productivity information available from the "Building Construction Cost Data" publication.

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

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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 cost estimate.

3.3 IMPACT OF DECOMMISSIONING MULTIPLE REACTOR UNITS In estimating the near simultaneous decommissioning of two co-located reactor units there can be opportunities to achieve economies of scale, by sharing costs between units, and coordinating the sequence of work activities. There will also be schedule constraints, particularly where there are requirements for specialty equipment and staff, or practical limitations on when final status surveys can take place. For purposes of the estimate, Units 1 and 2 are assumed to be essentially identical. Common facilities have been assigned to Unit 2. A summary of the principal impacts are listed below.



The sequence of work generally follows the principal that the work is done at Unit 1 first, followed by similar work at Unit 2. This permits the experience gained at Unit 1 to be applied by the workforce at the second unit. It should be noted however, that the estimate does not consider productivity improvements at the second unit, since there is little documented experience with decommissioning two units simultaneously The work associated with developing activity specifications and procedures can be considered essentially identical between the two units, therefore the second unit costs are assumed to be a fraction of the first unit (~ 42%).



Segmenting the reactor vessel and internals will require the use of special equipment. The decommissioning project will be scheduled such that Unit 2s reactor internals and vessel are segmented immediately after the activities at Unit 1 have been completed.



Some program management and support costs, particularly costs associated with the more senior positions, can be avoided with two reactors undergoing decommissioning simultaneously. As a result, the estimate is based on a lead unit that includes these senior positions, and a second unit that excludes these positions. The designation as lead is based on the unit undertaking the most complex tasks (for instance vessel segmentation) or performing tasks for the first time.



The final radiological survey schedule is also affected by a two-unit decommissioning schedule. It would be considered impractical to try to complete the final status survey of Unit 1, while Unit 2 still has ongoing radiological remediation work and waste handling in process. As such, the transfer of the spent fuel from the storage pools and subsequent

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decontamination of the reactor buildings is coordinated so as to synchronize the final status survey for the station.



The final demolition of buildings at Units 1 and 2 are considered to take place concurrently. This is considered a reasonable assumption since access to the buildings is considered good at the station.



Unit 1, as the first unit to enter decommissioning, incurs the majority of site characterization costs.



Shared systems and structures are generally assigned to Unit 2.



Station costs such as emergency response fees, regulatory agency fees, corporate overhead, and insurance are generally allocated on an equal basis between the two units.

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

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

3.4.1 Contingency The activity-and period-dependent costs are combined to develop the total decommissioning cost. A contingency is then applied on a line-item basis, using one or more of the contingency types listed in the AIF/NESP-036 study. "Contingencies" are defined in the American Association of Cost Engineers Project and Cost Engineers' Handbook[20]

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;

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therefore, consistent with industry practice, a contingency factor has been applied. In the AIF/NESP-036 study, the types of unforeseeable events that are likely to occur in decommissioning are discussed and guidelines are provided for percentage contingency in each category. It should be noted that contingency, as used in this analysis, does not account for price escalation and inflation in the cost of decommissioning over the remaining operating life of the station.

The use and role of contingency within decommissioning estimates is not a safety factor issue. Safety factors provide additional security and address situations that may never occur. Contingency funds are expected to be fully expended throughout the program. They also provide assurance that sufficient funding is available to accomplish the intended tasks. An estimate without contingency, or from which contingency has been removed, can disrupt the orderly progression of events and jeopardize a successful conclusion to the decommissioning process.

For

example, the most technologically challenging task in decommissioning a commercial nuclear station is the disposition of the reactor vessel and internal components, now highly radioactive after a lifetime of exposure to core activity. The disposition of these components forms the basis of the critical path (schedule) for decommissioning operations. Cost and schedule are interdependent, and any deviation in schedule has a significant impact on cost for performing a specific activity.

Disposition of the reactor vessel internals involves the underwater cutting of complex components that are highly radioactive. Costs are based upon optimum segmentation, handling, and packaging scenarios.

The schedule is primarily dependent upon the turnaround time for the heavily shielded shipping casks, including preparation, loading, and decontamination of the containers for transport. The number of casks required is a function of the pieces generated in the segmentation activity, a value calculated on optimum performance of the tooling employed in cutting the various subassemblies. The expected optimization, however, may not be achieved, resulting in delays and additional program costs. For this reason, contingency must be included to mitigate the consequences of the expected inefficiencies inherent in this complex activity, along with related concerns associated with the operation of highly specialized tooling, field conditions, and water clarity.

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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 TLGs 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%

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 estimate. For example, the composite contingency values reported for the DECON alternative are 19.7% and 19.6% for Units 1 and 2, respectively. Values for the other alternatives are delineated within the detailed cost tables in Appendices D and E.

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

Examples can include 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 (e.g., affecting worker health and safety, site release criteria, waste transportation, and disposal).



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



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

This cost study does not add any additional cost 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 estimate.

3.5 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 impacts of the considerations identified below are included in this cost study.

3.5.1 Spent Fuel Management The cost to dispose of spent fuel generated from plant operations is not reflected within the estimates to decommission the LaSalle County site.

Ultimate disposition of the spent fuel is within the province of the DOEs Waste Management System, as defined by the NWPA. As such, the disposal cost is financed by a 1 mill/kWhr surcharge paid into the DOEs 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 reactors until title of the fuel is transferred to the Secretary of Energy. This funding requirement is fulfilled through inclusion of certain high-level waste cost elements within the estimate, as described below.

The total inventory of assemblies that will require handling during decommissioning is based upon several assumptions. The pickup of commercial fuel is assumed to begin in the year 2018. The maximum rate at which the fuel is removed from the commercial sites is based upon an annual capacity at the geologic repository of 3,000 metric tons of uranium (MTU). Any delay in the startup of the repository or decrease in the rate of acceptance will correspondingly prolong the transfer process and result in the fuel remaining at the site longer.

In all three scenarios, the ISFSI will continue to operate until such time that the transfer of spent fuel to the DOE can be completed. Assuming that the DOE commences repository operation in 2018, fuel is projected to be removed from the LaSalle County site by the year 2055. In the Delayed DECON scenario, the ISFSI is only used to store fuel placed during plant operations. Spent fuel off-loaded from the pools after operations cease, remains in the pools during the transfer period. The inventory of fuel assemblies located in the spent fuel pools is preferentially off-loaded as the allocations permit.

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Operation and maintenance costs for the storage facilities (the ISFSI and the pools for the Delayed DECON scenario) are included within the estimates and address the cost for staffing the facilities, as well as security, insurance, and licensing fees. The estimates include the costs to purchase (DECON and SAFSTOR scenarios), load, and transfer the fuel storage canisters. Costs are also provided for the final disposition of the facilities once the transfer is complete.

Repository Startup Operation of the DOEs yet-to-be constructed geologic repository is contingent upon the review and approval of the facilitys license application by the NRC, the successful resolution of pending litigation, and the development of a national transportation system. The DOE submitted its license application to the NRC on June 3, 2008, seeking authorization to construct the repository at Yucca Mountain, Nevada.

The NRC formally docketed the DOEs license application on September 8, 2008, triggering a three-year deadline, with a possible one-year extension, set by Congress for the NRC to decide on whether to grant a construction authorization.

Construction, if adequately funded, could take five to six years after the DOE receives authorization to proceed. As such, the spent fuel management plan described in this section is predicated upon the DOE initiating the pickup of commercial fuel in the year 2018.

Spent Fuel Management Model The Exelon nuclear fleet consists of 21 units at 11 sites in Illinois, Pennsylvania, and New Jersey, including the inactive units at Dresden, Peach Bottom, and Zion. The ability to complete the decommissioning of these units, particularly for the DECON and Delayed DECON alternatives, is highly dependent upon when the DOE is assumed to remove spent fuel from the sites.

The DOE's repository program assumes that spent fuel will be accepted for disposal from the nation's commercial nuclear plants in the order (the "queue") in which it was removed from service ("oldest fuel first").[21]

A computer model developed by Exelon Nuclear was used to determine when the DOE would provide allocations in the queue for removal of spent fuel from the individual sites. Repository operations were based upon annual industry-wide receipt of 400 Metric Tons Heavy Metal

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(MTHM) in the first year of operation, a total of 3,800 MTHM in years 2 through 4 and 3,000 MTHM for year 5 and beyond.[22]

ISFSIs are constructed as necessary to maintain full-core discharge capability at the individual sites. Once the DOE begins repository operations, queue allocations are used to ship spent fuel from Exelon's operating sites.

Spent fuel shipments are then made from decommissioning sites in the order of retirement.

Canister Design The design and capacity of the ISFSI is based upon a vertical cask system, with a 68-fuel assemblies capacity, is assumed for future cask acquisitions. A unit cost of $500,000 is used for pricing the internal multi-purpose canister (MPC), with an additional cost of $250,000 for the concrete storage module. The DOE is assumed to provide the MPC for fuel transferred directly from the pools to the DOE at no cost to the owner.

Canister Loading and Transfer An average cost of $250,000 is used for the labor to load/transport the spent fuel from the pools to the ISFSI pad, based upon Exelon experience. For estimating purposes, 50% of this cost is used to estimate the cost to transfer the fuel from the ISFSI to the DOE.

Operations and Maintenance Annual costs (excluding labor) of approximately $763,000 and $88,000 are used for operation and maintenance of each spent fuel pool and the ISFSI, respectively.

ISFSI Design Considerations A multi-purpose (storage and transport) dry shielded storage canister with a vertcal, reinforced concrete storage module is used as a basis for the cost analysis. The final core off load from each unit, equivalent to 12 modules, are assumed to have some level of neutron-induced activation as a result of the long-term storage of the fuel (i.e., to levels exceeding free-release limits). The steel support structure is assumed to be removed from these modules for controlled disposal. The cost of the

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disposition of this material, as well as the demolition of the ISFSI facility, is included in the estimate.

3.5.2 Reactor Vessel and Internal Components The NSSS (reactor vessel and reactor recirculation system components) will be decontaminated using chemical agents prior to the start of cutting operations (for DECON alternative only). A decontamination factor (average reduction) of 10 is assumed for the process.

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

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

The dismantling of the reactor internals will generate radioactive waste considered unsuitable for shallow land disposal (i.e., GTCC). Although the material is not classified as high-level waste, the DOE has indicated it will accept this waste for disposal at the future high-level waste repository.[23] However, the DOE has not been forthcoming with an acceptance criteria or disposition schedule for this material, and numerous questions remain as to the ultimate disposal cost and waste form requirements. As such, for purposes of this study, the GTCC has been packaged and disposed of as high-level waste, at a cost equivalent to that envisioned for the spent fuel. It is not anticipated that the DOE would accept this waste prior to completing the transfer of spent fuel.

Therefore, until such time the DOE is ready to accept GTCC waste, it is reasonable to assume that this material would remain in storage at the LaSalle County site.

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. However, its location on the Columbia River simplified the transportation analysis since:

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 12 of 29 TLG Services, Inc.



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



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



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

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

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

It is not known whether this option will be available when LaSalle County ceases operation. Future viability of this option will depend upon the ultimate location of the disposal site, as well as the disposal site licensees ability to accept highly radioactive packages and effectively isolate them from the environment. Additionally, with BWRs, the diameter of the reactor vessel may severely limit overland transport.

Consequently, the study assumes the reactor vessel will require segmentation, as a bounding condition.

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

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

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 13 of 29 TLG Services, Inc.

packaged and readied for transport in accordance with the intended disposition.

3.5.5 Transportation Methods Contaminated piping, components, and structural material other than the highly activated reactor vessel and internal components will qualify as LSA-I, II or III or Surface Contaminated Object, SCO-I or II, as described in Title 49.[24] 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 §71, as Type B. It is conceivable that the reactor, due to its limited specific activity, could qualify as LSA II or III. However, the high radiation levels on the outer surface would require that additional shielding be incorporated within the packaging so as to attenuate the dose to levels acceptable for transport.

Transport of the highly activated metal, produced in the segmentation of the reactor vessels 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. Truck transport costs were estimated using published tariffs from Tri-State Motor Transit.[25]

3.5.6 Low-Level Radioactive Waste Disposal To the greatest extent practical, metallic material generated in the decontamination and dismantling processes is treated to reduce the total volume requiring controlled disposal. The treated material, meeting the regulatory and/or site release criterion, is released as scrap, requiring no further cost consideration. Conditioning and recovery of the waste stream is performed off site at a licensed processing center.

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 14 of 29 TLG Services, Inc.

The mass of radioactive waste generated during the various decommissioning activities is reported by line-item in Appendices C, D and E, and summarized in Section 5. The Section 5 waste summaries are consistent with 10 CFR §61 classifications. Commercially available steel containers are 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 waste volumes are calculated on the exterior package dimensions for containerized material or a dimensional calculation for components serving as their own waste containers.

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

Disposal fees are calculated using current disposal agreements, with surcharges added for the highly activated components, for example, generated in the segmentation of the reactor vessel. The cost to dispose of the majority of the material generated from the decontamination and dismantling activities is based upon Exelons current disposal agreement with EnergySolutions for its facility in Clive, Utah.

Since the EnergySolutions facility is not able to accept the higher activity waste (Class B and C) generated in the decontamination of the reactor vessel and segmentation of the components closest to the core, the cost of disposal of this material at a yet-to-be determined facility were based upon Exelons last negotiated rates for the Barnwell facility.

Material exceeding Class C limits (limited to material closest to the reactor core and comprising a small percentage of the total waste volume) is generally not suitable for shallow-land disposal. This material is packaged in the same multipurpose canisters used for spent fuel storage/transport and designated for geologic disposal.

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 15 of 29 TLG Services, Inc.

3.5.7 Site Conditions Following Decommissioning The NRC will terminate (or amend) the site license when 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 NRCs 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 the owners own future plans for the site.

Non-essential structures or buildings severely damaged in decontamination process are removed to a nominal depth of three feet below grade. Concrete rubble generated from demolition activities is processed and made available as clean fill. The excavations will be regraded such that the power block area will have a final contour consistent with adjacent surroundings.

The estimates do assume the remediation of a small volume of contaminated soil. This estimate may be adjusted by continued plant operations and/or future regulatory actions, such as the development of site-specific release criteria.

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

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

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 16 of 29 TLG Services, Inc.

3.6.2 Labor Costs The craft labor required to decontaminate and dismantle the nuclear units will be acquired through standard site contracting practices. The current cost of labor at the site is used as an estimating basis. Costs for site administration, operations, construction, and maintenance personnel are based upon average salary information provided by Exelon or from comparable industry information.

Exelon will hire a Decommissioning Operations Contractor (DOC) to manage the decommissioning. The owner will provide site security, radiological health and safety, quality assurance and overall site administration during the decommissioning and demolition phases.

Contract personnel will provide engineering services (e.g., for preparing the activity specifications, work procedures, activation, and structural analyses) under the direction of Exelon.

3.6.3 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.[26] Actual estimates are derived from the curie/gram values contained therein and adjusted for the different mass of the LaSalle County components, projected operating life, and different periods of decay. Additional short-lived isotopes were derived from CR-0130[27]

and CR-0672,[28]

and benchmarked to the long-lived values from CR-3474.

The disposal cost for the control blades removed from the vessel with the final core load is included within the estimates. Control blade residence time in the reactor is assumed to be controlled such that the blades do not become GTCC material. Disposition of any blades stored in the pools from operations is considered an operating expense and therefore not accounted for in the estimates.

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 17 of 29 TLG Services, Inc.

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

3.6.4 General Transition Activities Existing warehouses will be cleared of non-essential material and remain for use by Exelon and its subcontractors. The plants operating staff will perform 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.



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

Scrap and Salvage The existing plant equipment is considered obsolete and suitable for scrap as deadweight quantities only. Exelon 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

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 18 of 29 TLG Services, Inc.

the possible salvage 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 will be removed at no cost or credit to the decommissioning project. Disposition may include relocation to other facilities. Spare parts will also be 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 for the cost of energy consumption during decommissioning for tooling, lighting, ventilation, and essential services.

Insurance Costs for continuing coverage (nuclear liability and property insurance) following cessation of plant operations and during decommissioning are included and based upon current operating premiums. Reductions in premiums, throughout the decommissioning process, are based upon the guidance and the limits for coverage defined in the NRCs proposed rulemaking Financial Protection Requirements for Permanently Shutdown Nuclear Power Reactors.[29] NRCs financial protection requirements are based on various reactor (and spent fuel) configurations.

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 19 of 29 TLG Services, Inc.

Taxes Property taxes are included for all decommissioning periods. Exelon provided a schedule of decreasing tax payments against the current tax assessment. These reductions continue until reaching a minimum property tax payment of $1 million per year for the site; this level is maintained for the balance of the decommissioning program.

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.

3.7 COST ESTIMATE

SUMMARY

A schedule of expenditures for each scenario is provided in Tables 3.1 through 3.3. Decommissioning costs are reported in the year of projected expenditure; however, the values are provided in thousands of 2009 dollars. Costs are not inflated, escalated, or discounted over the period of expenditure. The annual expenditures are based upon the detailed activity costs reported in Appendices C through E, along with the schedules discussed in Section 4.

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 20 of 29 TLG Services, Inc.

TABLE 3.1a LaSALLE COUNTY STATION, UNIT 1 DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2042 38,815 6,592 1,119 30 10,726 57,282 2043 65,734 16,765 2,351 10,787 25,167 120,804 2044 65,688 21,934 1,502 30,071 9,081 128,276 2045 59,048 19,474 1,394 22,097 7,642 109,654 2046 45,857 14,572 1,182 5,985 4,753 72,350 2047 43,307 12,984 1,069 6,712 4,778 68,850 2048 11,710 2,254 202 3,058 2,575 19,799 2049 2,456 186 10 8

1,511 4,170 2050 30,322 4,693 273 23 2,106 37,416 2051 17,867 8,578 158 0

1,491 28,094 2052 13,733 6,605 115 0

1,456 21,910 2053 2,448 1,217 0

0 1,346 5,011 2054 2,448 1,217 0

0 1,346 5,011 2055 2,415 1,667 0

0 14,131 18,213 2056 1,806 901 0

191 1,345 4,242 Total 403,654 119,638 9,375 78,961 89,452 701,080

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 21 of 29 TLG Services, Inc.

TABLE 3.1b LaSALLE COUNTY STATION, UNIT 2 DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2043 1,886 633 69 2

651 3,241 2044 43,600 14,924 1,654 458 15,418 76,054 2045 62,177 25,314 2,251 20,939 16,795 127,475 2046 70,151 26,334 1,498 30,872 9,109 137,964 2047 65,900 15,579 1,289 14,847 6,160 103,774 2048 63,914 10,140 1,186 6,720 4,673 86,633 2049 55,469 8,476 875 8,229 4,633 77,682 2050 33,380 5,568 273 23 1,916 41,160 2051 23,090 11,439 158 0

1,492 36,179 2052 17,555 8,698 115 0

1,456 27,824 2053 2,448 1,217 0

0 1,346 5,011 2054 2,448 1,217 0

0 1,346 5,011 2055 2,415 1,667 0

0 14,131 18,213 2056 1,806 901 0

191 1,345 4,242 Total 446,238 132,107 9,368 82,280 80,471 750,464

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 22 of 29 TLG Services, Inc.

TABLE 3.2a LaSALLE COUNTY STATION, UNIT 1 DELAYED DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2042 29,478 749 1,119 30 2,239 33,615 2043 33,007 5,498 1,311 856 17,366 58,038 2044 5,272 1,705 316 27 3,424 10,743 2045 5,258 1,700 315 27 3,414 10,714 2046 5,258 1,700 315 27 3,414 10,714 2047 5,258 1,700 315 27 3,414 10,714 2048 5,272 1,705 316 27 3,424 10,743 2049 5,258 1,700 315 27 3,414 10,714 2050 5,258 1,700 315 27 3,414 10,714 2051 3,414 1,350 249 26 2,631 7,669 2052 861 867 158 26 1,549 3,460 2053 858 864 158 26 1,545 3,451 2054 10,854 1,326 504 28 1,544 14,255 2055 45,655 3,685 1,577 37 3,222 54,176 2056 56,278 12,883 1,522 15,588 12,421 98,693 2057 52,659 13,447 1,437 17,910 11,855 97,308 2058 39,995 6,809 1,182 5,294 3,851 57,131 2059 39,995 6,809 1,182 5,294 3,851 57,131 2060 2,251 274 32 152 978 3,687 2061 24,374 1,189 231 25 1,511 27,329 2062 16,949 7,359 163 1

743 25,215 2063 16,407 7,555 158 0

709 24,829 2064 494 228 5

0 21 748 Total 410,361 82,801 13,196 45,480 89,953 641,791

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 23 of 29 TLG Services, Inc.

TABLE 3.2b LaSALLE COUNTY STATION, UNIT 2 DELAYED DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2043 1,980 46 69 2

127 2,225 2044 46,871 1,802 1,581 130 3,192 53,577 2045 25,356 5,389 885 786 13,329 45,746 2046 7,315 1,757 315 27 3,368 12,783 2047 7,315 1,757 315 27 3,368 12,783 2048 7,336 1,762 316 27 3,377 12,818 2049 7,315 1,757 315 27 3,368 12,783 2050 7,315 1,757 315 27 3,368 12,783 2051 7,315 1,757 315 27 3,368 12,783 2052 7,336 1,762 316 27 3,377 12,818 2053 7,309 1,756 315 27 3,363 12,770 2054 4,790 1,580 158 26 1,537 8,091 2055 4,849 1,580 162 26 1,537 8,153 2056 26,314 1,455 1,581 34 1,405 30,789 2057 46,082 10,423 1,537 10,769 8,956 77,766 2058 57,849 15,587 1,498 21,442 13,605 109,981 2059 56,684 7,742 1,199 6,908 4,316 76,849 2060 56,775 7,331 1,186 6,127 3,816 75,235 2061 40,922 3,242 548 1,663 2,104 48,479 2062 22,076 10,131 163 1

735 33,105 2063 21,631 10,416 158 0

710 32,914 2064 652 314 5

0 21 992 Total 471,388 91,103 13,252 48,130 82,346 706,218

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 24 of 29 TLG Services, Inc.

TABLE 3.3a LaSALLE COUNTY STATION, UNIT 1 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2042 31,323 6,257 1,119 30 10,726 49,455 2043 35,573 14,123 1,311 856 20,855 72,717 2044 5,646 7,388 316 27 3,499 16,876 2045 5,630 7,368 315 27 3,490 16,829 2046 5,630 7,368 315 27 3,490 16,829 2047 5,239 6,084 282 27 3,078 14,710 2048 3,763 1,206 158 26 1,516 6,669 2049 3,753 1,203 158 26 1,511 6,651 2050 3,753 1,203 158 26 1,511 6,651 2051 3,753 1,203 158 26 1,511 6,651 2052 3,763 1,206 158 26 1,516 6,669 2053 3,753 1,203 158 26 1,511 6,651 2054 3,753 1,203 158 26 1,511 6,651 2055 3,750 1,200 158 26 1,511 6,645 2056 2,449 258 158 26 1,324 4,215 2057 2,442 257 158 26 1,320 4,204 2058 2,442 257 158 26 1,320 4,204 2059 2,442 257 158 26 1,320 4,204 2060 2,449 258 158 26 1,324 4,215 2061 2,442 257 158 26 1,320 4,204 2062 2,442 257 158 26 1,320 4,204 2063 2,442 257 158 26 1,320 4,204 2064 2,449 258 158 26 1,324 4,215 2065 2,442 257 158 26 1,320 4,204 2066 2,442 257 158 26 1,320 4,204 2067 2,442 257 158 26 1,320 4,204 2068 2,449 258 158 26 1,324 4,215 2069 2,442 257 158 26 1,320 4,204 2070 2,442 257 158 26 1,320 4,204 2071 2,442 257 158 26 1,320 4,204

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 25 of 29 TLG Services, Inc.

TABLE 3.3a (continued)

LaSALLE COUNTY STATION, UNIT 1 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2072 2,449 258 158 26 1,324 4,215 2073 2,442 257 158 26 1,320 4,204 2074 2,442 257 158 26 1,320 4,204 2075 2,442 257 158 26 1,320 4,204 2076 2,449 258 158 26 1,324 4,215 2077 2,442 257 158 26 1,320 4,204 2078 2,442 257 158 26 1,320 4,204 2079 2,442 257 158 26 1,320 4,204 2080 2,449 258 158 26 1,324 4,215 2081 2,442 257 158 26 1,320 4,204 2082 2,442 257 158 26 1,320 4,204 2083 2,442 257 158 26 1,320 4,204 2084 2,449 258 158 26 1,324 4,215 2085 2,442 257 158 26 1,320 4,204 2086 2,442 257 158 26 1,320 4,204 2087 2,442 257 158 26 1,320 4,204 2088 2,449 258 158 26 1,324 4,215 2089 2,442 257 158 26 1,320 4,204 2090 2,442 257 158 26 1,320 4,204 2091 2,442 257 158 26 1,320 4,204 2092 2,449 258 158 26 1,324 4,215 2093 2,442 257 158 26 1,320 4,204 2094 2,442 257 158 26 1,320 4,204 2095 18,227 750 737 30 1,348 21,092 2096 47,637 3,030 1,581 38 4,242 56,528 2097 58,704 16,637 1,505 17,321 15,039 109,206 2098 46,475 10,490 1,290 9,824 7,833 75,912 2099 40,003 6,699 1,182 5,025 3,733 56,642 2100 22,985 3,802 664 2,825 2,488 32,765

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 26 of 29 TLG Services, Inc.

TABLE 3.3a (continued)

LaSALLE COUNTY STATION, UNIT 1 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2101 16,217 802 149 18 1,294 18,480 2102 21,209 5,823 203 9

1,008 28,252 2103 16,422 7,555 158 0

709 24,844 2104 4,724 2,173 45 0

204 7,147 Total 507,005 126,018 18,589 37,315 146,656 835,583

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 27 of 29 TLG Services, Inc.

TABLE 3.3b LaSALLE COUNTY STATION, UNIT 2 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2043 2,103 387 69 2

651 3,212 2044 49,708 9,708 1,581 130 14,628 75,755 2045 28,887 13,758 885 786 13,392 57,708 2046 10,740 8,468 315 27 3,481 23,031 2047 10,740 8,468 315 27 3,481 23,031 2048 10,769 8,491 316 27 3,491 23,094 2049 5,530 4,671 230 26 2,409 12,866 2050 1,135 1,469 158 26 1,504 4,292 2051 1,135 1,469 158 26 1,504 4,292 2052 1,138 1,473 158 26 1,508 4,304 2053 1,135 1,469 158 26 1,504 4,292 2054 1,135 1,469 158 26 1,504 4,292 2055 1,137 1,466 158 26 1,503 4,289 2056 1,629 284 158 26 1,328 3,424 2057 1,624 283 158 26 1,325 3,415 2058 1,624 283 158 26 1,325 3,415 2059 1,624 283 158 26 1,325 3,415 2060 1,629 284 158 26 1,328 3,424 2061 1,624 283 158 26 1,325 3,415 2062 1,624 283 158 26 1,325 3,415 2063 1,624 283 158 26 1,325 3,415 2064 1,629 284 158 26 1,328 3,424 2065 1,624 283 158 26 1,325 3,415 2066 1,624 283 158 26 1,325 3,415 2067 1,624 283 158 26 1,325 3,415 2068 1,629 284 158 26 1,328 3,424 2069 1,624 283 158 26 1,325 3,415 2070 1,624 283 158 26 1,325 3,415 2071 1,624 283 158 26 1,325 3,415

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 28 of 29 TLG Services, Inc.

TABLE 3.3b (continued)

LaSALLE COUNTY STATION, UNIT 2 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2072 1,629 284 158 26 1,328 3,424 2073 1,624 283 158 26 1,325 3,415 2074 1,624 283 158 26 1,325 3,415 2075 1,624 283 158 26 1,325 3,415 2076 1,629 284 158 26 1,328 3,424 2077 1,624 283 158 26 1,325 3,415 2078 1,624 283 158 26 1,325 3,415 2079 1,624 283 158 26 1,325 3,415 2080 1,629 284 158 26 1,328 3,424 2081 1,624 283 158 26 1,325 3,415 2082 1,624 283 158 26 1,325 3,415 2083 1,624 283 158 26 1,325 3,415 2084 1,629 284 158 26 1,328 3,424 2085 1,624 283 158 26 1,325 3,415 2086 1,624 283 158 26 1,325 3,415 2087 1,624 283 158 26 1,325 3,415 2088 1,629 284 158 26 1,328 3,424 2089 1,624 283 158 26 1,325 3,415 2090 1,624 283 158 26 1,325 3,415 2091 1,624 283 158 26 1,325 3,415 2092 1,629 284 158 26 1,328 3,424 2093 1,624 283 158 26 1,325 3,415 2094 1,624 283 158 26 1,325 3,415 2095 1,624 283 158 26 1,325 3,415 2096 12,829 811 803 29 1,340 15,813 2097 29,843 3,144 1,577 35 2,669 37,268 2098 59,491 17,740 1,502 18,661 14,956 112,350 2099 57,981 10,643 1,279 10,084 7,322 87,310 2100 56,697 7,197 1,182 5,835 3,682 74,593 2101 46,498 4,614 771 3,084 2,638 57,605

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 3, Page 29 of 29 TLG Services, Inc.

TABLE 3.3b (continued)

LaSALLE COUNTY STATION, UNIT 2 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2102 25,576 7,899 203 9

933 34,620 2103 21,646 10,416 158 0

710 32,929 2104 6,227 2,996 45 0

204 9,473 Total 507,089 139,544 18,491 39,949 138,033 843,106

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 4, Page 1 of 8 TLG Services, Inc.

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

A schedule or sequence of activities is presented in Figure 4.1 for the DECON decommissioning alternative. The schedule is also representative of the work activities identified in the delayed dismantling scenarios, absent any spent fuel constraints. The scheduling sequence assumes that fuel is removed from the spent fuel pools within the first 51/2 years after operations cease at Unit 2. 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 2003" computer software.[30]

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 tables, 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 DECON decommissioning schedule:



The reactor buildings are isolated until such time that all spent fuel has been discharged from the storage pools to the DOE or to the ISFSI.

Decontamination and dismantling of the storage pools are initiated once the transfer of spent fuel to the ISFSI is complete.



All work (except vessel and internals removal) is performed during an 8-hour workday, 5 days per week, with no overtime. There are eleven paid holidays per year.



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

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and laydown space, and with the stringent safety measures necessary during demolition of heavy components and structures.



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 schedule for decommissioning LaSalle County. 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 also shown for the spent fuel cooling period, which determines the release of the reactor building for final decontamination.

Project timelines are provided in Figures 4.2 through 4.4; the milestone dates are based on this same shutdown date. The start of decommissioning activities in the Delayed Decommissioning scenario is concurrent with the end of the fuel transfer activity (i.e. to an off-site DOE facility).

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FIGURE 4.1 DECON ACTIVITY SCHEDULE

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FIGURE 4.1 DECON ACTIVITY SCHEDULE (continued)

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FIGURE 4.1 DECON ACTIVITY SCHEDULE (continued)

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FIGURE 4.2 DECOMMISSIONING TIMELINE DECON (not to scale)

Unit 1 (Shutdown April 17, 2042)

Unit 2 (Shutdown December 16, 2043)

ISFSI Operations Pool and ISFSI Operations Storage Pool Empty 10/2047 Period 1 Transition and Preparations 04/2042 10/2043 09/2052 06/2056 Period 2 Decommissioning Period 3 Site Restoration ISFSI Operations 12/2055 ISFSI D&D 09/2050 Period 1 Transition and Preparations 12/2043 06/2045 09/2052 06/2056 Period 2 Decommissioning Period 3 Site Restoration ISFSI Operations 12/2055 ISFSI D&D 09/2050 Storage Pool Empty 06/2049

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FIGURE 4.3 DECOMMISSIONING TIMELINE DELAYED DECON (not to scale)

Unit 1 (Shutdown April 17, 2042)

Unit 2 (Shutdown December 16, 2043)

Spent Fuel Storage ISFSI/ Storage Pools Empty 12/2055 Period 1 Transition and Preparations 04/2042 10/2043 01/2062 01/2064 04/2056 Period 2 Dormancy 10/2054 Period 3 Delayed Preparations Period 4 Decommissioning Period 5 Site Restoration Period 1 Transition and Preparations 12/2043 06/2045 01/2062 01/2064 07/2057 Period 2 Dormancy 12/2055 Period 3 Delayed Preparations Period 4 Decommissioning Period 5 Site Restoration

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FIGURE 4.4 DECOMMISSIONING TIMELINE SAFSTOR (not to scale)

Unit 1 (Shutdown April 17, 2042)

Unit 2 (Shutdown December 16, 2043)

ISFSI Empty 12/2055 Spent Fuel Storage Storage Pool Empty 10/2047 Period 1 Transition and Preparations 04/2042 10/2043 04/2102 04/2104 02/2097 Period 2 Dormancy 08/2095 Period 3 Delayed Preparations Period 4 Decommissioning Period 5 Site Restoration Period 1 Transition and Preparations 12/2043 06/2045 04/2102 04/2104 01/2098 Period 2 Dormancy 07/2096 Period 3 Delayed Preparations Period 4 Decommissioning Period 5 Site Restoration Storage Pool Empty 06/2049

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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(s). This currently requires the remediation of all radioactive material at the site in excess of applicable legal limits. Under the Atomic Energy Act,[31] 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, §71 defines radioactive material as it pertains to packaging and transportation and §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 §173-178. Shipping containers are required to be Industrial Packages (IP-1, IP-2 or IP-3, as defined in subpart 173.411). For this study, commercially available steel containers are presumed to be used for the disposal of piping, small components, and concrete. Larger components can serve as their own containers, with proper closure of all openings, access ways, and penetrations.

The volumes of radioactive waste generated during the various decommissioning activities at the site is shown on a line-item basis in Appendices C, D, and E and summarized in Tables 5.1 through 5.3. The quantified waste volume summaries shown in these tables are consistent with §61 classifications. The volumes are calculated based on the exterior dimensions for containerized material and on the displaced volume of components serving as their own waste containers.

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

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

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

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

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While the dose rates decrease with time, radionuclides such as 137Cs will still control the disposition requirements.

The waste material generated in the decontamination and dismantling of LaSalle County is primarily generated during Period 2 of the DECON alternative and Period 4 of the deferred alternatives. Material that is considered potentially contaminated when removed from the radiologically controlled area is sent to processing facilities in Tennessee for conditioning and disposal. Heavily contaminated components and activated materials are routed for controlled disposal. The disposal volumes reported in the tables reflect the savings resulting from reprocessing and recycling.

Disposal fees are calculated using current disposal agreements, with surcharges added for the highly activated components, for example, generated in the segmentation of the reactor vessel. The cost to dispose of the majority of the material generated from the decontamination and dismantling activities is based upon Exelons current disposal agreement with EnergySolutions for its facility in Clive, Utah.

Since the EnergySolutions facility is not able to accept the higher activity waste (Class B and C) generated in the decontamination of the reactor vessel and segmentation of the components closest to the core, the cost of disposal of this material at a yet-to-be determined facility are based upon Exelons previously negotiated cost of disposal at the Barnwell site.

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TABLE 5.1 DECOMMISSIONING WASTE

SUMMARY

DECON Waste Cost Basis Class [1]

Waste Volume (cubic feet)

Mass (pounds)

EnergySolutions A

347,330 28,054,418 Barnwell B

10,423 1,329,245 Low-Level Radioactive Waste (near-surface disposal)

Barnwell C

2,870 224,010 Greater than Class C (geologic repository)

Spent Fuel Equivalent GTCC 1,342 219,820 Processed/Conditioned (off-site recycling center)

Recycling Vendors A

1,158,691 48,952,700 Total [2]

1,520,656 78,780,193 Scrap Metal 239,662,000

[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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TABLE 5.2 DECOMMISSIONING WASTE

SUMMARY

DELAYED DECON Waste Cost Basis Class [1]

Waste Volume (cubic feet)

Mass (pounds)

EnergySolutions A

218,238 15,972,520 Barnwell B

9,014 1,143,931 Low-Level Radioactive Waste (near-surface disposal)

Barnwell C

1,263 149,270 Greater than Class C (geologic repository)

Spent Fuel Equivalent GTCC 1,342 219,820 Processed/Conditioned (off-site recycling center)

Recycling Vendors A

1,368,652 57,572,900 Total [2]

1,598,509 75,058,441 Scrap Metal 239,102,000

[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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TABLE 5.3 DECOMMISSIONING WASTE

SUMMARY

SAFSTOR Waste Cost Basis Class [1]

Waste Volume (cubic feet)

Mass (pounds)

EnergySolutions A

247,950 16,796,526 Barnwell B

3,506 406,400 Low-Level Radioactive Waste (near-surface disposal)

Barnwell C

1,304 146,510 Greater than Class C (geologic repository)

Spent Fuel Equivalent GTCC 1,342 219,820 Processed/Conditioned (off-site recycling center)

Recycling Vendors A

1,372,013 57,876,560 Total [2]

1,626,115 75,445,816 Scrap Metal 239,102,000

[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 LaSalle County relied upon the site-specific, technical information developed for a previous analysis prepared in 2004. While not an engineering study, the estimates provide Exelon with sufficient information to assess its 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 plants spent fuel pools for a minimum of five and one-half years following the cessation of operations for continued cooling of the assemblies. For the DECON and SAFSTOR scenarios, the ISFSI is expanded to accommodate the spent fuel, once sufficiently cooled, until such time that the DOE can complete the transfer of the assemblies to its repository. The spent fuel remains in the storage pools in the Delayed-DECON alternative.

The cost projected to promptly decommission (DECON) LaSalle County is estimated to be $1,451.5 million. The majority of this cost (approximately 77.2%) is associated with the physical decontamination and dismantling of the nuclear unit so that the license can be terminated. Another 15.1% is associated with the management, interim storage, and eventual transfer of the spent fuel. The remaining 7.8% is for the demolition of the designated structures and limited restoration of the site.

The primary cost contributors, identified in Tables 6.1 through 6.3, 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 Exelon will oversee the decommissioning program, using a DOC to manage the decommissioning labor force and the associated subcontractors. The size and composition of the management organization varies with the decommissioning phase and associated site activities.

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

As described in this report, the spent fuel pools will remain operational for a minimum of five and one-half years following the cessation of operations. The pools

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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 five and one-half year period, the spent fuel will be packaged into transportable steel canisters for loading into a DOE-provided transport cask (DECON and SAFSTOR alternatives). The canisters will be stored in concrete overpacks at the ISFSI until the DOE is able to receive them. Dry storage of the fuel under a separate license provides additional flexibility in the event the DOE is not able to meet the current timetable for completing the transfer of assemblies to an off-site facility and minimizes the associated caretaking expenses.

The cost for waste disposal includes only those costs associated with the controlled disposition of the low-level radioactive waste generated from decontamination and dismantling activities, including plant equipment and components, structural material, filters, resins and dry-active waste. As described in Section 5, disposal of the majority of the radioactive material is at EnergySolutions facility in Clive, Utah or some alternative facility. Highly activated components, requiring additional isolation from the environment, are packaged for geologic disposal. Disposal of these components 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 table 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.

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

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

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

SUMMARY

OF DECOMMISSIONING COST ELEMENTS DECON (thousands of 2009 dollars)

Cost Element Total Percentage Decontamination 42,821 3.0 Removal 264,200 18.2 Packaging 40,909 2.8 Transportation 25,293 1.7 Waste Disposal 160,354 11.0 Off-site Waste Processing 26,459 1.8 Program Management [1]

568,207 39.1 Spent Fuel Pool Isolation 18,572 1.3 Spent Fuel Management [2]

179,204 12.3 Insurance and Regulatory Fees 21,558 1.5 Energy 18,743 1.3 Characterization and Licensing Surveys 42,870 3.0 Property Taxes 26,701 1.8 Miscellaneous Equipment 12,892 0.9 Site O&M 2,762 0.2 Total [3]

1,451,544 100.0 Cost Element Total Percentage NRC License Termination 1,120,226 77.2 Spent Fuel Management 218,596 15.1 Site Restoration 112,723 7.8 Total [3]

1,451,544 100.0

[1]

Includes security and 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

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TABLE 6.2

SUMMARY

OF DECOMMISSIONING COST ELEMENTS DELAYED DECON (thousands of 2009 dollars)

Cost Element Total Percentage Decontamination 48,480 3.6 Removal 252,519 18.7 Packaging 31,780 2.4 Transportation 16,621 1.2 Waste Disposal 88,063 6.5 Off-site Waste Processing 31,118 2.3 Program Management [1]

625,690 46.4 Spent Fuel Pool Isolation 18,572 1.4 Spent Fuel Management [2]

63,789 4.7 Insurance and Regulatory Fees 30,313 2.2 Energy 26,448 2.0 Characterization and Licensing Surveys 45,810 3.4 Property Taxes 42,334 3.1 Miscellaneous Equipment 20,461 1.5 Site O&M 6,011 0.4 Total [3]

1,348,009 100.0 Cost Element Total Percentage NRC License Termination 1,011,820 75.1 Spent Fuel Management 220,584 16.4 Site Restoration 115,606 8.6 Total [3]

1,348,009 100.0

[1]

Includes security and 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

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TABLE 6.3

SUMMARY

OF DECOMMISSIONING COST ELEMENTS SAFSTOR (thousands of 2009 dollars)

Cost Element Total Percentage Decontamination 47,619 2.8 Removal 255,496 15.2 Packaging 29,285 1.7 Transportation 14,116 0.8 Waste Disposal 71,553 4.3 Off-site Waste Processing 31,282 1.9 Program Management [1]

733,181 43.7 Spent Fuel Pool Isolation 18,572 1.1 Spent Fuel Management [2]

177,037 10.5 Insurance and Regulatory Fees 79,189 4.7 Energy 37,080 2.2 Characterization and Licensing Surveys 45,810 2.7 Property Taxes 79,273 4.7 Miscellaneous Equipment 41,613 2.5 Site O&M 17,584 1.0 Total [3]

1,678,689 100.0 Cost Element Total Percentage NRC License Termination 1,317,462 78.5 Spent Fuel Management 245,597 14.6 Site Restoration 115,630 6.9 Total [3]

1,678,689 100.0

[1]

Includes security and 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

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7. REFERENCES 1

Decommissioning Cost Analysis for the LaSalle County Station, Document No. E16-1455-011, Rev. 0, TLG Services, Inc., January 2005

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, Federal Register Volume 53, Number 123 (p 24018 et seq.), June 27, 1988

3.

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

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, Federal Register Volume 66, Number 200, 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, Federal Register Volume 61 (p 39278 et seq.), July 29, 1996

7.

Nuclear Waste Policy Act of 1982 and Amendments, U.S. Department of Energys Office of Civilian Radioactive Management, 1982

8.

Settlement: Exelon and the U.S. Department of Justice, in close consultation with the DOE, under which the government will reimburse Exelon for costs associated with storage of spent fuel at the company's nuclear stations pending DOE fulfilling its contractual obligation to accept commercial spent nuclear fuel. Additional amounts reimbursed annually for future costs. August 5, 2004

9.

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

10.

Low-Level Radioactive Waste Policy, Public Law 96-573, 1980

11.

Low-Level Radioactive Waste Policy Amendments Act of 1985, Public Law 99-240, January 15, 1986

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 7, Page 2 of 3 TLG Services, Inc.

7. REFERENCES (continued)

12.

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

13.

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

14.

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

15.

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

16.

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

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

17.

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

18.

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

Department of Energy, DOE/EV/10128-1, November 1980 19 "Building Construction Cost Data 2009," Robert Snow Means Company, Inc.,

Kingston, Massachusetts

20.

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

21.

DOE/RW-0351, Civilian Radioactive Waste Management System Waste Acceptance System Requirements Document, Revision 5, May 31, 2007

22.

Civilian Radioactive Waste Management System Requirements Document, DOE/RW-0406, Revision 8, September 2007

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Section 7, Page 3 of 3 TLG Services, Inc.

7. REFERENCES (continued)

23.

"Strategy for Management and Disposal of Greater-Than-Class C Low-Level Radioactive Waste, Federal Register Volume 60, Number 48 (p 13424 et seq.),

March 1995

24.

U.S. Department of Transportation, Title 49 of the Code of Federal Regulations, "Transportation," Parts 173 through 178, 2009

25.

Tri-Tri-State Motor Transit Company, published tariffs, Interstate Commerce Commission (ICC), Docket No. MC-427719 Rules Tariff, March 2004, Radioactive Materials Tariff, January 2008

26.

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

27.

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

28.

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

29.

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

30.

"Microsoft Project 2003," Microsoft Corporation, Redmond, WA, 2003

31.

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

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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% 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 44.56 1499.49 Craftsmen 2.00 11.217 59.67 1338.64 Foreman 1.00 11.217 61.21 686.59 General Foreman 0.25 11.217 63.08 176.89 Fire Watch 0.05 11.217 44.56 24.99 Health Physics Technician 1.00 11.217 51.42 576.78 Total labor cost

$4,303.38

4.

EQUIPMENT & CONSUMABLES COSTS Equipment Costs none Consumables/Materials Costs



Blotting paper 50 @ $0.50/sq ft {1}

$25.00



Plastic sheets/bags 50 @ $0.37/sq ft {2}

$18.50



Gas torch consumables 1 @ $8.70 x 1 /hr {3}

$8.70 Subtotal cost of equipment and materials

$52.20 Overhead & profit on equipment and materials @ 16.25 %

$8.48 Total costs, equipment & material

$60.68 TOTAL COST:

Removal of contaminated heat exchanger <3000 pounds:

$4,364.06 Total labor cost:

$4,303.38 Total equipment/material costs:

$60.68 Total craft labor man-hours required per unit:

81.88

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 4 of 4 TLG Services, Inc.

5.

NOTES AND REFERENCES



Work difficulty factors were developed in conjunction with the Atomic Industrial Forums (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 - Spill Control (7193T88)

2. R.S. Means (2009) 01 56 13.60-0200, page 20

3. R.S. Means (2009) 01 54 33.40-6360, page 626



Material and consumable costs were adjusted using the regional indices for LaSalle County, Illinois.

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 1 of 7 TLG Services, Inc.

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

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 2 of 7 APPENDIX B UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit TLG Services, Inc.

Removal of clean instrument and sampling tubing, $/linear foot 0.49 Removal of clean pipe 0.25 to 2 inches diameter, $/linear foot 5.20 Removal of clean pipe >2 to 4 inches diameter, $/linear foot 7.41 Removal of clean pipe >4 to 8 inches diameter, $/linear foot 14.60 Removal of clean pipe >8 to 14 inches diameter, $/linear foot 28.17 Removal of clean pipe >14 to 20 inches diameter, $/linear foot 36.53 Removal of clean pipe >20 to 36 inches diameter, $/linear foot 53.78 Removal of clean pipe >36 inches diameter, $/linear foot 63.93 Removal of clean valve >2 to 4 inches 95.95 Removal of clean valve >4 to 8 inches 146.03 Removal of clean valve >8 to 14 inches 281.72 Removal of clean valve >14 to 20 inches 365.32 Removal of clean valve >20 to 36 inches 537.75 Removal of clean valve >36 inches 639.32 Removal of clean pipe hanger for small bore piping 31.11 Removal of clean pipe hanger for large bore piping 113.77 Removal of clean pump, <300 pound 244.33 Removal of clean pump, 300-1000 pound 683.75 Removal of clean pump, 1000-10,000 pound 2,708.74 Removal of clean pump, >10,000 pound 5,231.61 Removal of clean pump motor, 300-1000 pound 288.19 Removal of clean pump motor, 1000-10,000 pound 1,129.00 Removal of clean pump motor, >10,000 pound 2,540.24 Removal of clean heat exchanger <3000 pound 1,449.65 Removal of clean heat exchanger >3000 pound 3,639.49 Removal of clean feedwater heater/deaerator 10,294.03 Removal of clean moisture separator/reheater 21,208.19 Removal of clean tank, <300 gallons 314.53 Removal of clean tank, 300-3000 gallon 995.55 Removal of clean tank, >3000 gallons, $/square foot surface area 8.36

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 3 of 7 APPENDIX B UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit TLG Services, Inc.

Removal of clean electrical equipment, <300 pound 134.27 Removal of clean electrical equipment, 300-1000 pound 469.21 Removal of clean electrical equipment, 1000-10,000 pound 938.41 Removal of clean electrical equipment, >10,000 pound 2,226.44 Removal of clean electrical transformer < 30 tons 1,546.22 Removal of clean electrical transformer > 30 tons 4,452.86 Removal of clean standby diesel generator, <100 kW 1,579.34 Removal of clean standby diesel generator, 100 kW to 1 MW 3,525.18 Removal of clean standby diesel generator, >1 MW 7,297.85 Removal of clean electrical cable tray, $/linear foot 12.49 Removal of clean electrical conduit, $/linear foot 5.45 Removal of clean mechanical equipment, <300 pound 134.27 Removal of clean mechanical equipment, 300-1000 pound 469.21 Removal of clean mechanical equipment, 1000-10,000 pound 938.41 Removal of clean mechanical equipment, >10,000 pound 2,226.44 Removal of clean HVAC equipment, <300 pound 162.37 Removal of clean HVAC equipment, 300-1000 pound 563.78 Removal of clean HVAC equipment, 1000-10,000 pound 1,123.63 Removal of clean HVAC equipment, >10,000 pound 2,226.44 Removal of clean HVAC ductwork, $/pound 0.52 Removal of contaminated instrument and sampling tubing, $/linear foot 1.54 Removal of contaminated pipe 0.25 to 2 inches diameter, $/linear foot 21.45 Removal of contaminated pipe >2 to 4 inches diameter, $/linear foot 36.73 Removal of contaminated pipe >4 to 8 inches diameter, $/linear foot 58.79 Removal of contaminated pipe >8 to 14 inches diameter, $/linear foot 114.88 Removal of contaminated pipe >14 to 20 inches diameter, $/linear foot 137.89 Removal of contaminated pipe >20 to 36 inches diameter, $/linear foot 190.79 Removal of contaminated pipe >36 inches diameter, $/linear foot 225.51 Removal of contaminated valve >2 to 4 inches 443.32 Removal of contaminated valve >4 to 8 inches 536.01

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 4 of 7 APPENDIX B UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit TLG Services, Inc.

Removal of contaminated valve >8 to 14 inches 1,098.29 Removal of contaminated valve >14 to 20 inches 1,394.88 Removal of contaminated valve >20 to 36 inches 1,857.37 Removal of contaminated valve >36 inches 2,204.52 Removal of contaminated pipe hanger for small bore piping 143.99 Removal of contaminated pipe hanger for large bore piping 477.43 Removal of contaminated pump, <300 pound 954.17 Removal of contaminated pump, 300-1000 pound 2,217.18 Removal of contaminated pump, 1000-10,000 pound 7,218.18 Removal of contaminated pump, >10,000 pound 17,577.56 Removal of contaminated pump motor, 300-1000 pound 946.42 Removal of contaminated pump motor, 1000-10,000 pound 2,942.19 Removal of contaminated pump motor, >10,000 pound 6,605.61 Removal of contaminated heat exchanger <3000 pound 4,364.06 Removal of contaminated heat exchanger >3000 pound 12,646.33 Removal of contaminated feedwater heater/deaerator 31,008.18 Removal of contaminated moisture separator/reheater 67,818.66 Removal of contaminated tank, <300 gallons 1,587.89 Removal of contaminated tank, >300 gallons, $/square foot 31.05 Removal of contaminated electrical equipment, <300 pound 742.85 Removal of contaminated electrical equipment, 300-1000 pound 1,813.23 Removal of contaminated electrical equipment, 1000-10,000 pound 3,492.50 Removal of contaminated electrical equipment, >10,000 pound 6,840.09 Removal of contaminated electrical cable tray, $/linear foot 35.77 Removal of contaminated electrical conduit, $/linear foot 17.48 Removal of contaminated mechanical equipment, <300 pound 826.38 Removal of contaminated mechanical equipment, 300-1000 pound 2,002.41 Removal of contaminated mechanical equipment, 1000-10,000 pound 3,850.56 Removal of contaminated mechanical equipment, >10,000 pound 6,840.09 Removal of contaminated HVAC equipment, <300 pound 826.38

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 5 of 7 APPENDIX B UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit TLG Services, Inc.

Removal of contaminated HVAC equipment, 300-1000 pound 2,002.41 Removal of contaminated HVAC equipment, 1000-10,000 pound 3,850.56 Removal of contaminated HVAC equipment, >10,000 pound 6,840.09 Removal of contaminated HVAC ductwork, $/pound 2.12 Removal/plasma arc cut of contaminated thin metal components, $/linear in.

3.96 Additional decontamination of surface by washing, $/square foot 8.14 Additional decontamination of surfaces by hydrolasing, $/square foot 35.77 Decontamination rig hook up and flush, $/ 250 foot length 6,965.99 Chemical flush of components/systems, $/gallon 14.49 Removal of clean standard reinforced concrete, $/cubic yard 133.21 Removal of grade slab concrete, $/cubic yard 180.48 Removal of clean concrete floors, $/cubic yard 345.16 Removal of sections of clean concrete floors, $/cubic yard 1,044.18 Removal of clean heavily rein concrete w/#9 rebar, $/cubic yard 225.02 Removal of contaminated heavily rein concrete w/#9 rebar, $/cubic yard 2,077.78 Removal of clean heavily rein concrete w/#18 rebar, $/cubic yard 284.45 Removal of contaminated heavily rein concrete w/#18 rebar, $/cubic yard 2,748.01 Removal heavily rein concrete w/#18 rebar & steel embedments, $/cubic yard 441.29 Removal of below-grade suspended floors, $/cubic yard 345.16 Removal of clean monolithic concrete structures, $/cubic yard 876.57 Removal of contaminated monolithic concrete structures, $/cubic yard 2,068.51 Removal of clean foundation concrete, $/cubic yard 686.99 Removal of contaminated foundation concrete, $/cubic yard 1,926.71 Explosive demolition of bulk concrete, $/cubic yard 29.89 Removal of clean hollow masonry block wall, $/cubic yard 93.99 Removal of contaminated hollow masonry block wall, $/cubic yard 318.45 Removal of clean solid masonry block wall, $/cubic yard 93.99 Removal of contaminated solid masonry block wall, $/cubic yard 318.45 Backfill of below-grade voids, $/cubic yard 21.09 Removal of subterranean tunnels/voids, $/linear foot 109.98

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 6 of 7 APPENDIX B UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit TLG Services, Inc.

Placement of concrete for below-grade voids, $/cubic yard 123.48 Excavation of clean material, $/cubic yard 2.79 Excavation of contaminated material, $/cubic yard 39.47 Removal of clean concrete rubble (tipping fee included), $/cubic yard 21.48 Removal of contaminated concrete rubble, $/cubic yard 24.64 Removal of building by volume, $/cubic foot 0.29 Removal of clean building metal siding, $/square foot 1.14 Removal of contaminated building metal siding, $/square foot 4.02 Removal of standard asphalt roofing, $/square foot 2.29 Removal of transite panels, $/square foot 2.11 Scarifying contaminated concrete surfaces (drill & spall), $/square foot 12.39 Scabbling contaminated concrete floors, $/square foot 7.61 Scabbling contaminated concrete walls, $/square foot 20.22 Scabbling contaminated ceilings, $/square foot 69.50 Scabbling structural steel, $/square foot 6.29 Removal of clean overhead crane/monorail < 10 ton capacity 657.77 Removal of contaminated overhead crane/monorail < 10 ton capacity 1,852.82 Removal of clean overhead crane/monorail >10-50 ton capacity 1,578.64 Removal of contaminated overhead crane/monorail >10-50 ton capacity 4,445.99 Removal of polar crane > 50 ton capacity 6,576.02 Removal of gantry crane > 50 ton capacity 27,830.40 Removal of structural steel, $/pound 0.21 Removal of clean steel floor grating, $/square foot 4.63 Removal of contaminated steel floor grating, $/square foot 13.43 Removal of clean free standing steel liner, $/square foot 12.53 Removal of contaminated free standing steel liner, $/square foot 36.36 Removal of clean concrete-anchored steel liner, $/square foot 6.27 Removal of contaminated concrete-anchored steel liner, $/square foot 42.35 Placement of scaffolding in clean areas, $/square foot 16.04 Placement of scaffolding in contaminated areas, $/square foot 26.33

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 7 of 7 APPENDIX B UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost/Unit TLG Services, Inc.

Landscaping with topsoil, $/acre 18,124.88 Cost of CPC B-88 LSA box & preparation for use 1,938.92 Cost of CPC B-25 LSA box & preparation for use 1,602.73 Cost of CPC B-12V 12 gauge LSA box & preparation for use 1,446.32 Cost of CPC B-144 LSA box & preparation for use 8,443.56 Cost of LSA drum & preparation for use 169.75 Cost of cask liner for CNSI 14 195 cask 239.43 Cost of cask liner for CNSI 8 120A cask (resins) 7,072.43 Cost of cask liner for CNSI 8 120A cask (filters) 7,525.89 Decontamination of surfaces with vacuuming, $/square foot 0.75

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 1 of 23 TLG Services, Inc.

APPENDIX C DETAILED COST ANALYSIS DECON Page LaSalle County Station, Unit 1.....................................................................................C-2 LaSalle County Station, Unit 2..................................................................................C-13

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 2 of 23 Table C-1 LaSalle County Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:21 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs 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 Activities 1a.1.1 Prepare preliminary decommissioning cost 153 23 176 176 1,300 1a.1.2 Notification of Cessation of Operations a

1a.1.3 Remove fuel & source material n/a 1a.1.4 Notification of Permanent Defueling a

1a.1.5 Deactivate plant systems & process waste a

1a.1.6 Prepare and submit PSDAR 236 35 271 271 2,000 1a.1.7 Review plant dwgs & specs.

543 81 624 624 4,600 1a.1.8 Perform detailed rad survey a

1a.1.9 Estimate by-product inventory 118 18 136 136 1,000 1a.1.10 End product description 118 18 136 136 1,000 1a.1.11 Detailed by-product inventory 153 23 176 176 1,300 1a.1.12 Define major work sequence 885 133 1,018 1,018 7,500 1a.1.13 Perform SER and EA 366 55 421 421 3,100 1a.1.14 Perform Site-Specific Cost Study 590 89 679 679 5,000 1a.1.15 Prepare/submit License Termination Plan 483 73 556 556 4,096 1a.1.16 Receive NRC approval of termination plan a

Activity Specifications 1a.1.17.1 Plant & temporary facilities 581 87 668 601 67 4,920 1a.1.17.2 Plant systems 492 74 565 509 57 4,167 1a.1.17.3 NSSS Decontamination Flush 59 9

68 68 500 1a.1.17.4 Reactor internals 838 126 964 964 7,100 1a.1.17.5 Reactor vessel 767 115 882 882 6,500 1a.1.17.6 Sacrificial shield 59 9

68 68 500 1a.1.17.7 Moisture separators/reheaters 118 18 136 136 1,000 1a.1.17.8 Reinforced concrete 189 28 217 109 109 1,600 1a.1.17.9 Main Turbine 246 37 283 283 2,088 1a.1.17.10 Main Condensers 246 37 283 283 2,088 1a.1.17.11 Pressure suppression structure 236 35 271 271 2,000 1a.1.17.12 Drywell 189 28 217 217 1,600 1a.1.17.13 Plant structures & buildings 368 55 423 212 212 3,120 1a.1.17.14 Waste management 543 81 624 624 4,600 1a.1.17.15 Facility & site closeout 106 16 122 61 61 900 1a.1.17 Total 5,037 756 5,793 5,288 505 42,683 Planning & Site Preparations 1a.1.18 Prepare dismantling sequence 283 42 326 326 2,400 1a.1.19 Plant prep. & temp. svces 2,800 420 3,220 3,220 1a.1.20 Design water clean-up system 165 25 190 190 1,400 1a.1.21 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,200 330 2,530 2,530 1a.1.22 Procure casks/liners & containers 145 22 167 167 1,230 1a.1 Subtotal Period 1a Activity Costs 14,277 2,141 16,418 15,913 505 78,609 Period 1a Additional Costs 1a.2.1 ISFSI Expansion 10,400 1,560 11,960 11,960 1a.2 Subtotal Period 1a Additional Costs 10,400 1,560 11,960 11,960 Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 9,000 1,350 10,350 10,350 1a.3 Subtotal Period 1a Collateral Costs 9,000 1,350 10,350 10,350 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 3 of 23 Table C-1 LaSalle County Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:21 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 1a Period-Dependent Costs 1a.4.1 Insurance 876 88 964 964 1a.4.2 Property taxes 1a.4.3 Health physics supplies 396 99 495 495 1a.4.4 Heavy equipment rental 396 59 455 455 1a.4.5 Disposal of DAW generated 2

1 34 9

45 45 610 12,190 3

1a.4.6 Plant energy budget 1,371 206 1,577 1,577 1a.4.7 NRC Fees 706 71 776 776 1a.4.8 Emergency Planning Fees 313 31 344 344 1a.4.9 Site O&M Costs 125 19 144 144 1a.4.10 Spent Fuel Pool O&M 762 114 877 877 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 457 69 526 526 12,264 1a.4.13 Utility Staff Cost 31,082 4,662 35,745 35,745 423,400 1a.4 Subtotal Period 1a Period-Dependent Costs 792 2

1 34 35,736 5,433 41,997 40,726 1,271 610 12,190 3

435,664 1a.0 TOTAL PERIOD 1a COST 792 2

1 34 69,413 10,484 80,725 56,640 23,581 505 610 12,190 3

514,273 PERIOD 1b - Decommissioning Preparations Period 1b Direct Decommissioning Activities Detailed Work Procedures 1b.1.1.1 Plant systems 559 84 642 578 64 4,733 1b.1.1.2 NSSS Decontamination Flush 118 18 136 136 1,000 1b.1.1.3 Reactor internals 472 71 543 543 4,000 1b.1.1.4 Remaining buildings 159 24 183 46 137 1,350 1b.1.1.5 CRD housings & NIs 118 18 136 136 1,000 1b.1.1.6 Incore instrumentation 118 18 136 136 1,000 1b.1.1.7 Removal primary containment 236 35 271 271 2,000 1b.1.1.8 Reactor vessel 428 64 493 493 3,630 1b.1.1.9 Facility closeout 142 21 163 81 81 1,200 1b.1.1.10 Sacrificial shield 142 21 163 163 1,200 1b.1.1.11 Reinforced concrete 118 18 136 68 68 1,000 1b.1.1.12 Main Turbine 245 37 282 282 2,080 1b.1.1.13 Main Condensers 246 37 283 283 2,088 1b.1.1.14 Moisture separators & reheaters 236 35 271 271 2,000 1b.1.1.15 Radwaste building 322 48 370 333 37 2,730 1b.1.1.16 Reactor building 322 48 370 333 37 2,730 1b.1.1 Total 3,982 597 4,579 4,154 425 33,741 1b.1.2 Decon NSSS 631 315 946 946 1,067 1b.1 Subtotal Period 1b Activity Costs 631 3,982 913 5,525 5,100 425 1,067 33,741 Period 1b Additional Costs 1b.2.1 Site Characterization 6,086 1,826 7,912 7,912 29,730 10,672 1b.2.2 Spent Fuel Pool Isolation 9,690 1,453 11,143 11,143 1b.2 Subtotal Period 1b Additional Costs 15,775 3,279 19,055 19,055 29,730 10,672 Period 1b Collateral Costs 1b.3.1 Decon equipment 763 114 877 877 1b.3.2 DOC staff relocation expenses 1,130 169 1,299 1,299 1b.3.3 Process liquid waste 39 71 355 3,604 981 5,050 5,050 252 960 121,632 236 1b.3.4 Small tool allowance 2

0 2

2 1b.3.5 Pipe cutting equipment 1,100 165 1,265 1,265 1b.3.6 Decon rig 1,400 210 1,610 1,610 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 4 of 23 Table C-1 LaSalle County Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:21 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 1b Collateral Costs (continued) 1b.3.7 Spent Fuel Capital and Transfer 5,000 750 5,750 5,750 1b.3 Subtotal Period 1b Collateral Costs 2,202 1,102 71 355 3,604 6,130 2,390 15,854 10,104 5,750 252 960 121,632 236 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 23 6

29 29 1b.4.2 Insurance 211 21 232 232 1b.4.3 Property taxes 2,321 232 2,554 2,554 1b.4.4 Health physics supplies 223 56 279 279 1b.4.5 Heavy equipment rental 198 30 228 228 1b.4.6 Disposal of DAW generated 1

0 20 5

26 26 358 7,159 2

1b.4.7 Plant energy budget 1,375 206 1,581 1,581 1b.4.8 NRC Fees 354 35 389 389 1b.4.9 Emergency Planning Fees 157 16 172 172 1b.4.10 Site O&M Costs 63 9

72 72 1b.4.11 Spent Fuel Pool O&M 382 57 440 440 1b.4.12 ISFSI Operating Costs 22 3

25 25 1b.4.13 Security Staff Cost 229 34 264 264 6,149 1b.4.14 DOC Staff Cost 5,217 783 5,999 5,999 63,789 1b.4.15 Utility Staff Cost 15,652 2,348 17,999 17,999 213,326 1b.4 Subtotal Period 1b Period-Dependent Costs 23 421 1

0 20 25,983 3,842 30,290 29,653 637 358 7,159 2

283,263 1b.0 TOTAL PERIOD 1b COST 2,856 1,523 72 355 3,624 51,870 10,424 70,724 63,911 6,387 425 610 960 128,791 31,035 327,676 PERIOD 1 TOTALS 2,856 2,315 74 356 3,658 121,283 20,908 151,449 120,551 29,969 930 1,220 960 140,981 31,037 841,949 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.1 Recirculation System Piping & Valves 103 85 18 22 198 127 553 553 1,006 121,649 3,377 2a.1.1.2 Recirculation Pumps & Motors 55 48 14 30 9

313 125 594 594 238 2,356 211,420 1,957 2a.1.1.3 CRDMs & NIs Removal 232 177 492 119 166 269 1,455 1,455 5,536 141,063 7,193 2a.1.1.4 Reactor Vessel Internals 252 2,853 6,757 2,868 22,817 348 16,133 52,028 52,028 2,128 1,435 1,435 474,320 41,825 1,805 2a.1.1.5 Reactor Vessel 114 5,174 2,483 1,075 5,464 348 7,611 22,268 22,268 13,945 2,754 1,791,753 41,825 1,805 2a.1.1 Totals 756 8,337 9,764 4,113 9

28,959 695 24,265 76,899 76,899 238 24,972 4,189 1,435 2,740,204 96,177 3,610 Removal of Major Equipment 2a.1.2 Main Turbine/Generator 543 2,170 459 2,501 369 889 6,931 6,931 118,264 3,487 5,634,727 9,919 2a.1.3 Main Condensers 1,028 1,546 327 1,783 263 794 5,741 5,741 84,292 2,485 4,016,136 18,785 Cascading Costs from Clean Building Demolition 2a.1.4.1 Reactor Building 983 147 1,130 1,130 11,163 2a.1.4.2 Auxiliary Building 408 61 469 469 4,733 2a.1.4.3 Off Gas Building 71 11 82 82 920 2a.1.4.4 Turbine Building 597 90 687 687 7,337 2a.1.4 Totals 2,059 309 2,368 2,368 24,153 Disposal of Plant Systems 2a.1.5.1 Auxiliary Steam 108 2

4 24 31 169 169 1,250 50,766 1,862 2a.1.5.2 CSCS Equipment Cooling 6

1 7

7 122 2a.1.5.3 Circulating Water 175 26 201 201 3,464 2a.1.5.4 Circulating Water - RCA 225 4

8 50 65 353 353 2,599 105,533 3,802 2a.1.5.5 Clean Condensate Storage 83 12 95 95 1,677 2a.1.5.6 Clean Condensate Storage - RCA 25 0

0 3

7 36 36 150 6,112 419 2a.1.5.7 Condensate 934 84 107 382 296 389 2,191 2,191 19,997 2,795 1,062,833 17,322 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 5 of 23 Table C-1 LaSalle County Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:21 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Disposal of Plant Systems (continued) 2a.1.5.8 Condensate Booster 965 231 273 711 1,041 672 3,892 3,892 37,272 9,829 2,395,561 18,222 2a.1.5.9 Condensate Polishing Demineralizer 902 30 28 73 108 270 1,410 1,410 3,806 1,038 246,105 16,162 2a.1.5.10 Containment Combustible Gas Control 85 1

2 13 24 124 124 671 27,268 1,436 2a.1.5.11 Cycled Condensate Storage 297 12 12 29 48 94 492 492 1,526 454 102,734 5,352 2a.1.5.12 Drywell Instrument Nitrogen 61 1

2 12 18 94 94 646 26,238 1,070 2a.1.5.13 Extraction Steam 357 23 29 93 91 133 725 725 4,856 856 273,991 6,662 2a.1.5.14 Feedwater 593 59 72 208 249 259 1,440 1,440 10,913 2,357 654,598 11,054 2a.1.5.15 Feedwater Heater Vents & Drains 2,835 155 191 655 558 991 5,385 5,385 34,334 5,282 1,867,479 52,311 2a.1.5.16 Gland Steam 253 9

9 24 35 78 408 408 1,234 328 79,493 4,601 2a.1.5.17 HVAC-River\\Lake Screen House 8

1 9

9 151 2a.1.5.18 HVAC-Service Building 12 2

14 14 221 2a.1.5.19 Hydrogen & Carbon Dioxide 110 2

4 23 32 171 171 1,214 49,318 1,878 2a.1.5.20 Main Steam 138 5

5 8

24 43 223 223 422 226 37,404 2,483 2a.1.5.21 Misc Bldgs Floor Drains 0

0 1

1 9

2a.1.5.22 Screen Wash 25 4

29 29 506 2a.1.5.23 Service Air 11 2

13 13 222 2a.1.5.24 Standby Gas Treatment 57 4

5 15 15 21 116 116 770 141 43,939 1,047 2a.1.5.25 Station Heat Recovery 252 4

6 40 70 373 373 2,104 85,433 4,310 2a.1.5.26 Switchgear Heat Removal 10 1

11 11 180 2a.1.5.27 Turbine Bldg Closed Cooling Water 520 34 38 123 117 187 1,018 1,018 6,446 1,105 360,727 9,422 2a.1.5.28 Turbine Building Equip Drains 73 96 4

5 13 18 68 278 278 700 170 43,649 2,331 2a.1.5.29 Turbine Building Floor Drains 16 38 1

1 2

4 19 79 79 81 35 6,465 943 2a.1.5.30 Turbine Generator 199 27 30 55 137 99 546 546 2,857 1,297 232,141 3,760 2a.1.5.31 Turbine Oil 585 21 26 112 50 181 975 975 5,855 519 280,058 10,694 2a.1.5 Totals 89 9,966 713 855 2,667 2,790 3,800 20,878 20,499 380 139,705 26,433 8,037,842 183,694 2a.1.6 Scaffolding in support of decommissioning 2,357 39 9

43 14 604 3,066 3,066 2,054 128 103,876 48,820 2a.1 Subtotal Period 2a Activity Costs 845 24,289 14,232 5,763 7,003 32,395 695 30,661 115,883 115,503 380 344,553 57,504 4,189 1,435 20,532,780 381,550 3,610 Period 2a Collateral Costs 2a.3.1 Process liquid waste 91 46 224 257 148 767 767 784 55,478 153 2a.3.2 Small tool allowance 320 48 368 331 37 2a.3.3 Spent Fuel Capital and Transfer 17,000 2,550 19,550 19,550 2a.3 Subtotal Period 2a Collateral Costs 91 320 46 224 257 17,000 2,746 20,685 1,098 19,550 37 784 55,478 153 Period 2a Period-Dependent Costs 2a.4.1 Decon supplies 88 22 110 110 2a.4.2 Insurance 793 79 873 873 2a.4.3 Property taxes 4,818 482 5,300 4,770 530 2a.4.4 Health physics supplies 2,164 541 2,706 2,706 2a.4.5 Heavy equipment rental 3,142 471 3,613 3,613 2a.4.6 Disposal of DAW generated 20 8

404 104 536 536 7,248 144,951 33 2a.4.7 Plant energy budget 2,451 368 2,819 2,819 2a.4.8 NRC Fees 1,239 124 1,363 1,363 2a.4.9 Emergency Planning Fees 188 19 207 207 2a.4.10 Site O&M Costs 235 35 270 270 2a.4.11 Spent Fuel Pool O&M 1,435 215 1,650 1,650 2a.4.12 ISFSI Operating Costs 83 12 95 95 2a.4.13 Security Staff Cost 8,290 1,243 9,533 9,533 222,235 2a.4.14 DOC Staff Cost 24,139 3,621 27,760 27,760 298,354 2a.4.15 Utility Staff Cost 41,198 6,180 47,378 47,378 553,251 2a.4 Subtotal Period 2a Period-Dependent Costs 88 5,306 20 8

404 84,870 13,517 104,212 101,730 1,952 530 7,248 144,951 33 1,073,840 2a.0 TOTAL PERIOD 2a COST 1,023 29,916 14,298 5,994 7,003 33,057 102,565 46,924 240,780 218,331 21,502 947 344,553 65,536 4,189 1,435 20,733,210 381,736 1,077,450 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 6 of 23 Table C-1 LaSalle County Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:21 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours PERIOD 2b - Site Decontamination Period 2b Direct Decommissioning Activities Disposal of Plant Systems 2b.1.1.1 Aux Diesel Bldg Floor Drains 4

1 5

5 86 2b.1.1.2 Auxiliary Diesel Generator 52 8

59 59 1,006 2b.1.1.3 Control Rod Drive 216 4

5 14 15 61 315 315 718 146 42,251 4,064 2b.1.1.4 Diesel Oil 43 6

50 50 823 2b.1.1.5 Electrical 273 41 314 314 5,201 2b.1.1.6 Electrical - RCA 4,641 86 155 962 1,337 7,182 7,182 50,427 2,047,847 79,254 2b.1.1.7 Fire Protection 116 17 134 134 2,339 2b.1.1.8 HVAC-Auxiliary Building 220 6

10 52 8

67 362 362 2,745 73 118,018 3,773 2b.1.1.9 HVAC-Diesel Generator Room 7

1 8

8 127 2b.1.1.10 HVAC-Off Gas Building 22 0

1 4

1 6

34 34 226 6

9,699 376 2b.1.1.11 HVAC-Radwaste Building 6

0 0

2 0

2 11 11 101 4

4,494 108 2b.1.1.12 HVAC-Turbine Building 811 19 31 168 25 241 1,294 1,294 8,797 234 378,235 13,872 2b.1.1.13 High Pressure Core Spray 349 58 52 74 263 178 974 974 3,883 2,484 380,413 6,460 2b.1.1.14 Instrument Air 5

1 5

5 94 2b.1.1.15 Instrument Air - RCA 134 1

2 12 36 185 185 629 25,528 2,372 2b.1.1.16 Low Pressure Core Spray 167 27 24 33 123 84 458 458 1,754 1,159 175,160 3,078 2b.1.1.17 Nuclear Boiler 1,700 166 166 272 801 707 3,812 3,812 14,267 7,566 1,258,057 31,666 2b.1.1.18 Off Gas 662 48 46 68 231 245 1,301 1,301 3,564 2,192 340,686 12,044 2b.1.1.19 Primary Containment Vent & Purge 452 39 50 164 153 187 1,045 1,045 8,608 1,447 479,446 8,497 2b.1.1.20 Process Radiation Monitoring 22 0

0 0

1 6

30 30 19 12 1,822 437 2b.1.1.21 Process Sampling 30 0

0 1

2 8

42 42 57 17 3,831 589 2b.1.1.22 Radioactive Waste Disposal 1,609 83 70 139 314 520 2,736 2,736 7,272 3,297 561,812 29,103 2b.1.1.23 Reactor Building Equipment Drains 71 3

3 5

12 22 116 116 250 124 20,359 1,293 2b.1.1.24 Reactor Core Isolation Cooling 117 236 13 11 14 61 138 590 590 718 573 80,539 5,667 2b.1.1.25 Reactor Recirculation 44 1

1 1

4 13 64 64 76 39 6,618 819 2b.1.1.26 Reactor Water Clean-up 488 915 35 26 25 146 520 2,155 2,155 1,302 1,377 176,282 24,691 2b.1.1.27 Residual Heat Removal 1,534 1,715 269 247 353 1,243 1,623 6,984 6,984 18,520 11,751 1,805,919 38,888 2b.1.1.28 Service Air - RCA 234 2

4 25 63 328 328 1,326 53,837 3,994 2b.1.1.29 Service Water 48 7

55 55 938 2b.1.1.30 Service Water - RCA 683 22 40 247 216 1,208 1,208 12,930 525,074 11,877 2b.1.1.31 Standby Liquid Control 51 1

1 7

14 73 73 341 13,830 854 2b.1.1 Totals 2,138 15,538 885 945 2,644 3,403 6,376 31,929 31,298 631 138,527 32,502 8,509,760 294,389 2b.1.2 Scaffolding in support of decommissioning 2,946 49 11 54 17 755 3,832 3,832 2,567 160 129,845 61,026 Decontamination of Site Buildings 2b.1.3.1 Reactor Building 2,626 2,692 105 122 223 263 2,114 8,146 8,146 11,674 4,684 934,937 94,606 2b.1.3.2 Auxiliary Building 323 101 16 18 2

49 203 712 712 100 914 95,416 7,570 2b.1.3.3 Off Gas Building 147 58 12 13 1

35 100 365 365 46 651 66,884 3,619 2b.1.3.4 Turbine Building 1,726 1,003 141 159 98 399 1,266 4,793 4,793 5,149 7,435 946,610 47,961 2b.1.3 Totals 4,822 3,854 275 312 324 745 3,684 14,016 14,016 16,969 13,684 2,043,847 153,755 2b.1 Subtotal Period 2b Activity Costs 6,960 22,338 1,208 1,268 3,022 4,165 10,815 49,777 49,146 631 158,063 46,346 10,683,450 509,170 Period 2b Collateral Costs 2b.3.1 Process liquid waste 169 343 1,705 2,740 1,060 6,017 6,017 5,821 590,533 1,135 2b.3.2 Small tool allowance 414 62 476 476 2b.3.3 Spent Fuel Capital and Transfer 17,000 2,550 19,550 19,550 2b.3 Subtotal Period 2b Collateral Costs 169 414 343 1,705 2,740 17,000 3,672 26,043 6,493 19,550 5,821 590,533 1,135 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 7 of 23 Table C-1 LaSalle County Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:21 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 2b Period-Dependent Costs 2b.4.1 Decon supplies 1,482 371 1,853 1,853 2b.4.2 Insurance 895 89 984 984 2b.4.3 Property taxes 1,061 106 1,167 1,167 2b.4.4 Health physics supplies 2,651 663 3,313 3,313 2b.4.5 Heavy equipment rental 3,515 527 4,042 4,042 2b.4.6 Disposal of DAW generated 24 9

480 124 637 637 8,609 172,182 39 2b.4.7 Plant energy budget 2,183 327 2,511 2,511 2b.4.8 NRC Fees 1,397 140 1,537 1,537 2b.4.9 Emergency Planning Fees 212 21 233 233 2b.4.10 Site O&M Costs 265 40 305 305 2b.4.11 Spent Fuel Pool O&M 1,619 243 1,862 1,862 2b.4.12 Liquid Radwaste Processing Equipment/Services 407 61 468 468 2b.4.13 ISFSI Operating Costs 93 14 107 107 2b.4.14 Security Staff Cost 909 136 1,045 1,045 24,357 2b.4.15 DOC Staff Cost 18,478 2,772 21,249 21,249 239,143 2b.4.16 Utility Staff Cost 31,728 4,759 36,487 36,487 445,071 2b.4 Subtotal Period 2b Period-Dependent Costs 1,482 6,166 24 9

480 59,246 10,393 77,800 75,598 2,202 8,609 172,182 39 708,571 2b.0 TOTAL PERIOD 2b COST 8,611 28,918 1,575 2,982 3,022 7,385 76,246 24,880 153,620 131,236 21,752 631 158,063 60,776 11,446,170 510,344 708,571 PERIOD 2c - Decontamination Following Wet Fuel Storage Period 2c Direct Decommissioning Activities 2c.1.1 Remove spent fuel racks 918 82 166 157 1,030 777 3,130 3,130 9,726 872,665 1,631 Disposal of Plant Systems 2c.1.2.1 Containment Monitoring 23 0

0 1

1 6

32 32 55 12 3,285 439 2c.1.2.2 Electrical - Contaminated 750 11 18 100 15 210 1,104 1,104 5,233 139 225,019 13,327 2c.1.2.3 Fire Protection - RCA 664 13 23 143 192 1,035 1,035 7,493 304,287 11,294 2c.1.2.4 Fuel Pool Cooling & Cleanup 810 48 57 193 171 288 1,567 1,567 10,121 1,621 556,011 14,738 2c.1.2.5 HVAC-Primary Containment 959 32 44 194 86 300 1,615 1,615 10,180 814 485,888 16,962 2c.1.2.6 Reactor Bldg Closed Cooling Water 339 43 51 178 146 160 917 917 9,311 1,379 501,684 6,004 2c.1.2.7 Reactor Building Floor Drains 7

0 0

0 1

2 10 10 8

7 951 123 2c.1.2 Totals 3,550 148 194 809 419 1,158 6,278 6,278 42,400 3,971 2,077,126 62,887 Decontamination of Site Buildings 2c.1.3.1 Reactor Building Spent Fuel Pool 265 973 254 262 16 1,201 743 3,714 3,714 842 14,610 1,412,321 20,548 2c.1.3 Totals 265 973 254 262 16 1,201 743 3,714 3,714 842 14,610 1,412,321 20,548 2c.1.4 Scaffolding in support of decommissioning 589 10 2

11 3

151 766 766 513 32 25,969 12,205 2c.1 Subtotal Period 2c Activity Costs 1,183 5,195 578 615 836 2,653 2,829 13,889 13,889 43,756 28,339 4,388,080 97,271 Period 2c Additional Costs 2c.2.1 License Termination Survey Planning 940 282 1,222 1,222 6,240 2c.2 Subtotal Period 2c Additional Costs 940 282 1,222 1,222 6,240 Period 2c Collateral Costs 2c.3.1 Process liquid waste 137 55 266 262 179 899 899 940 56,409 183 2c.3.2 Small tool allowance 92 14 106 106 2c.3.3 Decommissioning Equipment Disposition 114 31 127 40 45 356 356 6,000 373 303,507 88 2c.3 Subtotal Period 2c Collateral Costs 137 92 169 297 127 301 238 1,362 1,362 6,000 1,314 359,916 271 Period 2c Period-Dependent Costs 2c.4.1 Decon supplies 48 12 60 60 2c.4.2 Insurance 222 22 244 244 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 8 of 23 Table C-1 LaSalle County Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:21 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 2c Period-Dependent Costs (continued) 2c.4.3 Property taxes 263 26 289 289 2c.4.4 Health physics supplies 531 133 664 664 2c.4.5 Heavy equipment rental 871 131 1,001 1,001 2c.4.6 Disposal of DAW generated 8

3 168 43 223 223 3,008 60,169 14 2c.4.7 Plant energy budget 288 43 332 332 2c.4.8 NRC Fees 346 35 381 381 2c.4.9 Emergency Planning Fees 53 5

58 58 2c.4.10 Site O&M Costs 66 10 76 76 2c.4.11 Liquid Radwaste Processing Equipment/Services 202 30 232 232 2c.4.12 ISFSI Operating Costs 23 3

27 27 2c.4.13 Security Staff Cost 123 18 141 141 3,291 2c.4.14 DOC Staff Cost 3,093 464 3,557 3,557 40,046 2c.4.15 Utility Staff Cost 4,644 697 5,341 5,341 66,377 2c.4 Subtotal Period 2c Period-Dependent Costs 48 1,402 8

3 168 9,322 1,673 12,625 12,540 84 3,008 60,169 14 109,714 2c.0 TOTAL PERIOD 2c COST 1,368 6,689 755 915 963 3,123 10,262 5,022 29,097 29,013 84 49,756 32,661 4,808,165 97,556 115,954 PERIOD 2d - Delay before License Termination Period 2d Direct Decommissioning Activities Period 2d Period-Dependent Costs 2d.4.1 Insurance 647 65 711 711 2d.4.2 Property taxes 825 83 908 908 2d.4.3 Health physics supplies 118 30 148 148 2d.4.4 Disposal of DAW generated 0

0 9

2 12 12 165 3,294 1

2d.4.5 Plant energy budget 2d.4.6 NRC Fees 301 30 332 332 2d.4.7 Emergency Planning Fees 165 17 182 182 2d.4.8 Site O&M Costs 206 31 237 237 2d.4.9 ISFSI Operating Costs 73 11 83 83 2d.4.10 Security Staff Cost 386 58 443 443 10,337 2d.4.11 Utility Staff Cost 1,697 255 1,952 1,952 24,120 2d.4 Subtotal Period 2d Period-Dependent Costs 118 0

0 9

4,301 580 5,008 4,743 265 165 3,294 1

34,457 2d.0 TOTAL PERIOD 2d COST 118 0

0 9

4,301 580 5,008 4,743 265 165 3,294 1

34,457 PERIOD 2e - License Termination Period 2e Direct Decommissioning Activities 2e.1.1 ORISE confirmatory survey 151 45 197 197 2e.1.2 Terminate license a

2e.1 Subtotal Period 2e Activity Costs 151 45 197 197 Period 2e Additional Costs 2e.2.1 License Termination Survey 10,410 3,123 13,533 13,533 191,885 3,120 2e.2 Subtotal Period 2e Additional Costs 10,410 3,123 13,533 13,533 191,885 3,120 Period 2e Collateral Costs 2e.3.1 DOC staff relocation expenses 1,130 169 1,299 1,299 2e.3.2 Spent Fuel Capital and Transfer 1,500 225 1,725 1,725 2e.3 Subtotal Period 2e Collateral Costs 2,630 394 3,024 1,299 1,725 Period 2e Period-Dependent Costs 2e.4.1 Insurance 299 30 329 329 2e.4.2 Property taxes 382 38 420 420 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 9 of 23 Table C-1 LaSalle County Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:21 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 2e Period-Dependent Costs (continued) 2e.4.3 Health physics supplies 942 236 1,178 1,178 2e.4.4 Disposal of DAW generated 1

0 19 5

25 25 342 6,832 2

2e.4.5 Plant energy budget 210 31 241 241 2e.4.6 NRC Fees 539 54 593 593 2e.4.7 Emergency Planning Fees 76 8

84 84 2e.4.8 Site O&M Costs 95 14 110 110 2e.4.9 ISFSI Operating Costs 34 5

39 39 2e.4.10 Security Staff Cost 1,197 180 1,377 1,377 28,299 2e.4.11 DOC Staff Cost 3,856 578 4,434 4,434 47,430 2e.4.12 Utility Staff Cost 4,865 730 5,594 5,594 60,981 2e.4 Subtotal Period 2e Period-Dependent Costs 942 1

0 19 11,553 1,909 14,425 14,302 123 342 6,832 2

136,710 2e.0 TOTAL PERIOD 2e COST 942 1

0 19 24,745 5,472 31,180 29,332 1,848 342 6,832 191,887 139,830 PERIOD 2 TOTALS 11,002 66,583 16,629 9,892 10,989 43,593 218,119 82,878 459,685 412,656 45,452 1,577 552,372 159,479 4,189 1,435 36,997,670 1,181,524 2,076,263 PERIOD 3b - Site Restoration Period 3b Direct Decommissioning Activities Demolition of Remaining Site Buildings 3b.1.1.1 Reactor Building 5,664 850 6,514 6,514 64,472 3b.1.1.2 Auxiliary Building 3,692 554 4,246 4,246 43,048 3b.1.1.3 Diesel Generator Room 468 70 538 538 6,000 3b.1.1.4 Off Gas Building 648 97 745 745 8,484 3b.1.1.5 Turbine Building 5,501 825 6,326 6,326 68,584 3b.1.1.6 Turbine Pedestal 2,881 432 3,313 3,313 30,829 3b.1.1 Totals 18,854 2,828 21,682 21,682 221,416 Site Closeout Activities 3b.1.2 Grade & landscape site 149 22 171 171 499 3b.1.3 Final report to NRC 184 28 212 212 1,560 3b.1 Subtotal Period 3b Activity Costs 19,003 184 2,878 22,065 212 21,853 221,916 1,560 Period 3b Additional Costs 3b.2.1 Concrete Crushing 776 4

117 897 897 3,936 3b.2 Subtotal Period 3b Additional Costs 776 4

117 897 897 3,936 Period 3b Collateral Costs 3b.3.1 Small tool allowance 194 29 223 223 3b.3.2 Spent Fuel Capital and Transfer 3,000 450 3,450 3,450 3b.3 Subtotal Period 3b Collateral Costs 194 3,000 479 3,673 3,450 223 Period 3b Period-Dependent Costs 3b.4.1 Insurance 782 78 860 860 3b.4.2 Property taxes 998 100 1,098 1,098 3b.4.3 Heavy equipment rental 4,728 709 5,437 5,437 3b.4.4 Plant energy budget 274 41 315 63 252 3b.4.5 NRC ISFSI Fees 372 37 409 409 3b.4.6 Emergency Planning Fees 200 20 220 220 3b.4.7 ISFSI Operating Costs 88 13 101 101 3b.4.8 Site O&M Cost 249 37 287 287 3b.4.9 Security Staff Cost 2,993 449 3,442 (0) 2,822 619 70,317 3b.4.10 DOC Staff Cost 9,384 1,408 10,792 10,792 110,391 3b.4.11 Utility Staff Cost 5,667 850 6,516 (0) 1,238 5,278 70,317 3b.4 Subtotal Period 3b Period-Dependent Costs 4,728 21,006 3,743 29,476 (0) 6,811 22,666 251,026 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 10 of 23 Table C-1 LaSalle County Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:21 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours 3b.0 TOTAL PERIOD 3b COST 24,700 24,194 7,217 56,110 212 10,261 45,638 225,852 252,586 PERIOD 3c - Fuel Storage Operations/Shipping Period 3c Direct Decommissioning Activities Period 3c Collateral Costs 3c.3.1 Spent Fuel Capital and Transfer 4,500 675 5,175 5,175 3c.3 Subtotal Period 3c Collateral Costs 4,500 675 5,175 5,175 Period 3c Period-Dependent Costs 3c.4.1 Insurance 1,248 125 1,373 1,373 3c.4.2 Property taxes 1,593 159 1,753 1,753 3c.4.3 Plant energy budget 3c.4.4 NRC ISFSI Fees 594 59 654 654 3c.4.5 Emergency Planning Fees 319 32 351 351 3c.4.6 ISFSI Operating Costs 140 21 161 161 3c.4.7 Security Staff Cost 3,941 591 4,532 4,532 89,794 3c.4.8 Utility Staff Cost 1,723 258 1,981 1,981 22,482 3c.4 Subtotal Period 3c Period-Dependent Costs 9,559 1,246 10,805 10,805 112,276 3c.0 TOTAL PERIOD 3c COST 14,059 1,921 15,980 15,980 112,276 PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d.1.1.1 Vessel & Internals GTCC Disposal 500 11,118 1,718 13,336 13,336 671 109,910 3d.1.1 Totals 500 11,118 1,718 13,336 13,336 671 109,910 3d.1 Subtotal Period 3d Activity Costs 500 11,118 1,718 13,336 13,336 671 109,910 Period 3d Period-Dependent Costs 3d.4.1 Insurance 32 3

35 35 3d.4.2 Property taxes 41 4

45 45 3d.4.3 Plant energy budget 3d.4.4 NRC ISFSI Fees 15 2

17 17 3d.4.5 Emergency Planning Fees 8

1 9

9 3d.4.6 ISFSI Operating Costs 4

1 4

4 3d.4.7 Security Staff Cost 102 15 117 117 2,314 3d.4.8 Utility Staff Cost 44 7

51 51 579 3d.4 Subtotal Period 3d Period-Dependent Costs 246 32 278 278 2,894 3d.0 TOTAL PERIOD 3d COST 500 11,118 246 1,750 13,614 13,336 278 671 109,910 2,894 PERIOD 3e - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 3e Additional Costs 3e.2.1 ISFSI License Termination 57 1

38 153 749 169 1,167 1,167 2,905 244,104 3,498 1,280 3e.2 Subtotal Period 3e Additional Costs 57 1

38 153 749 169 1,167 1,167 2,905 244,104 3,498 1,280 Period 3e Collateral Costs 3e.3.1 Small tool allowance 1

0 1

1 3e.3 Subtotal Period 3e Collateral Costs 1

0 1

1 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 11 of 23 Table C-1 LaSalle County Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:21 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 3e Period-Dependent Costs 3e.4.1 Insurance 128 13 140 140 3e.4.2 Property taxes 163 16 179 179 3e.4.3 Heavy equipment rental 209 31 241 241 3e.4.4 Plant energy budget 3e.4.5 Security Staff Cost 106 16 122 122 2,468 3e.4.6 Utility Staff Cost 147 22 169 169 1,870 3e.4 Subtotal Period 3e Period-Dependent Costs 209 544 98 851 851 4,338 3e.0 TOTAL PERIOD 3e COST 267 1

38 153 1,292 267 2,018 2,018 2,905 244,104 3,498 5,618 PERIOD 3f - ISFSI Site Restoration Period 3f Direct Decommissioning Activities Period 3f Additional Costs 3f.2.1 ISFSI Demolition and Site Restoration 1,604 24 244 1,872 1,872 21,545 80 3f.2 Subtotal Period 3f Additional Costs 1,604 24 244 1,872 1,872 21,545 80 Period 3f Collateral Costs 3f.3.1 Small tool allowance 18 3

21 21 3f.3 Subtotal Period 3f Collateral Costs 18 3

21 21 Period 3f Period-Dependent Costs 3f.4.1 Insurance 3f.4.2 Property taxes 86 9

95 95 3f.4.3 Heavy equipment rental 86 13 98 98 3f.4.4 Plant energy budget 3f.4.5 Security Staff Cost 56 8

64 64 1,307 3f.4.6 Utility Staff Cost 64 10 73 73 810 3f.4 Subtotal Period 3f Period-Dependent Costs 86 206 39 331 331 2,117 3f.0 TOTAL PERIOD 3f COST 1,708 230 286 2,224 2,224 21,545 2,197 PERIOD 3 TOTALS 26,675 501 38 11,271 40,021 11,441 89,946 13,547 30,761 45,638 2,905 671 354,014 250,895 375,571 TOTAL COST TO DECOMMISSION 13,858 95,574 17,204 10,286 10,989 58,521 379,423 115,226 701,080 546,754 106,181 48,145 552,372 163,604 5,149 1,435 671 37,492,660 1,463,456 3,293,782 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 12 of 23 Table C-1 LaSalle County Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:21 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours TOTAL COST TO DECOMMISSION WITH 19.67% CONTINGENCY:

$701,080 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 77.99% OR:

$546,754 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 15.15% OR:

$106,181 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 6.87% OR:

$48,145 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

170,188 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

671 cubic feet TOTAL SCRAP METAL REMOVED:

52,025 tons TOTAL CRAFT LABOR REQUIREMENTS:

1,463,456 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.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 13 of 23 Table C-2 LaSalle County Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs 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 Activities 1a.1.1 Prepare preliminary decommissioning cost 64 10 74 74 545 1a.1.2 Notification of Cessation of Operations a

1a.1.3 Remove fuel & source material n/a 1a.1.4 Notification of Permanent Defueling a

1a.1.5 Deactivate plant systems & process waste a

1a.1.6 Prepare and submit PSDAR 99 15 114 114 838 1a.1.7 Review plant dwgs & specs.

227 34 262 262 1,927 1a.1.8 Perform detailed rad survey a

1a.1.9 Estimate by-product inventory 49 7

57 57 419 1a.1.10 End product description 49 7

57 57 419 1a.1.11 Detailed by-product inventory 64 10 74 74 545 1a.1.12 Define major work sequence 371 56 426 426 3,143 1a.1.13 Perform SER and EA 153 23 176 176 1,299 1a.1.14 Perform Site-Specific Cost Study 247 37 284 284 2,095 1a.1.15 Prepare/submit License Termination Plan 203 30 233 233 1,716 1a.1.16 Receive NRC approval of termination plan a

Activity Specifications 1a.1.17.1 Plant & temporary facilities 243 36 280 252 28 2,061 1a.1.17.2 Plant systems 206 31 237 213 24 1,746 1a.1.17.3 NSSS Decontamination Flush 25 4

28 28 210 1a.1.17.4 Reactor internals 351 53 404 404 2,975 1a.1.17.5 Reactor vessel 321 48 370 370 2,724 1a.1.17.6 Sacrificial shield 25 4

28 28 210 1a.1.17.7 Moisture separators/reheaters 49 7

57 57 419 1a.1.17.8 Reinforced concrete 79 12 91 45 45 670 1a.1.17.9 Main Turbine 103 15 119 119 875 1a.1.17.10 Main Condensers 103 15 119 119 875 1a.1.17.11 Pressure suppression structure 99 15 114 114 838 1a.1.17.12 Drywell 79 12 91 91 670 1a.1.17.13 Plant structures & buildings 154 23 177 89 89 1,307 1a.1.17.14 Waste management 227 34 262 262 1,927 1a.1.17.15 Facility & site closeout 45 7

51 26 26 377 1a.1.17 Total 2,110 317 2,427 2,216 211 17,884 Planning & Site Preparations 1a.1.18 Prepare dismantling sequence 119 18 136 136 1,006 1a.1.19 Plant prep. & temp. svces 2,800 420 3,220 3,220 1a.1.20 Design water clean-up system 69 10 80 80 587 1a.1.21 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,200 330 2,530 2,530 1a.1.22 Procure casks/liners & containers 61 9

70 70 515 1a.1 Subtotal Period 1a Activity Costs 8,887 1,333 10,220 10,008 211 32,937 Period 1a Additional Costs 1a.2.1 ISFSI Expansion 10,400 1,560 11,960 11,960 1a.2 Subtotal Period 1a Additional Costs 10,400 1,560 11,960 11,960 Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 15,000 2,250 17,250 17,250 1a.3 Subtotal Period 1a Collateral Costs 15,000 2,250 17,250 17,250 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 14 of 23 Table C-2 LaSalle County Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 1a Period-Dependent Costs 1a.4.1 Insurance 876 88 964 964 1a.4.2 Property taxes 1a.4.3 Health physics supplies 373 93 466 466 1a.4.4 Heavy equipment rental 396 59 455 455 1a.4.5 Disposal of DAW generated 2

1 32 8

42 42 565 11,299 3

1a.4.6 Plant energy budget 1,371 206 1,577 1,577 1a.4.7 NRC Fees 471 47 518 518 1a.4.8 Emergency Planning Fees 313 31 344 344 1a.4.9 Site O&M Costs 125 19 144 144 1a.4.10 Spent Fuel Pool O&M 762 114 877 877 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 457 69 526 526 12,264 1a.4.13 Utility Staff Cost 24,828 3,724 28,552 28,552 346,229 1a.4 Subtotal Period 1a Period-Dependent Costs 769 2

1 32 29,247 4,465 34,514 33,243 1,271 565 11,299 3

358,493 1a.0 TOTAL PERIOD 1a COST 769 2

1 32 63,534 9,608 73,944 43,252 30,481 211 565 11,299 3

391,430 PERIOD 1b - Decommissioning Preparations Period 1b Direct Decommissioning Activities Detailed Work Procedures 1b.1.1.1 Plant systems 234 35 269 242 27 1,983 1b.1.1.2 NSSS Decontamination Flush 49 7

57 57 419 1b.1.1.3 Reactor internals 198 30 227 227 1,676 1b.1.1.4 Remaining buildings 67 10 77 19 58 566 1b.1.1.5 CRD housings & NIs 49 7

57 57 419 1b.1.1.6 Incore instrumentation 49 7

57 57 419 1b.1.1.7 Removal primary containment 99 15 114 114 838 1b.1.1.8 Reactor vessel 179 27 206 206 1,521 1b.1.1.9 Facility closeout 59 9

68 34 34 503 1b.1.1.10 Sacrificial shield 59 9

68 68 503 1b.1.1.11 Reinforced concrete 49 7

57 28 28 419 1b.1.1.12 Main Turbine 103 15 118 118 872 1b.1.1.13 Main Condensers 103 15 119 119 875 1b.1.1.14 Moisture separators & reheaters 99 15 114 114 838 1b.1.1.15 Radwaste building 135 20 155 140 16 1,144 1b.1.1.16 Reactor building 135 20 155 140 16 1,144 1b.1.1 Total 1,668 250 1,919 1,741 178 14,137 1b.1.2 Decon NSSS 631 315 946 946 1,067 1b.1 Subtotal Period 1b Activity Costs 631 1,668 566 2,864 2,686 178 1,067 14,137 Period 1b Additional Costs 1b.2.1 Site Characterization 2,550 765 3,315 3,315 12,457 4,471 1b.2.2 Spent Fuel Pool Isolation 6,460 969 7,429 7,429 1b.2 Subtotal Period 1b Additional Costs 9,010 1,734 10,744 10,744 12,457 4,471 Period 1b Collateral Costs 1b.3.1 Decon equipment 763 114 877 877 1b.3.2 DOC staff relocation expenses 1,130 169 1,299 1,299 1b.3.3 Process liquid waste 39 71 355 3,604 981 5,050 5,050 252 960 121,632 236 1b.3.4 Small tool allowance 2

0 2

2 1b.3.5 Pipe cutting equipment 1,100 165 1,265 1,265 1b.3.6 Decon rig 1,400 210 1,610 1,610 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 15 of 23 Table C-2 LaSalle County Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 1b Collateral Costs (continued) 1b.3.7 Spent Fuel Capital and Transfer 8,000 1,200 9,200 9,200 1b.3 Subtotal Period 1b Collateral Costs 2,202 1,102 71 355 3,604 9,130 2,840 19,304 10,104 9,200 252 960 121,632 236 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 23 6

29 29 1b.4.2 Insurance 211 21 232 232 1b.4.3 Property taxes 2,321 232 2,554 2,554 1b.4.4 Health physics supplies 206 52 258 258 1b.4.5 Heavy equipment rental 198 30 228 228 1b.4.6 Disposal of DAW generated 1

0 18 5

24 24 325 6,507 1

1b.4.7 Plant energy budget 1,375 206 1,581 1,581 1b.4.8 NRC Fees 236 24 260 260 1b.4.9 Emergency Planning Fees 157 16 172 172 1b.4.10 Site O&M Costs 63 9

72 72 1b.4.11 Spent Fuel Pool O&M 382 57 440 440 1b.4.12 ISFSI Operating Costs 22 3

25 25 1b.4.13 Security Staff Cost 229 34 264 264 6,149 1b.4.14 DOC Staff Cost 3,689 553 4,242 4,242 47,057 1b.4.15 Utility Staff Cost 12,448 1,867 14,315 14,315 173,589 1b.4 Subtotal Period 1b Period-Dependent Costs 23 404 1

0 18 21,134 3,116 24,696 24,059 637 325 6,507 1

226,795 1b.0 TOTAL PERIOD 1b COST 2,856 1,506 72 355 3,622 40,942 8,255 57,608 47,592 9,837 178 577 960 128,139 13,761 245,403 PERIOD 1 TOTALS 2,856 2,275 74 355 3,654 104,476 17,863 131,552 90,844 40,319 390 1,142 960 139,438 13,764 636,833 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.1 Recirculation System Piping & Valves 103 85 18 22 198 127 553 553 1,006 121,649 3,377 2a.1.1.2 Recirculation Pumps & Motors 55 48 14 30 9

313 125 594 594 238 2,356 211,420 1,957 2a.1.1.3 CRDMs & NIs Removal 232 177 492 119 166 269 1,455 1,455 5,536 141,063 7,193 2a.1.1.4 Reactor Vessel Internals 252 2,853 6,757 2,868 22,908 348 16,178 52,163 52,163 2,003 1,560 1,435 474,320 41,825 1,805 2a.1.1.5 Reactor Vessel 114 5,174 2,483 1,075 5,466 348 7,612 22,270 22,270 13,945 2,754 1,791,753 41,825 1,805 2a.1.1 Totals 756 8,337 9,764 4,113 9

29,051 695 24,311 77,037 77,037 238 24,846 4,315 1,435 2,740,204 96,177 3,610 Removal of Major Equipment 2a.1.2 Main Turbine/Generator 543 2,170 459 2,501 369 889 6,931 6,931 118,264 3,487 5,634,727 9,919 2a.1.3 Main Condensers 1,028 1,546 327 1,783 263 794 5,741 5,741 84,292 2,485 4,016,136 18,785 Cascading Costs from Clean Building Demolition 2a.1.4.1 Reactor Building 985 148 1,132 1,132 11,181 2a.1.4.2 Auxiliary Building 407 61 468 468 4,723 2a.1.4.3 IRSF Building 74 11 85 85 939 2a.1.4.4 Service Building 162 24 187 187 2,230 2a.1.4.5 Solid Radwaste Building 224 34 258 258 2,559 2a.1.4.6 Turbine Building 597 90 687 687 7,337 2a.1.4 Totals 2,449 367 2,816 2,816 28,970 Disposal of Plant Systems 2a.1.5.1 Acid & Caustic 17 2

19 19 317 2a.1.5.2 Auxiliary Steam 304 7

12 74 89 486 486 3,882 157,664 5,230 2a.1.5.3 CSCS Equipment Cooling 7

1 9

9 141 2a.1.5.4 Chemical Feed 34 5

39 39 638 2a.1.5.5 Circulating Water 158 24 182 182 3,125 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 16 of 23 Table C-2 LaSalle County Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Disposal of Plant Systems (continued) 2a.1.5.6 Circulating Water - RCA 218 3

6 36 61 324 324 1,874 76,117 3,663 2a.1.5.7 Clean Condensate Storage 146 22 168 168 2,875 2a.1.5.8 Clean Condensate Storage - RCA 68 1

1 8

18 96 96 429 17,422 1,131 2a.1.5.9 Condensate 801 77 98 353 269 343 1,940 1,940 18,488 2,540 978,672 14,863 2a.1.5.10 Condensate Booster 902 227 269 697 1,028 650 3,774 3,774 36,538 9,709 2,354,967 17,069 2a.1.5.11 Condensate Polishing Demineralizer 893 30 28 72 111 269 1,404 1,404 3,756 1,065 246,471 15,985 2a.1.5.12 Containment Combustible Gas Control 69 1

2 11 19 101 101 567 23,007 1,161 2a.1.5.13 Cycled Condensate Storage 532 21 27 110 60 170 920 920 5,741 602 283,940 9,749 2a.1.5.14 Drywell Instrument Nitrogen 59 1

2 12 17 90 90 613 24,892 1,048 2a.1.5.15 Extraction Steam 294 20 25 79 78 111 606 606 4,161 736 234,989 5,484 2a.1.5.16 Feedwater 508 56 67 194 235 230 1,289 1,289 10,138 2,218 610,662 9,480 2a.1.5.17 Feedwater Heater Vents & Drains 2,350 138 169 587 492 838 4,574 4,574 30,744 4,650 1,665,071 43,380 2a.1.5.18 Gland Steam 210 8

8 21 30 65 342 342 1,117 281 70,536 3,809 2a.1.5.19 HVAC-Machine Shop\\TB Sandblast 33 1

1 5

1 9

49 49 256 7

11,025 598 2a.1.5.20 HVAC-River\\Lake Screen House 21 3

24 24 422 2a.1.5.21 HVAC-Service Building 54 8

63 63 1,072 2a.1.5.22 Hydrogen & Carbon Dioxide 36 5

41 41 708 2a.1.5.23 Lake Makeup & Blowdown 214 32 246 246 4,257 2a.1.5.24 Main Steam 114 5

4 7

22 36 187 187 375 203 33,466 2,050 2a.1.5.25 Makeup Demineralizer 688 25 32 142 61 216 1,164 1,164 7,416 634 352,906 12,612 2a.1.5.26 Misc Bldgs Floor Drains 832 1,156 66 58 125 250 802 3,288 3,288 6,544 2,367 477,918 29,288 2a.1.5.27 Refrigeration 55 8

63 63 1,110 2a.1.5.28 Refrigeration - RCA 40 0

1 5

11 57 57 245 9,954 666 2a.1.5.29 Screen Wash 20 3

23 23 407 2a.1.5.30 Service Air 22 3

25 25 427 2a.1.5.31 Sewage Treatment 87 13 100 100 1,741 2a.1.5.32 Standby Gas Treatment 46 3

4 13 13 18 97 97 661 122 37,760 855 2a.1.5.33 Station Heat Recovery 581 18 31 195 181 1,007 1,007 10,223 415,159 10,039 2a.1.5.34 Switchgear Heat Removal 10 1

11 11 180 2a.1.5.35 Turbine Bldg Closed Cooling Water 459 32 36 118 111 169 924 924 6,181 1,047 344,838 8,319 2a.1.5.36 Turbine Building Equipment Drains 59 81 4

4 12 15 56 232 232 610 146 37,892 1,912 2a.1.5.37 Turbine Building Floor Drains 32 82 2

2 3

8 39 168 168 183 73 13,933 2,020 2a.1.5.38 Turbine Generator 237 28 32 66 139 111 613 613 3,455 1,319 257,852 4,479 2a.1.5.39 Turbine Oil 684 24 28 115 64 211 1,128 1,128 6,048 656 300,237 12,441 2a.1.5.40 Wastewater Treatment 129 19 148 148 2,499 2a.1.5 Totals 923 12,418 798 948 3,059 2,985 4,892 26,022 24,861 1,161 160,246 28,376 9,037,352 237,248 2a.1.6 Scaffolding in support of decommissioning 2,722 43 10 48 15 697 3,534 3,534 2,253 140 113,976 56,438 2a.1 Subtotal Period 2a Activity Costs 1,678 27,498 14,321 5,857 7,399 32,683 695 31,950 122,082 120,921 1,161 365,294 59,334 4,315 1,435 21,542,400 447,539 3,610 Period 2a Collateral Costs 2a.3.1 Process liquid waste 101 119 589 883 372 2,065 2,065 2,024 190,399 395 2a.3.2 Small tool allowance 374 56 430 387 43 2a.3.3 Spent Fuel Capital and Transfer 25,000 3,750 28,750 28,750 2a.3 Subtotal Period 2a Collateral Costs 101 374 119 589 883 25,000 4,178 31,244 2,452 28,750 43 2,024 190,399 395 Period 2a Period-Dependent Costs 2a.4.1 Decon supplies 88 22 110 110 2a.4.2 Insurance 793 79 873 873 2a.4.3 Property taxes 4,818 482 5,300 4,770 530 2a.4.4 Health physics supplies 2,408 602 3,010 3,010 2a.4.5 Heavy equipment rental 3,142 471 3,613 3,613 2a.4.6 Disposal of DAW generated 21 8

437 112 579 579 7,823 156,465 36 2a.4.7 Plant energy budget 2,451 368 2,819 2,819 2a.4.8 NRC Fees 848 85 933 933 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 17 of 23 Table C-2 LaSalle County Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 2a Period-Dependent Costs (continued) 2a.4.9 Emergency Planning Fees 188 19 207 207 2a.4.10 Site O&M Costs 235 35 270 270 2a.4.11 Spent Fuel Pool O&M 1,435 215 1,650 1,650 2a.4.12 ISFSI Operating Costs 83 12 95 95 2a.4.13 Security Staff Cost 9,960 1,494 11,455 11,455 248,301 2a.4.14 DOC Staff Cost 24,139 3,621 27,760 27,760 298,354 2a.4.15 Utility Staff Cost 41,456 6,218 47,675 47,675 555,489 2a.4 Subtotal Period 2a Period-Dependent Costs 88 5,550 21 8

437 86,408 13,837 106,348 103,866 1,952 530 7,823 156,465 36 1,102,144 2a.0 TOTAL PERIOD 2a COST 1,867 33,421 14,462 6,454 7,399 34,003 112,103 49,965 259,675 227,239 30,702 1,734 365,294 69,181 4,315 1,435 21,889,260 447,969 1,105,754 PERIOD 2b - Site Decontamination Period 2b Direct Decommissioning Activities Disposal of Plant Systems 2b.1.1.1 Aux Diesel Bldg Floor Drains 8

1 9

9 147 2b.1.1.2 Auxiliary Diesel Generator 69 10 79 79 1,341 2b.1.1.3 Control Rod Drive 206 4

4 13 14 58 300 300 694 136 40,347 3,887 2b.1.1.4 Diesel Oil 58 9

67 67 1,104 2b.1.1.5 Domestic Water 25 4

29 29 499 2b.1.1.6 Domestic Water - RCA 39 0

1 5

11 56 56 263 10,694 653 2b.1.1.7 Electrical 518 78 596 596 9,872 2b.1.1.8 Electrical - RCA 5,152 94 168 1,047 1,480 7,941 7,941 54,830 2,226,676 87,927 2b.1.1.9 Fire Protection 214 32 246 246 4,263 2b.1.1.10 HVAC-Auxiliary Building 290 8

13 72 11 89 482 482 3,773 100 162,244 5,080 2b.1.1.11 HVAC-Control Rm\\Aux Equip Area 38 6

44 44 729 2b.1.1.12 HVAC-Diesel Generator Room 14 2

16 16 284 2b.1.1.13 HVAC-Off Gas Building 68 3

5 28 4

23 132 132 1,470 39 63,223 1,242 2b.1.1.14 HVAC-Radwaste Building 108 2

4 22 4

32 172 172 1,130 35 49,058 1,906 2b.1.1.15 HVAC-Turbine Building 811 19 31 168 25 241 1,294 1,294 8,797 234 378,235 13,872 2b.1.1.16 High Pressure Core Spray 297 55 49 69 249 160 879 879 3,637 2,355 358,873 5,498 2b.1.1.17 Instrument Air 7

1 9

9 152 2b.1.1.18 Instrument Air - RCA 142 1

2 13 38 197 197 681 27,654 2,514 2b.1.1.19 Low Pressure Core Spray 141 26 23 31 116 75 413 413 1,647 1,100 165,528 2,613 2b.1.1.20 Nuclear Boiler 1,410 145 144 235 694 597 3,224 3,224 12,316 6,555 1,088,103 26,278 2b.1.1.21 Off Gas 558 43 41 61 208 211 1,122 1,122 3,170 1,968 304,618 10,160 2b.1.1.22 Primary Containment Vent & Purge 440 36 46 160 135 178 994 994 8,370 1,282 454,098 8,267 2b.1.1.23 Process Radiation Monitoring 14 0

0 0

1 4

20 20 19 8

1,433 282 2b.1.1.24 Process Sampling 52 1

1 3

3 14 74 74 158 27 8,792 1,001 2b.1.1.25 Radioactive Waste Disposal 2,457 135 116 241 506 808 4,263 4,263 12,638 5,367 941,983 44,557 2b.1.1.26 Radwaste Area Floor Drains 2

0 0

0 0

1 3

3 2

2 272 35 2b.1.1.27 Reactor Building Equipment Drains 34 64 3

2 5

11 37 155 155 239 115 19,131 1,707 2b.1.1.28 Reactor Core Isolation Cooling 95 198 12 10 12 54 115 496 496 625 510 71,097 4,693 2b.1.1.29 Reactor Recirculation 113 13 14 24 67 52 282 282 1,243 631 107,158 2,142 2b.1.1.30 Reactor Water Clean-up 401 744 29 22 20 123 426 1,766 1,766 1,062 1,159 146,989 20,103 2b.1.1.31 Residual Heat Removal 1,395 1,470 260 236 337 1,195 1,476 6,368 6,368 17,633 11,296 1,729,020 33,311 2b.1.1.32 Service Air - RCA 325 3

6 37 88 459 459 1,953 79,314 5,520 2b.1.1.33 Service Water 82 12 95 95 1,595 2b.1.1.34 Service Water - RCA 749 24 44 271 237 1,325 1,325 14,208 577,006 12,979 2b.1.1.35 Standby Liquid Control 42 0

1 6

12 60 60 291 11,832 702 2b.1.1 Totals 1,925 16,926 918 985 2,879 3,419 6,617 33,669 32,480 1,189 150,849 32,919 9,023,378 316,914 2b.1.2 Scaffolding in support of decommissioning 3,402 53 12 60 19 871 4,418 4,418 2,816 175 142,471 70,548 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 18 of 23 Table C-2 LaSalle County Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Decontamination of Site Buildings 2b.1.3.1 Reactor Building 2,626 2,688 105 121 221 262 2,113 8,138 8,138 11,604 4,679 931,913 94,524 2b.1.3.2 Auxiliary Building 1,397 645 52 63 275 91 938 3,460 3,460 14,385 1,321 712,143 36,118 2b.1.3.3 IRSF Building 78 34 6

7 1

18 54 199 199 26 348 35,816 1,985 2b.1.3.4 Service Building 108 41 9

10 1

26 73 267 267 34 485 49,855 2,631 2b.1.3.5 Solid Radwaste Building 477 377 22 25 19 61 356 1,336 1,336 984 1,120 151,467 15,211 2b.1.3.6 Turbine Building 1,734 1,005 142 160 98 401 1,271 4,811 4,811 5,149 7,470 950,042 48,144 2b.1.3 Totals 6,420 4,791 336 386 614 859 4,806 18,212 18,212 32,181 15,423 2,831,236 198,613 2b.1 Subtotal Period 2b Activity Costs 8,345 25,120 1,307 1,383 3,553 4,296 12,294 56,299 55,110 1,189 185,847 48,517 11,997,080 586,075 Period 2b Additional Costs 2b.2.1 Soil Remediation 29 1

216 706 216 1,168 1,168 13,453 1,119,288 367 2b.2 Subtotal Period 2b Additional Costs 29 1

216 706 216 1,168 1,168 13,453 1,119,288 367 Period 2b Collateral Costs 2b.3.1 Process liquid waste 182 328 1,627 2,584 1,014 5,735 5,735 5,561 556,934 1,084 2b.3.2 Small tool allowance 480 72 553 553 2b.3.3 Spent Fuel Capital and Transfer 5,000 750 5,750 5,750 2b.3 Subtotal Period 2b Collateral Costs 182 480 328 1,627 2,584 5,000 1,836 12,037 6,287 5,750 5,561 556,934 1,084 Period 2b Period-Dependent Costs 2b.4.1 Decon supplies 1,657 414 2,071 2,071 2b.4.2 Insurance 896 90 986 986 2b.4.3 Property taxes 1,062 106 1,169 1,169 2b.4.4 Health physics supplies 3,008 752 3,760 3,760 2b.4.5 Heavy equipment rental 3,520 528 4,048 4,048 2b.4.6 Disposal of DAW generated 27 10 544 140 721 721 9,748 194,954 45 2b.4.7 Plant energy budget 2,186 328 2,514 2,514 2b.4.8 NRC Fees 958 96 1,054 1,054 2b.4.9 Emergency Planning Fees 212 21 234 234 2b.4.10 Site O&M Costs 266 40 305 305 2b.4.11 Spent Fuel Pool O&M 1,621 243 1,864 1,864 2b.4.12 Liquid Radwaste Processing Equipment/Services 407 61 468 468 2b.4.13 ISFSI Operating Costs 93 14 107 107 2b.4.14 Security Staff Cost 11,251 1,688 12,938 12,938 280,469 2b.4.15 DOC Staff Cost 26,230 3,935 30,165 30,165 323,703 2b.4.16 Utility Staff Cost 45,020 6,753 51,773 51,773 600,846 2b.4 Subtotal Period 2b Period-Dependent Costs 1,657 6,527 27 10 544 90,203 15,208 114,177 111,971 2,205 9,748 194,954 45 1,205,017 2b.0 TOTAL PERIOD 2b COST 10,184 32,157 1,663 3,236 3,553 8,130 95,203 29,555 183,681 174,537 7,955 1,189 185,847 77,279 13,868,260 587,571 1,205,017 PERIOD 2c - Decontamination Following Wet Fuel Storage Period 2c Direct Decommissioning Activities 2c.1.1 Remove spent fuel racks 918 82 166 157 1,030 777 3,130 3,130 9,726 872,665 1,631 Disposal of Plant Systems 2c.1.2.1 Containment Monitoring 23 0

0 1

1 6

33 33 58 12 3,416 455 2c.1.2.2 Electrical - Contaminated 830 12 20 108 16 232 1,219 1,219 5,678 151 244,161 14,760 2c.1.2.3 Fire Protection - RCA 1,033 22 39 244 303 1,641 1,641 12,787 519,289 17,581 2c.1.2.4 Fuel Pool Cooling & Cleanup 777 47 56 190 168 278 1,517 1,517 9,938 1,594 546,102 14,131 2c.1.2.5 HVAC-Primary Containment 887 30 43 191 77 279 1,508 1,508 10,027 732 472,374 15,669 2c.1.2.6 Reactor Bldg Closed Cooling Water 355 44 51 177 151 165 943 943 9,277 1,424 504,377 6,243 2c.1.2.7 Reactor Building Floor Drains 0

7 0

0 0

1 2

10 10 8

7 951 123 2c.1.2.8 Well Water 91 14 104 104 1,732 2c.1.2 Totals 0

4,003 157 210 912 414 1,279 6,975 6,870 104 47,773 3,920 2,290,669 70,694 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 19 of 23 Table C-2 LaSalle County Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Decontamination of Site Buildings 2c.1.3.1 Reactor Building Spent Fuel Pool 265 973 254 262 16 1,201 743 3,714 3,714 842 14,610 1,412,321 20,548 2c.1.3 Totals 265 973 254 262 16 1,201 743 3,714 3,714 842 14,610 1,412,321 20,548 2c.1.4 Scaffolding in support of decommissioning 680 11 2

12 4

174 884 884 563 35 28,494 14,110 2c.1 Subtotal Period 2c Activity Costs 1,183 5,739 588 631 940 2,648 2,974 14,702 14,598 104 49,179 28,292 4,604,149 106,983 Period 2c Additional Costs 2c.2.1 License Termination Survey Planning 940 282 1,222 1,222 6,240 2c.2 Subtotal Period 2c Additional Costs 940 282 1,222 1,222 6,240 Period 2c Collateral Costs 2c.3.1 Process liquid waste 138 56 267 263 180 904 904 945 56,700 184 2c.3.2 Small tool allowance 100 15 115 115 2c.3.3 Decommissioning Equipment Disposition 114 31 127 40 45 356 356 6,000 373 303,507 88 2c.3 Subtotal Period 2c Collateral Costs 138 100 169 298 127 303 240 1,375 1,375 6,000 1,318 360,207 272 Period 2c Period-Dependent Costs 2c.4.1 Decon supplies 47 12 59 59 2c.4.2 Insurance 215 21 236 236 2c.4.3 Property taxes 255 25 280 280 2c.4.4 Health physics supplies 577 144 722 722 2c.4.5 Heavy equipment rental 844 127 970 970 2c.4.6 Disposal of DAW generated 9

3 182 47 242 242 3,268 65,363 15 2c.4.7 Plant energy budget 279 42 321 321 2c.4.8 NRC Fees 230 23 253 253 2c.4.9 Emergency Planning Fees 51 5

56 56 2c.4.10 Site O&M Costs 64 10 73 73 2c.4.11 Liquid Radwaste Processing Equipment/Services 195 29 224 224 2c.4.12 ISFSI Operating Costs 22 3

26 26 2c.4.13 Security Staff Cost 1,507 226 1,733 1,733 35,340 2c.4.14 DOC Staff Cost 4,344 652 4,995 4,995 53,143 2c.4.15 Utility Staff Cost 7,939 1,191 9,130 9,130 101,503 2c.4 Subtotal Period 2c Period-Dependent Costs 47 1,421 9

3 182 15,101 2,557 19,321 19,240 82 3,268 65,363 15 189,986 2c.0 TOTAL PERIOD 2c COST 1,368 7,260 766 933 1,067 3,133 16,041 6,053 36,621 36,435 82 104 55,179 32,878 5,029,720 107,271 196,226 PERIOD 2e - License Termination Period 2e Direct Decommissioning Activities 2e.1.1 ORISE confirmatory survey 151 45 197 197 2e.1.2 Terminate license a

2e.1 Subtotal Period 2e Activity Costs 151 45 197 197 Period 2e Additional Costs 2e.2.1 License Termination Survey 11,748 3,524 15,272 15,272 217,865 3,120 2e.2 Subtotal Period 2e Additional Costs 11,748 3,524 15,272 15,272 217,865 3,120 Period 2e Collateral Costs 2e.3.1 DOC staff relocation expenses 1,130 169 1,299 1,299 2e.3.2 Spent Fuel Capital and Transfer 1,500 225 1,725 1,725 2e.3 Subtotal Period 2e Collateral Costs 2,630 394 3,024 1,299 1,725 Period 2e Period-Dependent Costs 2e.4.1 Insurance 299 30 329 329 2e.4.2 Property taxes 382 38 420 420 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 20 of 23 Table C-2 LaSalle County Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 2e Period-Dependent Costs (continued) 2e.4.3 Health physics supplies 1,038 259 1,297 1,297 2e.4.4 Disposal of DAW generated 1

0 19 5

25 25 342 6,832 2

2e.4.5 Plant energy budget 210 31 241 241 2e.4.6 NRC Fees 360 36 396 396 2e.4.7 Emergency Planning Fees 76 8

84 84 2e.4.8 Site O&M Costs 95 14 110 110 2e.4.9 ISFSI Operating Costs 34 5

39 39 2e.4.10 Security Staff Cost 1,197 180 1,377 1,377 28,299 2e.4.11 DOC Staff Cost 3,856 578 4,434 4,434 47,430 2e.4.12 Utility Staff Cost 4,865 730 5,594 5,594 60,981 2e.4 Subtotal Period 2e Period-Dependent Costs 1,038 1

0 19 11,374 1,915 14,347 14,224 123 342 6,832 2

136,710 2e.0 TOTAL PERIOD 2e COST 1,038 1

0 19 25,903 5,879 32,840 30,993 1,848 342 6,832 217,867 139,830 PERIOD 2 TOTALS 13,419 73,876 16,891 10,623 12,019 45,286 249,251 91,452 512,817 469,203 40,587 3,027 606,319 179,680 4,315 1,435 40,794,070 1,360,677 2,646,827 PERIOD 3b - Site Restoration Period 3b Direct Decommissioning Activities Demolition of Remaining Site Buildings 3b.1.1.1 Reactor Building 5,667 850 6,518 6,518 64,458 3b.1.1.2 Auxiliary Building 3,686 553 4,239 4,239 42,962 3b.1.1.3 Capital Improvements 2009 1,314 197 1,511 1,511 20,778 3b.1.1.4 Chemical Feed Building 32 5

36 36 482 3b.1.1.5 Diesel Generator Room 468 70 538 538 6,000 3b.1.1.6 Discharge Structure 20 3

23 23 190 3b.1.1.7 IRSF Building 691 104 794 794 8,924 3b.1.1.8 ISFSI Haul Path 651 98 748 748 9,520 3b.1.1.9 Lake Screen House 1,102 165 1,267 1,267 13,877 3b.1.1.10 Main Access Facility 390 58 448 448 5,396 3b.1.1.11 Miscellaneous Yard Structures 1,946 292 2,238 2,238 27,034 3b.1.1.12 New Service Building 1,840 276 2,116 2,116 23,587 3b.1.1.13 Outfall Structure 8

1 9

9 113 3b.1.1.14 River Screen House 330 50 380 380 4,230 3b.1.1.15 Security Modifications 677 102 778 778 3,834 3b.1.1.16 Service Building 1,534 230 1,764 1,764 21,582 3b.1.1.17 Sewage Treatment Plant 36 5

41 41 591 3b.1.1.18 Sewage Treatment Plant Upgrades 263 39 302 302 3,306 3b.1.1.19 Solid Radwaste Building 2,029 304 2,333 2,333 23,167 3b.1.1.20 Training Center 1,222 183 1,406 1,406 16,863 3b.1.1.21 Turbine Building 5,501 825 6,326 6,326 68,584 3b.1.1.22 Turbine Pedestal 2,102 315 2,418 2,418 22,592 3b.1.1.23 Wastewater Treatment Plant 59 9

68 68 911 3b.1.1 Totals 31,566 4,735 36,300 748 35,552 388,980 Site Closeout Activities 3b.1.2 BackFill Site 522 78 600 600 1,485 3b.1.3 Grade & landscape site 149 22 171 171 499 3b.1.4 Final report to NRC 77 12 89 89 654 3b.1 Subtotal Period 3b Activity Costs 32,236 77 4,847 37,160 89 748 36,323 390,964 654 Period 3b Additional Costs 3b.2.1 Concrete Crushing 1,155 5

174 1,333 1,333 5,855 3b.2.2 Cofferdam Construction and Teardown 389 58 447 447 3,896 3b.2 Subtotal Period 3b Additional Costs 1,543 5

232 1,780 1,780 9,751 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 21 of 23 Table C-2 LaSalle County Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 3b Collateral Costs 3b.3.1 Small tool allowance 341 51 392 392 3b.3.2 Spent Fuel Capital and Transfer 3,000 450 3,450 3,450 3b.3 Subtotal Period 3b Collateral Costs 341 3,000 501 3,842 3,450 392 Period 3b Period-Dependent Costs 3b.4.1 Insurance 782 78 860 860 3b.4.2 Property taxes 998 100 1,098 1,098 3b.4.3 Heavy equipment rental 4,728 709 5,437 5,437 3b.4.4 Plant energy budget 274 41 315 63 252 3b.4.5 NRC ISFSI Fees 372 37 409 409 3b.4.6 Emergency Planning Fees 200 20 220 220 3b.4.7 ISFSI Operating Costs 88 13 101 101 3b.4.8 Site O&M Cost 249 37 287 287 3b.4.9 Security Staff Cost 2,993 449 3,442 (0) 2,822 619 70,317 3b.4.10 DOC Staff Cost 9,384 1,408 10,792 10,792 110,391 3b.4.11 Utility Staff Cost 5,667 850 6,516 (0) 1,238 5,278 70,317 3b.4 Subtotal Period 3b Period-Dependent Costs 4,728 21,006 3,743 29,476 (0) 6,811 22,666 251,026 3b.0 TOTAL PERIOD 3b COST 38,848 24,088 9,323 72,259 89 11,009 61,161 400,715 251,680 PERIOD 3c - Fuel Storage Operations/Shipping Period 3c Direct Decommissioning Activities Period 3c Collateral Costs 3c.3.1 Spent Fuel Capital and Transfer 4,500 675 5,175 5,175 3c.3 Subtotal Period 3c Collateral Costs 4,500 675 5,175 5,175 Period 3c Period-Dependent Costs 3c.4.1 Insurance 1,248 125 1,373 1,373 3c.4.2 Property taxes 1,593 159 1,753 1,753 3c.4.3 Plant energy budget 3c.4.4 NRC ISFSI Fees 594 59 654 654 3c.4.5 Emergency Planning Fees 319 32 351 351 3c.4.6 ISFSI Operating Costs 140 21 161 161 3c.4.7 Security Staff Cost 3,941 591 4,532 4,532 89,794 3c.4.8 Utility Staff Cost 1,723 258 1,981 1,981 22,482 3c.4 Subtotal Period 3c Period-Dependent Costs 9,559 1,246 10,805 10,805 112,276 3c.0 TOTAL PERIOD 3c COST 14,059 1,921 15,980 15,980 112,276 PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d.1.1.1 Vessel & Internals GTCC Disposal 500 11,118 1,718 13,336 13,336 671 109,910 3d.1.1 Totals 500 11,118 1,718 13,336 13,336 671 109,910 3d.1 Subtotal Period 3d Activity Costs 500 11,118 1,718 13,336 13,336 671 109,910 Period 3d Period-Dependent Costs 3d.4.1 Insurance 32 3

35 35 3d.4.2 Property taxes 41 4

45 45 3d.4.3 Plant energy budget 3d.4.4 NRC ISFSI Fees 15 2

17 17 3d.4.5 Emergency Planning Fees 8

1 9

9 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 22 of 23 Table C-2 LaSalle County Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 3d Period-Dependent Costs (continued) 3d.4.6 ISFSI Operating Costs 4

1 4

4 3d.4.7 Security Staff Cost 102 15 117 117 2,314 3d.4.8 Utility Staff Cost 44 7

51 51 579 3d.4 Subtotal Period 3d Period-Dependent Costs 246 32 278 278 2,894 3d.0 TOTAL PERIOD 3d COST 500 11,118 246 1,750 13,614 13,336 278 671 109,910 2,894 PERIOD 3e - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 3e Additional Costs 3e.2.1 ISFSI License Termination 57 1

38 153 749 169 1,167 1,167 2,905 244,104 3,498 1,280 3e.2 Subtotal Period 3e Additional Costs 57 1

38 153 749 169 1,167 1,167 2,905 244,104 3,498 1,280 Period 3e Collateral Costs 3e.3.1 Small tool allowance 1

0 1

1 3e.3 Subtotal Period 3e Collateral Costs 1

0 1

1 Period 3e Period-Dependent Costs 3e.4.1 Insurance 128 13 140 140 3e.4.2 Property taxes 163 16 179 179 3e.4.3 Heavy equipment rental 209 31 241 241 3e.4.4 Plant energy budget 3e.4.5 Security Staff Cost 106 16 122 122 2,468 3e.4.6 Utility Staff Cost 147 22 169 169 1,870 3e.4 Subtotal Period 3e Period-Dependent Costs 209 544 98 851 851 4,338 3e.0 TOTAL PERIOD 3e COST 267 1

38 153 1,292 267 2,018 2,018 2,905 244,104 3,498 5,618 PERIOD 3f - ISFSI Site Restoration Period 3f Direct Decommissioning Activities Period 3f Additional Costs 3f.2.1 ISFSI Demolition and Site Restoration 1,604 24 244 1,872 1,872 21,545 80 3f.2 Subtotal Period 3f Additional Costs 1,604 24 244 1,872 1,872 21,545 80 Period 3f Collateral Costs 3f.3.1 Small tool allowance 18 3

21 21 3f.3 Subtotal Period 3f Collateral Costs 18 3

21 21 Period 3f Period-Dependent Costs 3f.4.1 Insurance 3f.4.2 Property taxes 86 9

95 95 3f.4.3 Heavy equipment rental 86 13 98 98 3f.4.4 Plant energy budget 3f.4.5 Security Staff Cost 56 8

64 64 1,307 3f.4.6 Utility Staff Cost 64 10 73 73 810 3f.4 Subtotal Period 3f Period-Dependent Costs 86 206 39 331 331 2,117 3f.0 TOTAL PERIOD 3f COST 1,708 230 286 2,224 2,224 21,545 2,197 PERIOD 3 TOTALS 40,823 501 38 11,271 39,915 13,547 106,095 13,424 31,510 61,161 2,905 671 354,014 425,758 374,665 TOTAL COST TO DECOMMISSION 16,275 116,974 17,466 11,017 12,019 60,210 393,642 122,862 750,464 573,472 112,415 64,578 606,319 183,727 5,274 1,435 671 41,287,520 1,800,199 3,658,324 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix C, Page 23 of 23 Table C-2 LaSalle County Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Fri, May 29, 2009 at 13:37:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours TOTAL COST TO DECOMMISSION WITH 19.58% CONTINGENCY:

$750,464 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 76.42% OR:

$573,472 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 14.98% OR:

$112,415 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 8.61% OR:

$64,578 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

190,436 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED 671 cubic feet TOTAL SCRAP METAL REMOVED:

67,806 tons TOTAL CRAFT LABOR REQUIREMENTS:

1,800,199 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.

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Appendix D, Page 1 of 23 TLG Services, Inc.

APPENDIX D DETAILED COST ANALYSIS DELAYED DECON Page LaSalle County Station, Unit 1.....................................................................................D-2 LaSalle County Station, Unit 2..................................................................................D-13

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 2 of 23 Table D-1 LaSalle County Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:23 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs 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 Activities 1a.1.1 SAFSTOR site characterization survey 398 119 517 517 1a.1.2 Prepare preliminary decommissioning cost 153 23 176 176 1,300 1a.1.3 Notification of Cessation of Operations a

1a.1.4 Remove fuel & source material n/a 1a.1.5 Notification of Permanent Defueling a

1a.1.6 Deactivate plant systems & process waste a

1a.1.7 Prepare and submit PSDAR 236 35 271 271 2,000 1a.1.8 Review plant dwgs & specs.

153 23 176 176 1,300 1a.1.9 Perform detailed rad survey a

1a.1.10 Estimate by-product inventory 118 18 136 136 1,000 1a.1.11 End product description 118 18 136 136 1,000 1a.1.12 Detailed by-product inventory 177 27 204 204 1,500 1a.1.13 Define major work sequence 118 18 136 136 1,000 1a.1.14 Perform SER and EA 366 55 421 421 3,100 1a.1.15 Perform Site-Specific Cost Study 590 89 679 679 5,000 Activity Specifications 1a.1.16.1 Prepare plant and facilities for SAFSTOR 581 87 668 668 4,920 1a.1.16.2 Plant systems 492 74 565 565 4,167 1a.1.16.3 Plant structures and buildings 368 55 423 423 3,120 1a.1.16.4 Waste management 236 35 271 271 2,000 1a.1.16.5 Facility and site dormancy 236 35 271 271 2,000 1a.1.16 Total 1,913 287 2,199 2,199 16,207 Detailed Work Procedures 1a.1.17.1 Plant systems 140 21 161 161 1,183 1a.1.17.2 Facility closeout & dormancy 142 21 163 163 1,200 1a.1.17 Total 281 42 323 323 2,383 1a.1.18 Procure vacuum drying system 12 2

14 14 100 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 4,633 755 5,388 5,388 35,890 Period 1a Period-Dependent Costs 1a.4.1 Insurance 876 88 964 964 1a.4.2 Property taxes 1a.4.3 Health physics supplies 396 99 495 495 1a.4.4 Heavy equipment rental 396 59 455 455 1a.4.5 Disposal of DAW generated 2

1 34 9

45 45 610 12,190 3

1a.4.6 Plant energy budget 1,371 206 1,577 1,577 1a.4.7 NRC Fees 706 71 776 776 1a.4.8 Emergency Planning Fees 313 31 344 344 1a.4.9 Site O&M Costs 125 19 144 144 1a.4.10 Spent Fuel Pool O&M 762 114 877 877 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 446 67 512 512 12,264 1a.4.13 Utility Staff Cost 31,082 4,662 35,745 35,745 423,400 1a.4 Subtotal Period 1a Period-Dependent Costs 792 2

1 34 35,725 5,431 41,984 40,713 1,271 610 12,190 3

435,664 1a.0 TOTAL PERIOD 1a COST 792 2

1 34 40,358 6,186 47,372 46,101 1,271 610 12,190 3

471,554 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 3 of 23 Table D-1 LaSalle County Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:23 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours PERIOD 1b - SAFSTOR Limited DECON Activities Period 1b Direct Decommissioning Activities Decontamination of Site Buildings 1b.1.1.1 Reactor Building 2,820 1,410 4,230 4,230 49,197 1b.1.1.2 Auxiliary Building 311 155 466 466 5,731 1b.1.1.3 Off Gas Building 139 69 208 208 2,566 1b.1.1.4 Turbine Building 1,631 816 2,447 2,447 30,081 1b.1.1 Totals 4,901 2,450 7,351 7,351 87,576 1b.1 Subtotal Period 1b Activity Costs 4,901 2,450 7,351 7,351 87,576 Period 1b Collateral Costs 1b.3.1 Decon equipment 763 114 877 877 1b.3.2 Process liquid waste 167 67 322 317 218 1,090 1,090 1,137 68,232 222 1b.3.3 Small tool allowance 75 11 86 86 1b.3 Subtotal Period 1b Collateral Costs 930 75 67 322 317 343 2,053 2,053 1,137 68,232 222 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 1,260 315 1,576 1,576 1b.4.2 Insurance 105 11 116 116 1b.4.3 Property taxes 1,155 116 1,271 1,271 1b.4.4 Health physics supplies 421 105 527 527 1b.4.5 Heavy equipment rental 99 15 113 113 1b.4.6 Disposal of DAW generated 2

1 48 12 63 63 857 17,148 4

1b.4.7 Plant energy budget 342 51 393 393 1b.4.8 NRC Fees 176 18 194 194 1b.4.9 Emergency Planning Fees 78 8

86 86 1b.4.10 Site O&M Costs 31 5

36 36 1b.4.11 Spent Fuel Pool O&M 190 29 219 219 1b.4.12 ISFSI Operating Costs 11 2

13 13 1b.4.13 Security Staff Cost 111 17 128 128 3,058 1b.4.14 Utility Staff Cost 7,749 1,162 8,912 8,912 105,560 1b.4 Subtotal Period 1b Period-Dependent Costs 1,260 520 2

1 48 9,948 1,864 13,644 13,327 317 857 17,148 4

108,618 1b.0 TOTAL PERIOD 1b COST 7,091 595 69 322 364 9,948 4,658 23,048 22,731 317 1,995 85,381 87,801 108,618 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 432 65 496 496 3,000 1c.1.2 Install containment pressure equal. lines 42 6

48 48 700 1c.1.3 Interim survey prior to dormancy 733 220 953 953 13,416 1c.1.4 Secure building accesses a

1c.1.5 Prepare & submit interim report 69 10 79 79 583 1c.1 Subtotal Period 1c Activity Costs 473 802 301 1,576 1,576 17,116 583 Period 1c Additional Costs 1c.2.1 Spent Fuel Pool Isolation 9,690 1,453 11,143 11,143 1c.2 Subtotal Period 1c Additional Costs 9,690 1,453 11,143 11,143 Period 1c Collateral Costs 1c.3.1 Process liquid waste 158 64 305 300 206 1,033 1,033 1,078 64,659 210 1c.3.2 Small tool allowance 4

1 4

4 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 4 of 23 Table D-1 LaSalle County Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:23 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours 1c.3 Subtotal Period 1c Collateral Costs 158 4

64 305 300 207 1,037 1,037 1,078 64,659 210 Period 1c Period-Dependent Costs 1c.4.1 Insurance 105 11 116 116 1c.4.2 Property taxes 1,155 116 1,271 1,271 1c.4.3 Health physics supplies 139 35 173 173 1c.4.4 Heavy equipment rental 99 15 113 113 1c.4.5 Disposal of DAW generated 0

0 6

2 8

8 107 2,132 0

1c.4.6 Plant energy budget 342 51 393 393 1c.4.7 NRC Fees 176 18 194 194 1c.4.8 Emergency Planning Fees 78 8

86 86 1c.4.9 Site O&M Costs 31 5

36 36 1c.4.10 Spent Fuel Pool O&M 190 29 219 219 1c.4.11 ISFSI Operating Costs 11 2

13 13 1c.4.12 Security Staff Cost 111 17 128 128 3,058 1c.4.13 Utility Staff Cost 2,147 322 2,468 2,468 27,040 1c.4 Subtotal Period 1c Period-Dependent Costs 237 0

0 6

4,346 627 5,216 4,900 317 107 2,132 0

30,098 1c.0 TOTAL PERIOD 1c COST 158 714 64 305 306 14,837 2,589 18,973 18,656 317 1,184 66,791 17,326 30,681 PERIOD 1 TOTALS 7,249 2,101 135 628 704 65,144 13,432 89,392 87,487 1,905 3,788 164,362 105,130 610,852 PERIOD 2a - SAFSTOR Dormancy with Wet Spent Fuel Storage Period 2a Direct Decommissioning Activities 2a.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 264 40 304 304 2a.1.5 Maintenance supplies 980 245 1,225 1,225 2a.1 Subtotal Period 2a Activity Costs 1,244 285 1,529 1,529 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 13,000 1,950 14,950 14,950 2a.3 Subtotal Period 2a Collateral Costs 13,000 1,950 14,950 14,950 Period 2a Period-Dependent Costs 2a.4.1 Insurance 3,286 329 3,615 3,615 2a.4.2 Property taxes 10,936 1,094 12,029 12,029 2a.4.3 Health physics supplies 596 149 744 744 2a.4.4 Disposal of DAW generated 8

3 167 43 221 221 2,985 59,702 14 2a.4.5 Plant energy budget 2,138 321 2,459 2,459 2a.4.6 NRC Fees 1,571 157 1,728 1,728 2a.4.7 Emergency Planning Fees 779 78 857 857 2a.4.8 Site O&M Costs 974 146 1,120 1,120 2a.4.9 Spent Fuel Pool O&M 5,944 892 6,836 6,836 2a.4.10 ISFSI Operating Costs 343 51 394 394 2a.4.11 Security Staff Cost 13,456 2,018 15,474 15,474 340,544 2a.4.12 Utility Staff Cost 18,769 2,815 21,585 21,585 240,853 2a.4 Subtotal Period 2a Period-Dependent Costs 596 8

3 167 58,196 8,093 67,062 2,694 64,368 2,985 59,702 14 581,397 2a.0 TOTAL PERIOD 2a COST 596 8

3 167 72,440 10,327 83,541 4,222 79,318 2,985 59,702 14 581,397 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 5 of 23 Table D-1 LaSalle County Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:23 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours PERIOD 2b - SAFSTOR Dormancy with Dry Spent Fuel Storage Period 2b Direct Decommissioning Activities 2b.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 108 16 124 124 2b.1.5 Maintenance supplies 399 100 499 499 2b.1 Subtotal Period 2b Activity Costs 507 116 623 623 Period 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 2,250 338 2,588 2,588 2b.3 Subtotal Period 2b Collateral Costs 2,250 338 2,588 2,588 Period 2b Period-Dependent Costs 2b.4.1 Insurance 1,339 134 1,473 1,473 2b.4.2 Property taxes 1,588 159 1,747 1,747 2b.4.3 Health physics supplies 221 55 276 276 2b.4.4 Disposal of DAW generated 3

1 66 17 87 87 1,175 23,506 5

2b.4.5 Plant energy budget 436 65 501 501 2b.4.6 NRC Fees 640 64 704 704 2b.4.7 Emergency Planning Fees 318 32 349 349 2b.4.8 Site O&M Costs 397 60 457 457 2b.4.9 ISFSI Operating Costs 140 21 161 161 2b.4.10 Security Staff Cost 7

1 9

9 2b.4.11 Utility Staff Cost 1,732 260 1,992 1,992 26,514 2b.4 Subtotal Period 2b Period-Dependent Costs 221 3

1 66 6,597 867 7,756 1,068 6,688 1,175 23,506 5

26,514 2b.0 TOTAL PERIOD 2b COST 221 3

1 66 9,354 1,321 10,966 1,691 9,275 1,175 23,506 5

26,514 PERIOD 2 TOTALS 817 11 4

232 81,794 11,648 94,507 5,913 88,594 4,160 83,208 19 607,911 PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy Period 3a Direct Decommissioning Activities 3a.1.1 Prepare preliminary decommissioning cost 153 23 176 176 1,300 3a.1.2 Review plant dwgs & specs.

543 81 624 624 4,600 3a.1.3 Perform detailed rad survey a

3a.1.4 End product description 118 18 136 136 1,000 3a.1.5 Detailed by-product inventory 153 23 176 176 1,300 3a.1.6 Define major work sequence 885 133 1,018 1,018 7,500 3a.1.7 Perform SER and EA 366 55 421 421 3,100 3a.1.8 Perform Site-Specific Cost Study 590 89 679 679 5,000 3a.1.9 Prepare/submit License Termination Plan 483 73 556 556 4,096 3a.1.10 Receive NRC approval of termination plan a

Activity Specifications 3a.1.11.1 Re-activate plant & temporary facilities 870 130 1,000 900 100 7,370 3a.1.11.2 Plant systems 492 74 565 509 57 4,167 3a.1.11.3 Reactor internals 838 126 964 964 7,100 3a.1.11.4 Reactor vessel 767 115 882 882 6,500 3a.1.11.5 Sacrificial shield 59 9

68 68 500 3a.1.11.6 Moisture separators/reheaters 118 18 136 136 1,000 3a.1.11.7 Reinforced concrete 189 28 217 109 109 1,600 3a.1.11.8 Main Turbine 246 37 283 283 2,088 3a.1.11.9 Main Condensers 246 37 283 283 2,088 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 6 of 23 Table D-1 LaSalle County Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:23 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Activity Specifications (continued) 3a.1.11.10 Pressure suppression structure 236 35 271 271 2,000 3a.1.11.11 Drywell 189 28 217 217 1,600 3a.1.11.12 Plant structures & buildings 368 55 423 212 212 3,120 3a.1.11.13 Waste management 543 81 624 624 4,600 3a.1.11.14 Facility & site closeout 106 16 122 61 61 900 3a.1.11 Total 5,267 790 6,057 5,519 538 44,633 Planning & Site Preparations 3a.1.12 Prepare dismantling sequence 283 42 326 326 2,400 3a.1.13 Plant prep. & temp. svces 2,800 420 3,220 3,220 3a.1.14 Design water clean-up system 165 25 190 190 1,400 3a.1.15 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,200 330 2,530 2,530 3a.1.16 Procure casks/liners & containers 145 22 167 167 1,230 3a.1 Subtotal Period 3a Activity Costs 14,153 2,123 16,276 15,738 538 77,559 Period 3a Collateral Costs 3a.3.1 Spent Fuel Capital and Transfer 1,500 225 1,725 1,725 3a.3 Subtotal Period 3a Collateral Costs 1,500 225 1,725 1,725 Period 3a Period-Dependent Costs 3a.4.1 Insurance 421 42 464 464 3a.4.2 Property taxes 500 50 550 550 3a.4.3 Health physics supplies 347 87 434 434 3a.4.4 Heavy equipment rental 396 59 455 455 3a.4.5 Disposal of DAW generated 1

1 29 7

38 38 516 10,311 2

3a.4.6 Plant energy budget 1,371 206 1,577 1,577 3a.4.7 NRC Fees 249 25 274 274 3a.4.8 Emergency Planning Fees 100 10 110 110 3a.4.9 Site O&M Costs 125 19 144 144 3a.4.10 Security Staff Cost 2,882 432 3,315 3,315 69,350 3a.4.11 Utility Staff Cost 19,481 2,922 22,403 22,403 260,714 3a.4 Subtotal Period 3a Period-Dependent Costs 743 1

1 29 25,129 3,859 29,762 29,652 110 516 10,311 2

330,064 3a.0 TOTAL PERIOD 3a COST 743 1

1 29 40,782 6,207 47,763 45,390 1,835 538 516 10,311 2

407,623 PERIOD 3b - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 559 84 642 578 64 4,733 3b.1.1.2 Reactor internals 472 71 543 543 4,000 3b.1.1.3 Remaining buildings 159 24 183 46 137 1,350 3b.1.1.4 CRD housings & NIs 118 18 136 136 1,000 3b.1.1.5 Incore instrumentation 118 18 136 136 1,000 3b.1.1.6 Removal primary containment 236 35 271 271 2,000 3b.1.1.7 Reactor vessel 428 64 493 493 3,630 3b.1.1.8 Facility closeout 142 21 163 81 81 1,200 3b.1.1.9 Sacrificial shield 142 21 163 163 1,200 3b.1.1.10 Reinforced concrete 118 18 136 68 68 1,000 3b.1.1.11 Main Turbine 245 37 282 282 2,080 3b.1.1.12 Main Condensers 246 37 283 283 2,088 3b.1.1.13 Moisture separators & reheaters 236 35 271 271 2,000 3b.1.1.14 Radwaste building 322 48 370 333 37 2,730 3b.1.1.15 Reactor building 322 48 370 333 37 2,730 3b.1.1 Total 3,864 580 4,443 4,018 425 32,741 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 7 of 23 Table D-1 LaSalle County Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:23 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours 3b.1 Subtotal Period 3b Activity Costs 3,864 580 4,443 4,018 425 32,741 Period 3b Additional Costs 3b.2.1 Site Characterization 6,086 1,826 7,912 7,912 29,730 10,672 3b.2 Subtotal Period 3b Additional Costs 6,086 1,826 7,912 7,912 29,730 10,672 Period 3b Collateral Costs 3b.3.1 Decon equipment 763 114 877 877 3b.3.2 DOC staff relocation expenses 1,130 169 1,299 1,299 3b.3.3 Pipe cutting equipment 1,100 165 1,265 1,265 3b.3.4 Spent Fuel Capital and Transfer 750 113 863 863 3b.3 Subtotal Period 3b Collateral Costs 763 1,100 1,880 561 4,304 3,442 863 Period 3b Period-Dependent Costs 3b.4.1 Decon supplies 23 6

29 29 3b.4.2 Insurance 211 21 232 232 3b.4.3 Property taxes 251 25 276 276 3b.4.4 Health physics supplies 192 48 240 240 3b.4.5 Heavy equipment rental 198 30 228 228 3b.4.6 Disposal of DAW generated 1

0 16 4

22 22 292 5,846 1

3b.4.7 Plant energy budget 687 103 790 790 3b.4.8 NRC Fees 125 12 137 137 3b.4.9 Emergency Planning Fees 50 5

55 55 3b.4.10 Site O&M Costs 63 9

72 72 3b.4.11 Security Staff Cost 1,445 217 1,662 1,662 34,770 3b.4.12 DOC Staff Cost 4,781 717 5,498 5,498 58,560 3b.4.13 Utility Staff Cost 9,767 1,465 11,232 11,232 130,714 3b.4 Subtotal Period 3b Period-Dependent Costs 23 390 1

0 16 17,380 2,663 20,474 20,419 55 292 5,846 1

224,044 3b.0 TOTAL PERIOD 3b COST 786 1,490 1

0 16 29,210 5,630 37,133 35,790 918 425 292 5,846 29,731 267,457 PERIOD 3 TOTALS 786 2,233 2

1 45 69,992 11,837 84,896 81,180 2,753 963 808 16,157 29,734 675,080 PERIOD 4a - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Recirculation System Piping & Valves 21 77 18 16 198 84 414 414 1,006 121,649 1,846 4a.1.1.2 Recirculation Pumps & Motors 11 43 14 28 9

313 102 520 520 238 2,356 211,420 1,136 4a.1.1.3 CRDMs & NIs Removal 48 177 492 88 166 172 1,143 1,143 5,536 141,063 4,118 4a.1.1.4 Reactor Vessel Internals 171 2,440 4,993 1,437 10,200 283 8,666 28,190 28,190 2,128 1,753 631 454,265 33,492 1,472 4a.1.1.5 Vessel & Internals GTCC Disposal 11,118 1,668 12,786 12,786 671 109,910 4a.1.1.6 Reactor Vessel 103 4,760 2,019 1,075 4,152 283 6,514 18,907 18,907 13,945 2,754 1,791,753 33,492 1,472 4a.1.1 Totals 354 7,497 7,536 2,644 9

26,148 567 17,204 61,960 61,960 238 24,972 4,507 631 671 2,830,059 74,084 2,943 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 480 2,215 424 2,633 800 6,551 6,551 124,489 5,601,986 8,748 4a.1.3 Main Condensers 921 1,579 302 1,877 715 5,393 5,393 88,729 3,992,800 16,783 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor Building 983 147 1,130 1,130 11,163 4a.1.4.2 Auxiliary Building 408 61 469 469 4,733 4a.1.4.3 Off Gas Building 71 11 82 82 920 4a.1.4.4 Turbine Building 597 90 687 687 7,337 4a.1.4 Totals 2,059 309 2,368 2,368 24,153 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 8 of 23 Table D-1 LaSalle County Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:23 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Disposal of Plant Systems 4a.1.5.1 Auxiliary Steam 108 2

4 24 31 169 169 1,250 50,766 1,862 4a.1.5.2 CSCS Equipment Cooling 6

1 7

7 122 4a.1.5.3 Circulating Water 175 26 201 201 3,464 4a.1.5.4 Circulating Water - RCA 225 4

8 50 65 353 353 2,599 105,533 3,802 4a.1.5.5 Clean Condensate Storage 83 12 95 95 1,677 4a.1.5.6 Clean Condensate Storage - RCA 25 0

0 3

7 36 36 150 6,112 419 4a.1.5.7 Condensate 841 42 78 487 299 1,748 1,748 25,514 1,036,129 15,392 4a.1.5.8 Condensate Booster 867 94 174 1,082 415 2,632 2,632 56,706 2,302,853 16,068 4a.1.5.9 Condensate Polishing Demineralizer 819 10 18 111 225 1,182 1,182 5,808 235,877 14,440 4a.1.5.10 Containment Combustible Gas Control 85 1

2 13 24 124 124 671 27,268 1,436 4a.1.5.11 Cycled Condensate Storage 269 4

7 46 76 403 403 2,421 98,310 4,774 4a.1.5.12 Drywell Instrument Nitrogen 61 1

2 12 18 94 94 646 26,238 1,070 4a.1.5.13 Extraction Steam 322 11 20 125 103 582 582 6,547 265,890 5,933 4a.1.5.14 Feedwater 534 26 48 297 188 1,093 1,093 15,570 632,298 9,816 4a.1.5.15 Feedwater Heater Vents & Drains 2,557 74 137 854 795 4,418 4,418 44,739 1,816,866 46,568 4a.1.5.16 Gland Steam 229 3

6 36 64 338 338 1,878 76,265 4,100 4a.1.5.17 HVAC-River\\Lake Screen House 8

1 9

9 151 4a.1.5.18 HVAC-Service Building 12 2

14 14 221 4a.1.5.19 Hydrogen & Carbon Dioxide 110 2

4 23 32 171 171 1,214 49,318 1,878 4a.1.5.20 Main Steam 125 1

3 17 34 179 179 866 35,179 2,211 4a.1.5.21 Misc Bldgs Floor Drains 0

0 1

1 9

4a.1.5.22 Screen Wash 25 4

29 29 506 4a.1.5.23 Service Air 11 2

13 13 222 4a.1.5.24 Standby Gas Treatment 51 2

3 20 17 93 93 1,049 42,596 932 4a.1.5.25 Station Heat Recovery 252 4

6 40 70 373 373 2,104 85,433 4,310 4a.1.5.26 Switchgear Heat Removal 10 1

11 11 180 4a.1.5.27 Turbine Bldg Closed Cooling Water 471 14 26 164 148 823 823 8,615 349,869 8,388 4a.1.5.28 Turbine Building Equip Drains 87 2

3 20 25 137 137 1,035 42,020 1,562 4a.1.5.29 Turbine Building Floor Drains 34 0

0 3

9 46 46 150 6,104 598 4a.1.5.30 Turbine Generator 178 9

17 103 63 370 370 5,416 219,950 3,324 4a.1.5.31 Turbine Oil 529 21 26 112 50 167 904 904 5,855 519 280,058 9,595 4a.1.5 Totals 9,111 327 594 3,642 50 2,925 16,649 16,269 380 190,804 519 7,790,930 165,027 4a.1.6 Scaffolding in support of decommissioning 2,111 39 9

43 14 543 2,758 2,758 2,054 128 103,876 43,646 4a.1 Subtotal Period 4a Activity Costs 354 22,178 11,696 3,972 8,204 26,212 567 22,496 95,679 95,299 380 406,313 25,618 4,507 631 671 20,319,650 332,441 2,943 Period 4a Collateral Costs 4a.3.1 Process liquid waste 65 27 128 126 86 432 432 454 27,224 88 4a.3.2 Small tool allowance 279 42 321 289 32 4a.3 Subtotal Period 4a Collateral Costs 65 279 27 128 126 128 753 721 32 454 27,224 88 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 72 18 90 90 4a.4.2 Insurance 655 65 720 720 4a.4.3 Property taxes 776 78 854 768 85 4a.4.4 Health physics supplies 1,825 456 2,281 2,281 4a.4.5 Heavy equipment rental 2,593 389 2,982 2,982 4a.4.6 Disposal of DAW generated 17 6

340 88 450 450 6,089 121,789 28 4a.4.7 Plant energy budget 2,023 303 2,327 2,327 4a.4.8 NRC Fees 1,022 102 1,125 1,125 4a.4.9 Site O&M Costs 194 29 223 223 4a.4.10 Liquid Radwaste Processing Equipment/Services 595 89 684 684 4a.4.11 Security Staff Cost 3,157 474 3,630 3,630 84,629 4a.4.12 DOC Staff Cost 17,754 2,663 20,418 20,418 222,264 4a.4.13 Utility Staff Cost 29,351 4,403 33,754 33,754 396,608 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 9 of 23 Table D-1 LaSalle County Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:23 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours 4a.4 Subtotal Period 4a Period-Dependent Costs 72 4,418 17 6

340 55,528 9,157 69,539 69,453 85 6,089 121,789 28 703,501 4a.0 TOTAL PERIOD 4a COST 491 26,875 11,739 4,107 8,204 26,678 56,095 31,781 165,971 165,474 497 406,313 32,161 4,507 631 671 20,468,660 332,557 706,445 PERIOD 4b - Site Decontamination Period 4b Direct Decommissioning Activities 4b.1.1 Remove spent fuel racks 832 82 166 157 1,030 734 3,001 3,001 9,726 872,665 1,631 Disposal of Plant Systems 4b.1.2.1 Aux Diesel Bldg Floor Drains 4

1 5

5 86 4b.1.2.2 Auxiliary Diesel Generator 52 8

59 59 1,006 4b.1.2.3 Containment Monitoring 20 0

0 1

5 27 27 78 3,169 392 4b.1.2.4 Control Rod Drive 194 2

3 19 52 270 270 1,006 40,845 3,622 4b.1.2.5 Diesel Oil 43 6

50 50 823 4b.1.2.6 Electrical 273 41 314 314 5,201 4b.1.2.7 Electrical - Contaminated 676 9

17 105 188 995 995 5,509 223,712 11,889 4b.1.2.8 Electrical - RCA 4,641 86 155 962 1,337 7,182 7,182 50,427 2,047,847 79,254 4b.1.2.9 Fire Protection 116 17 134 134 2,339 4b.1.2.10 Fire Protection - RCA 664 13 23 143 192 1,035 1,035 7,493 304,287 11,294 4b.1.2.11 Fuel Pool Cooling & Cleanup 732 22 41 254 229 1,279 1,279 13,307 540,403 13,138 4b.1.2.12 HVAC-Auxiliary Building 198 5

9 55 60 326 326 2,889 117,333 3,260 4b.1.2.13 HVAC-Diesel Generator Room 7

1 8

8 127 4b.1.2.14 HVAC-Off Gas Building 20 0

1 5

6 31 31 237 9,643 326 4b.1.2.15 HVAC-Primary Containment 865 19 36 225 257 1,403 1,403 11,773 478,116 14,924 4b.1.2.16 HVAC-Radwaste Building 5

0 0

2 2

10 10 110 4,453 97 4b.1.2.17 HVAC-Turbine Building 731 15 28 177 215 1,166 1,166 9,260 376,037 11,966 4b.1.2.18 High Pressure Core Spray 316 29 36 134 94 131 739 739 7,014 889 364,579 5,729 4b.1.2.19 Instrument Air 5

1 5

5 94 4b.1.2.20 Instrument Air - RCA 134 1

2 12 36 185 185 629 25,528 2,372 4b.1.2.21 Low Pressure Core Spray 151 13 17 62 43 62 347 347 3,225 410 167,703 2,731 4b.1.2.22 Nuclear Boiler 1,533 109 129 409 415 579 3,174 3,174 21,452 3,922 1,222,966 28,205 4b.1.2.23 Off Gas 598 34 37 101 139 209 1,118 1,118 5,271 1,319 332,284 10,737 4b.1.2.24 Primary Containment Vent & Purge 406 19 35 219 142 821 821 11,470 465,819 7,544 4b.1.2.25 Process Radiation Monitoring 20 0

0 1

5 26 26 42 1,697 393 4b.1.2.26 Process Sampling 27 0

0 2

7 36 36 90 3,660 528 4b.1.2.27 Radioactive Waste Disposal 1,459 54 57 189 174 450 2,383 2,383 9,882 1,711 548,907 26,040 4b.1.2.28 Reactor Bldg Closed Cooling Water 339 21 37 230 127 753 753 12,027 488,418 5,945 4b.1.2.29 Reactor Building Equipment Drains 64 2

2 7

7 19 101 101 344 68 19,878 1,152 4b.1.2.30 Reactor Building Floor Drains 6

0 0

0 0

2 8

8 17 2

897 108 4b.1.2.31 Reactor Core Isolation Cooling 214 8

9 24 33 67 354 354 1,237 309 77,945 3,847 4b.1.2.32 Reactor Recirculation 40 1

1 2

3 11 57 57 103 26 6,479 732 4b.1.2.33 Reactor Water Clean-up 831 28 23 37 110 247 1,276 1,276 1,958 1,041 172,819 14,701 4b.1.2.34 Residual Heat Removal 1,546 135 171 633 456 635 3,575 3,575 33,146 4,305 1,732,275 28,360 4b.1.2.35 Service Air - RCA 234 2

4 25 63 328 328 1,326 53,837 3,994 4b.1.2.36 Service Water 48 7

55 55 938 4b.1.2.37 Service Water - RCA 683 22 40 247 216 1,208 1,208 12,930 525,074 11,877 4b.1.2.38 Standby Liquid Control 51 1

1 7

14 73 73 341 13,830 854 4b.1.2 Totals 17,944 651 915 4,287 1,475 5,645 30,917 30,286 631 224,591 14,002 10,370,440 316,624 4b.1.3 Scaffolding in support of decommissioning 3,166 58 14 65 20 814 4,138 4,138 3,080 192 155,814 65,468 Decontamination of Site Buildings 4b.1.4.1 Reactor Building 2,568 3,069 310 339 239 1,092 2,442 10,059 10,059 12,516 16,303 2,089,406 99,097 4b.1.4.2 Auxiliary Building 287 56 8

9 2

24 166 553 553 100 459 49,865 6,152 4b.1.4.3 Off Gas Building 129 28 6

7 1

17 78 266 266 46 326 34,435 2,805 4b.1.4.4 Turbine Building 1,521 629 77 88 98 207 1,005 3,624 3,624 5,149 3,809 584,008 38,010 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 10 of 23 Table D-1 LaSalle County Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:23 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours 4b.1.4 Totals 4,506 3,783 401 443 340 1,341 3,691 14,503 14,503 17,812 20,897 2,757,713 146,065 4b.1 Subtotal Period 4b Activity Costs 5,338 24,975 1,277 1,528 4,692 3,865 10,885 52,559 51,928 631 245,483 44,816 14,156,630 529,789 Period 4b Additional Costs 4b.2.1 License Termination Survey Planning 940 282 1,222 1,222 6,240 4b.2.2 ISFSI License Termination 57 1

38 153 749 171 1,168 1,168 2,905 244,104 3,498 1,280 4b.2 Subtotal Period 4b Additional Costs 57 1

38 153 1,689 453 2,391 1,222 1,168 2,905 244,104 3,498 7,520 Period 4b Collateral Costs 4b.3.1 Process liquid waste 211 87 418 412 280 1,409 1,409 1,480 88,801 289 4b.3.2 Small tool allowance 445 67 511 511 4b.3.3 Decommissioning Equipment Disposition 114 31 127 40 45 356 356 6,000 373 303,507 88 4b.3 Subtotal Period 4b Collateral Costs 211 445 201 449 127 452 392 2,276 2,276 6,000 1,853 392,308 377 Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 1,352 338 1,690 1,690 4b.4.2 Insurance 935 94 1,029 1,029 4b.4.3 Property taxes 1,109 111 1,220 1,220 4b.4.4 Health physics supplies 2,739 685 3,423 3,423 4b.4.5 Heavy equipment rental 3,674 551 4,225 4,225 4b.4.6 Disposal of DAW generated 24 9

495 128 657 657 8,878 177,563 41 4b.4.7 Plant energy budget 2,282 342 2,624 2,624 4b.4.8 NRC Fees 1,461 146 1,607 1,607 4b.4.9 Site O&M Costs 277 42 319 319 4b.4.10 Liquid Radwaste Processing Equipment/Services 850 128 978 978 4b.4.11 Security Staff Cost 926 139 1,065 1,065 25,457 4b.4.12 DOC Staff Cost 16,451 2,468 18,919 18,919 217,543 4b.4.13 Utility Staff Cost 27,655 4,148 31,803 31,803 388,800 4b.4 Subtotal Period 4b Period-Dependent Costs 1,352 6,412 24 9

495 51,946 9,318 69,558 69,558 8,878 177,563 41 631,800 4b.0 TOTAL PERIOD 4b COST 6,901 31,889 1,503 2,025 4,819 4,965 53,635 21,047 126,783 124,984 1,168 631 251,483 58,453 14,970,610 533,704 639,320 PERIOD 4d - Delay before License Termination Period 4d Direct Decommissioning Activities Period 4d Period-Dependent Costs 4d.4.1 Insurance 4d.4.2 Property taxes 622 62 684 684 4d.4.3 Health physics supplies 89 22 111 111 4d.4.4 Disposal of DAW generated 0

0 7

2 9

9 124 2,480 1

4d.4.5 Plant energy budget 4d.4.6 NRC Fees 227 23 250 250 4d.4.7 Site O&M Costs 155 23 179 179 4d.4.8 Security Staff Cost 3

0 3

3 4d.4.9 Utility Staff Cost 1,278 192 1,470 1,470 18,160 4d.4 Subtotal Period 4d Period-Dependent Costs 89 0

0 7

2,285 324 2,705 2,705 124 2,480 1

18,160 4d.0 TOTAL PERIOD 4d COST 89 0

0 7

2,285 324 2,705 2,705 124 2,480 1

18,160 PERIOD 4e - License Termination Period 4e Direct Decommissioning Activities 4e.1.1 ORISE confirmatory survey 151 45 197 197 4e.1.2 Terminate license a

4e.1 Subtotal Period 4e Activity Costs 151 45 197 197 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 11 of 23 Table D-1 LaSalle County Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:23 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 4e Additional Costs 4e.2.1 License Termination Survey 10,410 3,123 13,533 13,533 191,885 3,120 4e.2 Subtotal Period 4e Additional Costs 10,410 3,123 13,533 13,533 191,885 3,120 Period 4e Collateral Costs 4e.3.1 DOC staff relocation expenses 1,130 169 1,299 1,299 4e.3 Subtotal Period 4e Collateral Costs 1,130 169 1,299 1,299 Period 4e Period-Dependent Costs 4e.4.1 Insurance 4e.4.2 Property taxes 382 38 420 420 4e.4.3 Health physics supplies 942 235 1,177 1,177 4e.4.4 Disposal of DAW generated 1

0 19 5

25 25 340 6,795 2

4e.4.5 Plant energy budget 210 31 241 241 4e.4.6 NRC Fees 539 54 593 593 4e.4.7 Site O&M Costs 95 14 110 110 4e.4.8 Security Staff Cost 528 79 607 607 11,957 4e.4.9 DOC Staff Cost 3,856 578 4,434 4,434 47,430 4e.4.10 Utility Staff Cost 4,617 693 5,310 5,310 57,793 4e.4 Subtotal Period 4e Period-Dependent Costs 942 1

0 19 10,227 1,728 12,917 12,917 340 6,795 2

117,180 4e.0 TOTAL PERIOD 4e COST 942 1

0 19 21,919 5,066 27,947 27,947 340 6,795 191,887 120,300 PERIOD 4 TOTALS 7,392 59,794 13,243 6,132 13,023 31,669 133,934 58,219 323,406 321,110 1,168 1,128 657,796 91,078 4,507 631 671 35,448,540 1,058,149 1,484,225 PERIOD 5b - Site Restoration Period 5b Direct Decommissioning Activities Demolition of Remaining Site Buildings 5b.1.1.1 Reactor Building 5,664 850 6,514 6,514 64,472 5b.1.1.2 Auxiliary Building 3,692 554 4,246 4,246 43,048 5b.1.1.3 Diesel Generator Room 468 70 538 538 6,000 5b.1.1.4 Off Gas Building 648 97 745 745 8,484 5b.1.1.5 Turbine Building 5,501 825 6,326 6,326 68,584 5b.1.1.6 Turbine Pedestal 2,881 432 3,313 3,313 30,829 5b.1.1 Totals 18,854 2,828 21,682 21,682 221,416 Site Closeout Activities 5b.1.2 Grade & landscape site 149 22 171 171 499 5b.1.3 Final report to NRC 184 28 212 212 1,560 5b.1 Subtotal Period 5b Activity Costs 19,003 184 2,878 22,065 212 21,853 221,916 1,560 Period 5b Additional Costs 5b.2.1 Concrete Crushing 776 4

117 897 897 3,936 5b.2.2 ISFSI Demolition and Site Restoration 1,604 24 244 1,872 1,872 21,545 80 5b.2 Subtotal Period 5b Additional Costs 2,380 28 361 2,769 1,872 897 25,481 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 212 32 244 244 5b.3 Subtotal Period 5b Collateral Costs 212 32 244 244 Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property taxes 998 100 1,098 1,098 5b.4.3 Heavy equipment rental 4,728 709 5,437 5,437 5b.4.4 Plant energy budget 274 41 315 315 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 12 of 23 Table D-1 LaSalle County Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:23 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 5b Period-Dependent Costs (continued) 5b.4.5 Site O&M Cost 249 37 287 287 5b.4.6 Security Staff Cost 1,247 187 1,435 1,435 27,619 5b.4.7 DOC Staff Cost 9,384 1,408 10,792 10,792 110,391 5b.4.8 Utility Staff Cost 4,478 672 5,149 5,149 54,154 5b.4 Subtotal Period 5b Period-Dependent Costs 4,728 16,631 3,154 24,512 24,512 192,164 5b.0 TOTAL PERIOD 5b COST 26,322 16,842 6,425 49,590 212 1,872 47,506 247,397 193,804 PERIOD 5 TOTALS 26,322 16,842 6,425 49,590 212 1,872 47,506 247,397 193,804 TOTAL COST TO DECOMMISSION 15,427 91,267 13,392 6,765 13,023 32,651 367,706 101,561 641,791 495,902 96,292 49,597 657,796 99,834 4,507 631 671 35,712,270 1,440,428 3,571,873 TOTAL COST TO DECOMMISSION WITH 18.8% CONTINGENCY:

$641,791 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 77.27% OR:

$495,902 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 15% OR:

$96,292 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 7.73% OR:

$49,597 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

104,972 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

671 cubic feet TOTAL SCRAP METAL REMOVED:

51,885 tons TOTAL CRAFT LABOR REQUIREMENTS:

1,440,428 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.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 13 of 23 Table D-2 LaSalle County Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:43 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs 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 Activities 1a.1.1 SAFSTOR site characterization survey 398 119 517 517 1a.1.2 Prepare preliminary decommissioning cost 64 10 74 74 545 1a.1.3 Notification of Cessation of Operations a

1a.1.4 Remove fuel & source material n/a 1a.1.5 Notification of Permanent Defueling a

1a.1.6 Deactivate plant systems & process waste a

1a.1.7 Prepare and submit PSDAR 99 15 114 114 838 1a.1.8 Review plant dwgs & specs.

64 10 74 74 545 1a.1.9 Perform detailed rad survey a

1a.1.10 Estimate by-product inventory 49 7

57 57 419 1a.1.11 End product description 49 7

57 57 419 1a.1.12 Detailed by-product inventory 74 11 85 85 629 1a.1.13 Define major work sequence 49 7

57 57 419 1a.1.14 Perform SER and EA 153 23 176 176 1,299 1a.1.15 Perform Site-Specific Cost Study 247 37 284 284 2,095 Activity Specifications 1a.1.16.1 Prepare plant and facilities for SAFSTOR 243 36 280 280 2,061 1a.1.16.2 Plant systems 206 31 237 237 1,746 1a.1.16.3 Plant structures and buildings 154 23 177 177 1,307 1a.1.16.4 Waste management 99 15 114 114 838 1a.1.16.5 Facility and site dormancy 99 15 114 114 838 1a.1.16 Total 801 120 922 922 6,791 Detailed Work Procedures 1a.1.17.1 Plant systems 59 9

67 67 496 1a.1.17.2 Facility closeout & dormancy 59 9

68 68 503 1a.1.17 Total 118 18 136 136 999 1a.1.18 Procure vacuum drying system 5

1 6

6 42 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 2,172 386 2,558 2,558 15,038 Period 1a Period-Dependent Costs 1a.4.1 Insurance 876 88 964 964 1a.4.2 Property taxes 1a.4.3 Health physics supplies 396 99 495 495 1a.4.4 Heavy equipment rental 396 59 455 455 1a.4.5 Disposal of DAW generated 2

1 34 9

45 45 610 12,190 3

1a.4.6 Plant energy budget 1,371 206 1,577 1,577 1a.4.7 NRC Fees 471 47 518 518 1a.4.8 Emergency Planning Fees 313 31 344 344 1a.4.9 Site O&M Costs 125 19 144 144 1a.4.10 Spent Fuel Pool O&M 762 114 877 877 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 6,070 911 6,981 6,981 157,471 1a.4.13 Utility Staff Cost 31,082 4,662 35,745 35,745 423,400 1a.4 Subtotal Period 1a Period-Dependent Costs 792 2

1 34 41,115 6,251 48,194 46,923 1,271 610 12,190 3

580,871 1a.0 TOTAL PERIOD 1a COST 792 2

1 34 43,287 6,637 50,752 49,481 1,271 610 12,190 3

595,909 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 14 of 23 Table D-2 LaSalle County Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:43 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours PERIOD 1b - SAFSTOR Limited DECON Activities Period 1b Direct Decommissioning Activities Decontamination of Site Buildings 1b.1.1.1 Reactor Building 2,820 1,410 4,230 4,230 49,197 1b.1.1.2 Auxiliary Building 1,385 692 2,077 2,077 24,021 1b.1.1.3 IRSF Building 67 33 100 100 1,210 1b.1.1.4 Service Building 92 46 139 139 1,692 1b.1.1.5 Solid Radwaste Building 417 208 625 625 7,355 1b.1.1.6 Turbine Building 1,484 742 2,227 2,227 27,018 1b.1.1 Totals 6,265 3,132 9,397 9,397 110,493 1b.1 Subtotal Period 1b Activity Costs 6,265 3,132 9,397 9,397 110,493 Period 1b Collateral Costs 1b.3.1 Decon equipment 763 114 877 877 1b.3.2 Process liquid waste 176 71 339 334 229 1,148 1,148 1,198 71,877 234 1b.3.3 Small tool allowance 96 14 111 111 1b.3 Subtotal Period 1b Collateral Costs 939 96 71 339 334 358 2,136 2,136 1,198 71,877 234 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 1,420 355 1,774 1,774 1b.4.2 Insurance 105 11 116 116 1b.4.3 Property taxes 1,155 116 1,271 1,271 1b.4.4 Health physics supplies 505 126 632 632 1b.4.5 Heavy equipment rental 99 15 113 113 1b.4.6 Disposal of DAW generated 2

1 49 13 65 65 876 17,516 4

1b.4.7 Plant energy budget 342 51 393 393 1b.4.8 NRC Fees 117 12 129 129 1b.4.9 Emergency Planning Fees 78 8

86 86 1b.4.10 Site O&M Costs 31 5

36 36 1b.4.11 Spent Fuel Pool O&M 190 29 219 219 1b.4.12 ISFSI Operating Costs 11 2

13 13 1b.4.13 Security Staff Cost 1,513 227 1,740 1,740 39,260 1b.4.14 Utility Staff Cost 7,749 1,162 8,912 8,912 105,560 1b.4 Subtotal Period 1b Period-Dependent Costs 1,420 604 2

1 49 11,292 2,130 15,498 15,181 317 876 17,516 4

144,820 1b.0 TOTAL PERIOD 1b COST 8,623 700 73 340 382 11,292 5,620 27,031 26,714 317 2,074 89,394 110,731 144,820 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 432 65 496 496 3,000 1c.1.2 Install containment pressure equal. lines 42 6

48 48 700 1c.1.3 Interim survey prior to dormancy 733 220 953 953 13,416 1c.1.4 Secure building accesses a

1c.1.5 Prepare & submit interim report 29 4

33 33 244 1c.1 Subtotal Period 1c Activity Costs 473 762 295 1,530 1,530 17,116 244 Period 1c Additional Costs 1c.2.1 Spent Fuel Pool Isolation 6,460 969 7,429 7,429 1c.2 Subtotal Period 1c Additional Costs 6,460 969 7,429 7,429 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 15 of 23 Table D-2 LaSalle County Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:43 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 1c Collateral Costs 1c.3.1 Process liquid waste 158 64 305 300 206 1,033 1,033 1,078 64,659 210 1c.3.2 Small tool allowance 4

1 4

4 1c.3 Subtotal Period 1c Collateral Costs 158 4

64 305 300 207 1,037 1,037 1,078 64,659 210 Period 1c Period-Dependent Costs 1c.4.1 Insurance 105 11 116 116 1c.4.2 Property taxes 1,155 116 1,271 1,271 1c.4.3 Health physics supplies 139 35 173 173 1c.4.4 Heavy equipment rental 99 15 113 113 1c.4.5 Disposal of DAW generated 0

0 6

2 8

8 107 2,132 0

1c.4.6 Plant energy budget 342 51 393 393 1c.4.7 NRC Fees 117 12 129 129 1c.4.8 Emergency Planning Fees 78 8

86 86 1c.4.9 Site O&M Costs 31 5

36 36 1c.4.10 Spent Fuel Pool O&M 190 29 219 219 1c.4.11 ISFSI Operating Costs 11 2

13 13 1c.4.12 Security Staff Cost 1,513 227 1,740 1,740 39,260 1c.4.13 Utility Staff Cost 2,147 322 2,468 2,468 27,040 1c.4 Subtotal Period 1c Period-Dependent Costs 237 0

0 6

5,689 832 6,765 6,448 317 107 2,132 0

66,300 1c.0 TOTAL PERIOD 1c COST 158 714 64 305 306 12,911 2,303 16,761 16,444 317 1,184 66,791 17,326 66,544 PERIOD 1 TOTALS 8,781 2,207 138 645 722 67,490 14,560 94,544 92,639 1,905 3,868 168,375 128,060 807,274 PERIOD 2a - SAFSTOR Dormancy with Wet Spent Fuel Storage Period 2a Direct Decommissioning Activities 2a.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 1,288 193 1,481 1,481 2a.1.5 Maintenance supplies 1,075 269 1,344 1,344 2a.1 Subtotal Period 2a Activity Costs 2,363 462 2,825 2,825 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 14,500 2,175 16,675 16,675 2a.3 Subtotal Period 2a Collateral Costs 14,500 2,175 16,675 16,675 Period 2a Period-Dependent Costs 2a.4.1 Insurance 3,603 360 3,964 3,964 2a.4.2 Property taxes 11,689 1,169 12,858 12,858 2a.4.3 Health physics supplies 674 168 842 842 2a.4.4 Disposal of DAW generated 9

3 185 48 245 245 3,313 66,251 15 2a.4.5 Plant energy budget 2,345 352 2,696 2,696 2a.4.6 NRC Fees 1,528 153 1,681 1,681 2a.4.7 Emergency Planning Fees 854 85 940 940 2a.4.8 Site O&M Costs 1,068 160 1,228 1,228 2a.4.9 Spent Fuel Pool O&M 6,519 978 7,496 7,496 2a.4.10 ISFSI Operating Costs 376 56 432 432 2a.4.11 Security Staff Cost 24,073 3,611 27,684 27,684 609,219 2a.4.12 Utility Staff Cost 25,854 3,878 29,733 29,733 331,718 2a.4 Subtotal Period 2a Period-Dependent Costs 674 9

3 185 77,910 11,019 89,800 2,768 87,032 3,313 66,251 15 940,937 2a.0 TOTAL PERIOD 2a COST 674 9

3 185 94,773 13,656 109,299 5,593 103,707 3,313 66,251 15 940,937 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 16 of 23 Table D-2 LaSalle County Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:43 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours PERIOD 2b - SAFSTOR Dormancy with Dry Spent Fuel Storage Period 2b Direct Decommissioning Activities 2b.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 301 45 346 346 2b.1.5 Maintenance supplies 251 63 314 314 2b.1 Subtotal Period 2b Activity Costs 553 108 661 661 Period 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 3,000 450 3,450 3,450 2b.3 Subtotal Period 2b Collateral Costs 3,000 450 3,450 3,450 Period 2b Period-Dependent Costs 2b.4.1 Insurance 843 84 927 927 2b.4.2 Property taxes 999 100 1,099 1,099 2b.4.3 Health physics supplies 145 36 181 181 2b.4.4 Disposal of DAW generated 2

1 42 11 56 56 751 15,012 3

2b.4.5 Plant energy budget 274 41 315 315 2b.4.6 NRC Fees 357 36 393 393 2b.4.7 Emergency Planning Fees 200 20 220 220 2b.4.8 Site O&M Costs 250 37 287 287 2b.4.9 ISFSI Operating Costs 88 13 101 101 2b.4.10 Security Staff Cost 4,821 723 5,544 5,544 112,629 2b.4.11 Utility Staff Cost 2,562 384 2,947 2,947 35,666 2b.4 Subtotal Period 2b Period-Dependent Costs 145 2

1 42 10,395 1,486 12,071 630 11,441 751 15,012 3

148,294 2b.0 TOTAL PERIOD 2b COST 145 2

1 42 13,948 2,044 16,182 1,290 14,891 751 15,012 3

148,294 PERIOD 2 TOTALS 818 11 4

227 108,720 15,700 125,481 6,883 118,598 4,063 81,263 19 1,089,231 PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy Period 3a Direct Decommissioning Activities 3a.1.1 Prepare preliminary decommissioning cost 64 10 74 74 545 3a.1.2 Review plant dwgs & specs.

227 34 262 262 1,927 3a.1.3 Perform detailed rad survey a

3a.1.4 End product description 49 7

57 57 419 3a.1.5 Detailed by-product inventory 64 10 74 74 545 3a.1.6 Define major work sequence 371 56 426 426 3,143 3a.1.7 Perform SER and EA 153 23 176 176 1,299 3a.1.8 Perform Site-Specific Cost Study 247 37 284 284 2,095 3a.1.9 Prepare/submit License Termination Plan 203 30 233 233 1,716 3a.1.10 Receive NRC approval of termination plan a

Activity Specifications 3a.1.11.1 Re-activate plant & temporary facilities 364 55 419 377 42 3,088 3a.1.11.2 Plant systems 206 31 237 213 24 1,746 3a.1.11.3 Reactor internals 351 53 404 404 2,975 3a.1.11.4 Reactor vessel 321 48 370 370 2,724 3a.1.11.5 Sacrificial shield 25 4

28 28 210 3a.1.11.6 Moisture separators/reheaters 49 7

57 57 419 3a.1.11.7 Reinforced concrete 79 12 91 45 45 670 3a.1.11.8 Main Turbine 103 15 119 119 875 3a.1.11.9 Main Condensers 103 15 119 119 875 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 17 of 23 Table D-2 LaSalle County Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:43 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Activity Specifications (continued) 3a.1.11.10 Pressure suppression structure 99 15 114 114 838 3a.1.11.11 Drywell 79 12 91 91 670 3a.1.11.12 Plant structures & buildings 154 23 177 89 89 1,307 3a.1.11.13 Waste management 227 34 262 262 1,927 3a.1.11.14 Facility & site closeout 45 7

51 26 26 377 3a.1.11 Total 2,207 331 2,538 2,313 225 18,701 Planning & Site Preparations 3a.1.12 Prepare dismantling sequence 119 18 136 136 1,006 3a.1.13 Plant prep. & temp. svces 2,800 420 3,220 3,220 3a.1.14 Design water clean-up system 69 10 80 80 587 3a.1.15 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,200 330 2,530 2,530 3a.1.16 Procure casks/liners & containers 61 9

70 70 515 3a.1 Subtotal Period 3a Activity Costs 8,835 1,325 10,160 9,935 225 32,497 Period 3a Period-Dependent Costs 3a.4.1 Insurance 423 42 465 465 3a.4.2 Property taxes 501 50 551 551 3a.4.3 Health physics supplies 330 82 412 412 3a.4.4 Heavy equipment rental 397 60 456 456 3a.4.5 Disposal of DAW generated 1

1 27 7

36 36 482 9,639 2

3a.4.6 Plant energy budget 1,375 206 1,581 1,581 3a.4.7 NRC Fees 215 21 236 236 3a.4.8 Site O&M Costs 125 19 144 144 3a.4.9 Security Staff Cost 229 34 264 264 6,274 3a.4.10 Utility Staff Cost 14,299 2,145 16,443 16,443 200,777 3a.4 Subtotal Period 3a Period-Dependent Costs 726 1

1 27 17,166 2,667 20,588 20,588 482 9,639 2

207,051 3a.0 TOTAL PERIOD 3a COST 726 1

1 27 26,001 3,992 30,749 30,523 225 482 9,639 2

239,549 PERIOD 3b - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 234 35 269 242 27 1,983 3b.1.1.2 Reactor internals 198 30 227 227 1,676 3b.1.1.3 Remaining buildings 67 10 77 19 58 566 3b.1.1.4 CRD housings & NIs 49 7

57 57 419 3b.1.1.5 Incore instrumentation 49 7

57 57 419 3b.1.1.6 Removal primary containment 99 15 114 114 838 3b.1.1.7 Reactor vessel 179 27 206 206 1,521 3b.1.1.8 Facility closeout 59 9

68 34 34 503 3b.1.1.9 Sacrificial shield 59 9

68 68 503 3b.1.1.10 Reinforced concrete 49 7

57 28 28 419 3b.1.1.11 Main Turbine 103 15 118 118 872 3b.1.1.12 Main Condensers 103 15 119 119 875 3b.1.1.13 Moisture separators & reheaters 99 15 114 114 838 3b.1.1.14 Radwaste building 135 20 155 140 16 1,144 3b.1.1.15 Reactor building 135 20 155 140 16 1,144 3b.1.1 Total 1,619 243 1,862 1,684 178 13,718 3b.1 Subtotal Period 3b Activity Costs 1,619 243 1,862 1,684 178 13,718 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 18 of 23 Table D-2 LaSalle County Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:43 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 3b Additional Costs 3b.2.1 Site Characterization 2,550 765 3,315 3,315 12,457 4,471 3b.2 Subtotal Period 3b Additional Costs 2,550 765 3,315 3,315 12,457 4,471 Period 3b Collateral Costs 3b.3.1 Decon equipment 763 114 877 877 3b.3.2 DOC 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 763 1,100 1,130 449 3,442 3,442 Period 3b Period-Dependent Costs 3b.4.1 Decon supplies 23 6

29 29 3b.4.2 Insurance 211 21 232 232 3b.4.3 Property taxes 251 25 276 276 3b.4.4 Health physics supplies 178 44 222 222 3b.4.5 Heavy equipment rental 198 30 228 228 3b.4.6 Disposal of DAW generated 1

0 15 4

20 20 266 5,315 1

3b.4.7 Plant energy budget 687 103 790 790 3b.4.8 NRC Fees 107 11 118 118 3b.4.9 Site O&M Costs 63 9

72 72 3b.4.10 Security Staff Cost 115 17 132 132 3,137 3b.4.11 DOC Staff Cost 3,296 494 3,790 3,790 42,874 3b.4.12 Utility Staff Cost 7,149 1,072 8,222 8,222 100,389 3b.4 Subtotal Period 3b Period-Dependent Costs 23 376 1

0 15 11,879 1,837 14,132 14,132 266 5,315 1

146,400 3b.0 TOTAL PERIOD 3b COST 786 1,476 1

0 15 17,178 3,294 22,750 22,572 178 266 5,315 12,458 164,590 PERIOD 3 TOTALS 786 2,202 2

1 42 43,179 7,286 53,498 53,095 403 748 14,954 12,460 404,138 PERIOD 4a - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Recirculation System Piping & Valves 21 77 18 16 198 84 414 414 1,006 121,649 1,846 4a.1.1.2 Recirculation Pumps & Motors 11 43 14 28 9

313 102 520 520 238 2,356 211,420 1,136 4a.1.1.3 CRDMs & NIs Removal 48 177 492 88 166 172 1,143 1,143 5,536 141,063 4,118 4a.1.1.4 Reactor Vessel Internals 171 2,440 4,993 1,437 10,215 283 8,673 28,213 28,213 2,128 1,753 631 454,265 33,492 1,472 4a.1.1.5 Vessel & Internals GTCC Disposal 11,118 1,668 12,786 12,786 671 109,910 4a.1.1.6 Reactor Vessel 103 4,760 2,019 1,075 4,157 283 6,516 18,914 18,914 13,945 2,754 1,791,753 33,492 1,472 4a.1.1 Totals 354 7,497 7,536 2,644 9

26,168 567 17,214 61,989 61,989 238 24,972 4,507 631 671 2,830,059 74,084 2,943 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 480 2,215 424 2,633 800 6,551 6,551 124,489 5,601,986 8,748 4a.1.3 Main Condensers 921 1,579 302 1,877 715 5,393 5,393 88,729 3,992,800 16,783 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor Building 985 148 1,132 1,132 11,181 4a.1.4.2 Auxiliary Building 407 61 468 468 4,723 4a.1.4.3 IRSF Building 74 11 85 85 939 4a.1.4.4 Service Building 162 24 187 187 2,230 4a.1.4.5 Solid Radwaste Building 224 34 258 258 2,559 4a.1.4.6 Turbine Building 597 90 687 687 7,337 4a.1.4 Totals 2,449 367 2,816 2,816 28,970 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 19 of 23 Table D-2 LaSalle County Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:43 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Disposal of Plant Systems 4a.1.5.1 Acid & Caustic 17 2

19 19 317 4a.1.5.2 Auxiliary Steam 304 7

12 74 89 486 486 3,882 157,664 5,230 4a.1.5.3 CSCS Equipment Cooling 7

1 9

9 141 4a.1.5.4 Chemical Feed 34 5

39 39 638 4a.1.5.5 Circulating Water 158 24 182 182 3,125 4a.1.5.6 Circulating Water - RCA 218 3

6 36 61 324 324 1,874 76,117 3,663 4a.1.5.7 Clean Condensate Storage 146 22 168 168 2,875 4a.1.5.8 Clean Condensate Storage - RCA 68 1

1 8

18 96 96 429 17,422 1,131 4a.1.5.9 Condensate 721 39 72 449 262 1,542 1,542 23,501 954,377 13,200 4a.1.5.10 Condensate Booster 811 92 171 1,064 397 2,535 2,535 55,734 2,263,391 15,040 4a.1.5.11 Condensate Polishing Demineralizer 811 10 18 111 223 1,173 1,173 5,810 235,956 14,279 4a.1.5.12 Containment Combustible Gas Control 69 1

2 11 19 101 101 567 23,007 1,161 4a.1.5.13 Cycled Condensate Storage 480 11 21 131 144 788 788 6,857 278,483 8,725 4a.1.5.14 Drywell Instrument Nitrogen 59 1

2 12 17 90 90 613 24,892 1,048 4a.1.5.15 Extraction Steam 265 9

17 107 86 485 485 5,615 228,022 4,883 4a.1.5.16 Feedwater 457 24 45 277 165 968 968 14,520 589,682 8,412 4a.1.5.17 Feedwater Heater Vents & Drains 2,119 66 123 762 669 3,738 3,738 39,902 1,620,422 38,608 4a.1.5.18 Gland Steam 190 3

5 32 53 283 283 1,669 67,764 3,394 4a.1.5.19 HVAC-Machine Shop\\TB Sandblast 29 0

1 5

8 44 44 270 10,961 531 4a.1.5.20 HVAC-River\\Lake Screen House 21 3

24 24 422 4a.1.5.21 HVAC-Service Building 54 8

63 63 1,072 4a.1.5.22 Hydrogen & Carbon Dioxide 36 5

41 41 708 4a.1.5.23 Lake Makeup & Blowdown 214 32 246 246 4,257 4a.1.5.24 Main Steam 103 1

2 15 28 150 150 775 31,473 1,824 4a.1.5.25 Makeup Demineralizer 622 14 26 163 185 1,010 1,010 8,552 347,300 11,294 4a.1.5.26 Misc Bldgs Floor Drains 1,156 66 58 125 250 386 2,041 2,041 6,544 2,367 477,918 19,530 4a.1.5.27 Refrigeration 55 8

63 63 1,110 4a.1.5.28 Refrigeration - RCA 40 0

1 5

11 57 57 245 9,954 666 4a.1.5.29 Screen Wash 20 3

23 23 407 4a.1.5.30 Service Air 22 3

25 25 427 4a.1.5.31 Sewage Treatment 87 13 100 100 1,741 4a.1.5.32 Standby Gas Treatment 42 1

3 17 14 77 77 901 36,604 761 4a.1.5.33 Station Heat Recovery 581 18 31 195 181 1,007 1,007 10,223 415,159 10,039 4a.1.5.34 Switchgear Heat Removal 10 1

11 11 180 4a.1.5.35 Turbine Bldg Closed Cooling Water 415 14 25 157 133 744 744 8,238 334,542 7,401 4a.1.5.36 Turbine Building Equipment Drains 73 1

3 17 21 116 116 898 36,485 1,308 4a.1.5.37 Turbine Building Floor Drains 74 1

1 6

20 102 102 325 13,189 1,313 4a.1.5.38 Turbine Generator 212 10 19 115 74 431 431 6,046 245,513 3,970 4a.1.5.39 Turbine Oil 619 24 28 115 64 195 1,047 1,047 6,048 656 300,237 11,160 4a.1.5.40 Wastewater Treatment 129 19 148 148 2,499 4a.1.5 Totals 11,548 418 693 4,009 315 3,612 20,595 19,434 1,161 210,037 3,023 8,796,532 208,490 4a.1.6 Scaffolding in support of decommissioning 2,452 43 10 48 15 630 3,197 3,197 2,253 140 113,977 50,760 4a.1 Subtotal Period 4a Activity Costs 354 25,347 11,790 4,072 8,575 26,498 567 23,338 100,542 99,381 1,161 425,746 28,135 4,507 631 671 21,335,350 387,835 2,943 Period 4a Collateral Costs 4a.3.1 Process liquid waste 68 28 134 132 90 453 453 476 28,537 93 4a.3.2 Small tool allowance 324 49 372 335 37 4a.3 Subtotal Period 4a Collateral Costs 68 324 28 134 132 139 825 788 37 476 28,537 93 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 72 18 90 90 4a.4.2 Insurance 655 65 720 720 4a.4.3 Property taxes 776 78 854 768 85 4a.4.4 Health physics supplies 2,029 507 2,536 2,536 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 20 of 23 Table D-2 LaSalle County Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:43 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 4a Period-Dependent Costs (continued) 4a.4.5 Heavy equipment rental 2,593 389 2,982 2,982 4a.4.6 Disposal of DAW generated 18 7

371 96 491 491 6,643 132,865 30 4a.4.7 Plant energy budget 2,023 303 2,327 2,327 4a.4.8 NRC Fees 700 70 770 770 4a.4.9 Site O&M Costs 194 29 223 223 4a.4.10 Liquid Radwaste Processing Equipment/Services 595 89 684 684 4a.4.11 Security Staff Cost 3,157 474 3,630 3,630 84,629 4a.4.12 DOC Staff Cost 17,754 2,663 20,418 20,418 222,264 4a.4.13 Utility Staff Cost 29,351 4,403 33,754 33,754 396,608 4a.4 Subtotal Period 4a Period-Dependent Costs 72 4,621 18 7

371 55,206 9,184 69,479 69,394 85 6,643 132,865 30 703,501 4a.0 TOTAL PERIOD 4a COST 495 30,292 11,836 4,214 8,575 27,001 55,773 32,661 170,847 169,563 1,283 425,746 35,254 4,507 631 671 21,496,760 387,958 706,445 PERIOD 4b - Site Decontamination Period 4b Direct Decommissioning Activities 4b.1.1 Remove spent fuel racks 832 82 166 157 1,030 734 3,001 3,001 9,726 872,665 1,631 Disposal of Plant Systems 4b.1.2.1 Aux Diesel Bldg Floor Drains 8

1 9

9 147 4b.1.2.2 Auxiliary Diesel Generator 69 10 79 79 1,341 4b.1.2.3 Containment Monitoring 21 0

0 2

6 28 28 81 3,296 407 4b.1.2.4 Control Rod Drive 185 2

3 18 50 258 258 961 39,042 3,464 4b.1.2.5 Diesel Oil 58 9

67 67 1,104 4b.1.2.6 Domestic Water 25 4

29 29 499 4b.1.2.7 Domestic Water - RCA 39 0

1 5

11 56 56 263 10,694 653 4b.1.2.8 Electrical 518 78 596 596 9,872 4b.1.2.9 Electrical - Contaminated 749 10 18 114 208 1,099 1,099 5,977 242,742 13,169 4b.1.2.10 Electrical - RCA 5,152 94 168 1,047 1,480 7,941 7,941 54,830 2,226,676 87,927 4b.1.2.11 Fire Protection 214 32 246 246 4,263 4b.1.2.12 Fire Protection - RCA 1,033 22 39 244 303 1,641 1,641 12,787 519,289 17,581 4b.1.2.13 Fuel Pool Cooling & Cleanup 703 22 40 249 221 1,235 1,235 13,068 530,713 12,596 4b.1.2.14 HVAC-Auxiliary Building 261 7

12 76 79 434 434 3,972 161,301 4,427 4b.1.2.15 HVAC-Control Rm\\Aux Equip Area 38 6

44 44 729 4b.1.2.16 HVAC-Diesel Generator Room 14 2

16 16 284 4b.1.2.17 HVAC-Off Gas Building 61 3

5 30 21 119 119 1,548 62,855 1,100 4b.1.2.18 HVAC-Primary Containment 800 19 35 219 240 1,313 1,313 11,460 465,384 13,770 4b.1.2.19 HVAC-Radwaste Building 97 2

4 23 28 154 154 1,200 48,728 1,667 4b.1.2.20 HVAC-Turbine Building 731 15 28 177 215 1,166 1,166 9,260 376,037 11,966 4b.1.2.21 High Pressure Core Spray 268 27 34 127 87 115 657 657 6,654 818 343,590 4,869 4b.1.2.22 Instrument Air 7

1 9

9 152 4b.1.2.23 Instrument Air - RCA 142 1

2 13 38 197 197 681 27,654 2,514 4b.1.2.24 Low Pressure Core Spray 128 12 15 59 40 54 308 308 3,069 376 158,310 2,315 4b.1.2.25 Nuclear Boiler 1,271 95 112 354 359 487 2,677 2,677 18,553 3,390 1,057,552 23,399 4b.1.2.26 Off Gas 504 30 34 90 126 179 962 962 4,693 1,189 297,108 9,052 4b.1.2.27 Primary Containment Vent & Purge 395 18 33 208 137 791 791 10,887 442,119 7,350 4b.1.2.28 Process Radiation Monitoring 13 0

0 1

3 17 17 33 1,355 253 4b.1.2.29 Process Sampling 46 0

1 4

12 64 64 210 8,527 895 4b.1.2.30 Radioactive Waste Disposal 2,225 85 93 328 261 693 3,685 3,685 17,201 2,582 919,500 39,849 4b.1.2.31 Radwaste Area Floor Drains 2

0 0

0 0

0 2

2 5

1 256 31 4b.1.2.32 Reactor Bldg Closed Cooling Water 355 21 37 231 131 774 774 12,081 490,626 6,182 4b.1.2.33 Reactor Building Equipment Drains 57 2

2 6

6 17 91 91 330 61 18,672 1,038 4b.1.2.34 Reactor Building Floor Drains 6

0 0

0 0

2 8

8 17 2

897 108 4b.1.2.35 Reactor Core Isolation Cooling 178 7

8 21 28 57 300 300 1,099 269 68,725 3,218 4b.1.2.36 Reactor Recirculation 102 9

11 35 34 42 232 232 1,858 321 104,233 1,910 4b.1.2.37 Reactor Water Clean-up 675 23 19 31 92 202 1,042 1,042 1,618 874 144,057 11,928 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 21 of 23 Table D-2 LaSalle County Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:43 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Disposal of Plant Systems (continued) 4b.1.2.38 Residual Heat Removal 1,324 129 163 608 429 567 3,220 3,220 31,857 4,053 1,657,265 24,347 4b.1.2.39 Service Air - RCA 325 3

6 37 88 459 459 1,953 79,314 5,520 4b.1.2.40 Service Water 82 12 95 95 1,595 4b.1.2.41 Service Water - RCA 749 24 44 271 237 1,325 1,325 14,208 577,006 12,979 4b.1.2.42 Standby Liquid Control 42 0

1 6

12 60 60 291 11,832 702 4b.1.2.43 Well Water 91 14 104 104 1,732 4b.1.2 Totals 19,765 682 968 4,633 1,462 6,103 33,612 32,319 1,293 242,706 13,935 11,095,350 348,903 4b.1.3 Scaffolding in support of decommissioning 3,678 64 15 71 22 944 4,795 4,795 3,380 210 170,965 76,140 Decontamination of Site Buildings 4b.1.4.1 Reactor Building 2,568 3,065 310 339 238 1,092 2,441 10,052 10,052 12,446 16,298 2,086,382 99,025 4b.1.4.2 Auxiliary Building 1,250 543 44 54 275 66 831 3,062 3,062 14,385 856 665,655 31,725 4b.1.4.3 IRSF Building 69 18 3

4 1

9 42 146 146 26 174 18,472 1,537 4b.1.4.4 Service Building 95 19 4

5 1

13 57 194 194 34 243 25,654 2,032 4b.1.4.5 Solid Radwaste Building 423 297 12 14 19 32 300 1,097 1,097 984 574 96,903 12,864 4b.1.4.6 Turbine Building 1,528 630 77 88 98 208 1,009 3,638 3,638 5,149 3,826 585,724 38,151 4b.1.4 Totals 5,933 4,573 450 503 630 1,420 4,680 18,188 18,188 33,023 21,972 3,478,791 185,335 4b.1 Subtotal Period 4b Activity Costs 6,765 28,097 1,363 1,643 5,334 3,934 12,461 59,598 58,304 1,293 279,109 45,843 15,617,780 612,009 Period 4b Additional Costs 4b.2.1 License Termination Survey Planning 940 282 1,222 1,222 6,240 4b.2.2 ISFSI License Termination 57 1

38 153 749 171 1,168 1,168 2,905 244,104 3,498 1,280 4b.2.3 Soil Remediation 29 1

216 706 216 1,168 1,168 13,453 1,119,288 367 4b.2 Subtotal Period 4b Additional Costs 86 2

254 859 1,689 669 3,559 2,391 1,168 16,358 1,363,392 3,865 7,520 Period 4b Collateral Costs 4b.3.1 Process liquid waste 222 92 440 433 294 1,480 1,480 1,555 93,305 303 4b.3.2 Small tool allowance 515 77 592 592 4b.3.3 Decommissioning Equipment Disposition 114 31 127 40 45 356 356 6,000 373 303,507 88 4b.3 Subtotal Period 4b Collateral Costs 222 515 205 471 127 472 416 2,429 2,429 6,000 1,929 396,812 391 Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 1,511 378 1,889 1,889 4b.4.2 Insurance 935 94 1,029 1,029 4b.4.3 Property taxes 1,109 111 1,220 1,220 4b.4.4 Health physics supplies 3,118 779 3,897 3,897 4b.4.5 Heavy equipment rental 3,674 551 4,225 4,225 4b.4.6 Disposal of DAW generated 27 10 558 144 740 740 10,002 200,042 46 4b.4.7 Plant energy budget 2,282 342 2,624 2,624 4b.4.8 NRC Fees 1,000 100 1,100 1,100 4b.4.9 Site O&M Costs 277 42 319 319 4b.4.10 Liquid Radwaste Processing Equipment/Services 850 128 978 978 4b.4.11 Security Staff Cost 6,061 909 6,970 6,970 144,643 4b.4.12 DOC Staff Cost 24,954 3,743 28,697 28,697 310,114 4b.4.13 Utility Staff Cost 41,070 6,161 47,231 47,231 546,171 4b.4 Subtotal Period 4b Period-Dependent Costs 1,511 6,792 27 10 558 78,538 13,481 100,918 100,918 10,002 200,042 46 1,000,929 4b.0 TOTAL PERIOD 4b COST 8,498 35,490 1,598 2,378 5,461 5,823 80,227 27,027 166,503 164,041 1,168 1,293 285,109 74,131 17,578,020 616,312 1,008,449 PERIOD 4e - License Termination Period 4e Direct Decommissioning Activities 4e.1.1 ORISE confirmatory survey 151 45 197 197 4e.1.2 Terminate license a

TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 22 of 23 Table D-2 LaSalle County Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:43 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours 4e.1 Subtotal Period 4e Activity Costs 151 45 197 197 Period 4e Additional Costs 4e.2.1 License Termination Survey 11,748 3,524 15,272 15,272 217,865 3,120 4e.2 Subtotal Period 4e Additional Costs 11,748 3,524 15,272 15,272 217,865 3,120 Period 4e Collateral Costs 4e.3.1 DOC staff relocation expenses 1,130 169 1,299 1,299 4e.3 Subtotal Period 4e Collateral Costs 1,130 169 1,299 1,299 Period 4e Period-Dependent Costs 4e.4.1 Insurance 4e.4.2 Property taxes 382 38 420 420 4e.4.3 Health physics supplies 1,037 259 1,296 1,296 4e.4.4 Disposal of DAW generated 1

0 19 5

25 25 340 6,795 2

4e.4.5 Plant energy budget 210 31 241 241 4e.4.6 NRC Fees 360 36 396 396 4e.4.7 Site O&M Costs 95 14 110 110 4e.4.8 Security Staff Cost 528 79 607 607 11,957 4e.4.9 DOC Staff Cost 3,856 578 4,434 4,434 47,430 4e.4.10 Utility Staff Cost 4,617 693 5,310 5,310 57,793 4e.4 Subtotal Period 4e Period-Dependent Costs 1,037 1

0 19 10,048 1,734 12,839 12,839 340 6,795 2

117,180 4e.0 TOTAL PERIOD 4e COST 1,037 1

0 19 23,077 5,474 29,608 29,608 340 6,795 217,867 120,300 PERIOD 4 TOTALS 8,993 66,819 13,435 6,593 14,037 32,843 159,077 65,161 366,958 363,212 1,168 2,577 710,855 109,725 4,507 631 671 39,081,570 1,222,137 1,835,193 PERIOD 5b - Site Restoration Period 5b Direct Decommissioning Activities Demolition of Remaining Site Buildings 5b.1.1.1 Sewage Treatment Plant Upgrade 263 39 302 302 3,306 5b.1.1.2 Reactor Building 5,667 850 6,518 6,518 64,458 5b.1.1.3 Auxiliary Building 3,686 553 4,239 4,239 42,962 5b.1.1.4 Capital Improvements 2009 1,314 197 1,511 1,511 20,778 5b.1.1.5 Chemical Feed Building 32 5

36 36 482 5b.1.1.6 Diesel Generator Room 468 70 538 538 6,000 5b.1.1.7 Discharge Structure 20 3

23 23 190 5b.1.1.8 IRSF Building 691 104 794 794 8,924 5b.1.1.9 ISFSI Haul Path 651 98 748 748 9,520 5b.1.1.10 Lake Screen House 1,102 165 1,267 1,267 13,877 5b.1.1.11 Main Access Facility 390 58 448 448 5,396 5b.1.1.12 Miscellaneous Yard Structures 1,946 292 2,238 2,238 27,034 5b.1.1.13 New Service Building 1,840 276 2,116 2,116 23,587 5b.1.1.14 Outfall Structure 8

1 9

9 113 5b.1.1.15 River Screen House 330 50 380 380 4,230 5b.1.1.16 Security Modifications 677 102 778 778 3,834 5b.1.1.17 Service Building 1,534 230 1,764 1,764 21,582 5b.1.1.18 Sewage Treatment Plant 36 5

41 41 591 5b.1.1.19 Solid Radwaste Building 2,029 304 2,333 2,333 23,167 5b.1.1.20 Training Center 1,222 183 1,406 1,406 16,863 5b.1.1.21 Turbine Building 5,501 825 6,326 6,326 68,584 5b.1.1.22 Turbine Pedestal 2,102 315 2,418 2,418 22,592 5b.1.1.23 Wastewater Treatment Plant 59 9

68 68 911 5b.1.1 Totals 31,566 4,735 36,300 748 35,552 388,980 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix D, Page 23 of 23 Table D-2 LaSalle County Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 08:53:43 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Site Closeout Activities 5b.1.2 BackFill Site 522 78 600 600 1,485 5b.1.3 Grade & landscape site 149 22 171 171 499 5b.1.4 Final report to NRC 77 12 89 89 654 5b.1 Subtotal Period 5b Activity Costs 32,236 77 4,847 37,160 89 748 36,323 390,964 654 Period 5b Additional Costs 5b.2.1 Concrete Crushing 1,155 5

174 1,333 1,333 5,855 5b.2.2 ISFSI Demolition and Site Restoration 1,604 24 244 1,872 1,872 21,545 80 5b.2.3 Cofferdam Construction and Teardown 389 58 447 447 3,896 5b.2 Subtotal Period 5b Additional Costs 3,147 29 476 3,652 1,872 1,780 31,296 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 359 54 413 413 5b.3 Subtotal Period 5b Collateral Costs 359 54 413 413 Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property taxes 998 100 1,098 1,098 5b.4.3 Heavy equipment rental 4,728 709 5,437 5,437 5b.4.4 Plant energy budget 274 41 315 315 5b.4.5 Site O&M Cost 249 37 287 287 5b.4.6 Security Staff Cost 1,247 187 1,435 1,435 27,619 5b.4.7 DOC Staff Cost 9,384 1,408 10,792 10,792 110,391 5b.4.8 Utility Staff Cost 4,478 672 5,149 5,149 54,154 5b.4 Subtotal Period 5b Period-Dependent Costs 4,728 16,631 3,154 24,512 24,512 192,164 5b.0 TOTAL PERIOD 5b COST 40,470 16,737 8,531 65,738 89 2,621 63,029 422,260 192,898 PERIOD 5 TOTALS 40,470 16,737 8,531 65,738 89 2,621 63,029 422,260 192,898 TOTAL COST TO DECOMMISSION 18,560 112,517 13,587 7,243 14,037 33,834 395,204 111,238 706,219 515,918 124,292 66,009 710,855 118,403 4,507 631 671 39,346,160 1,784,936 4,328,734 TOTAL COST TO DECOMMISSION WITH 18.7% CONTINGENCY:

$706,219 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 73.05% OR:

$515,918 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 17.6% OR:

$124,292 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 9.35% OR:

$66,009 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

123,541 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

671 cubic feet TOTAL SCRAP METAL REMOVED:

67,666 tons TOTAL CRAFT LABOR REQUIREMENTS:

1,784,936 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.

LaSalle County Station Document E16-1555-012, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 1 of 25 TLG Services, Inc.

APPENDIX E DETAILED COST ANALYSIS SAFSTOR Page LaSalle County Station, Unit 1.....................................................................................E-2 LaSalle County Station, Unit 2..................................................................................E-14

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 2 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs 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 Activities 1a.1.1 SAFSTOR site characterization survey 398 119 517 517 1a.1.2 Prepare preliminary decommissioning cost 153 23 176 176 1,300 1a.1.3 Notification of Cessation of Operations a

1a.1.4 Remove fuel & source material n/a 1a.1.5 Notification of Permanent Defueling a

1a.1.6 Deactivate plant systems & process waste a

1a.1.7 Prepare and submit PSDAR 236 35 271 271 2,000 1a.1.8 Review plant dwgs & specs.

153 23 176 176 1,300 1a.1.9 Perform detailed rad survey a

1a.1.10 Estimate by-product inventory 118 18 136 136 1,000 1a.1.11 End product description 118 18 136 136 1,000 1a.1.12 Detailed by-product inventory 177 27 204 204 1,500 1a.1.13 Define major work sequence 118 18 136 136 1,000 1a.1.14 Perform SER and EA 366 55 421 421 3,100 1a.1.15 Perform Site-Specific Cost Study 590 89 679 679 5,000 Activity Specifications 1a.1.16.1 Prepare plant and facilities for SAFSTOR 581 87 668 668 4,920 1a.1.16.2 Plant systems 492 74 565 565 4,167 1a.1.16.3 Plant structures and buildings 368 55 423 423 3,120 1a.1.16.4 Waste management 236 35 271 271 2,000 1a.1.16.5 Facility and site dormancy 236 35 271 271 2,000 1a.1.16 Total 1,913 287 2,199 2,199 16,207 Detailed Work Procedures 1a.1.17.1 Plant systems 140 21 161 161 1,183 1a.1.17.2 Facility closeout & dormancy 142 21 163 163 1,200 1a.1.17 Total 281 42 323 323 2,383 1a.1.18 Procure vacuum drying system 12 2

14 14 100 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 4,633 755 5,388 5,388 35,890 Period 1a Additional Costs 1a.2.1 ISFSI Expansion 10,400 1,560 11,960 11,960 1a.2 Subtotal Period 1a Additional Costs 10,400 1,560 11,960 11,960 Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 9,000 1,350 10,350 10,350 1a.3 Subtotal Period 1a Collateral Costs 9,000 1,350 10,350 10,350 Period 1a Period-Dependent Costs 1a.4.1 Insurance 876 88 964 964 1a.4.2 Property taxes 1a.4.3 Health physics supplies 396 99 495 495 1a.4.4 Heavy equipment rental 396 59 455 455 1a.4.5 Disposal of DAW generated 2

1 34 9

45 45 610 12,190 3

1a.4.6 Plant energy budget 1,371 206 1,577 1,577 1a.4.7 NRC Fees 706 71 776 776 1a.4.8 Emergency Planning Fees 313 31 344 344 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 3 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 1a Period-Dependent Costs (continued) 1a.4.9 Site O&M Costs 125 19 144 144 1a.4.10 Spent Fuel Pool O&M 762 114 877 877 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 457 69 526 526 12,264 1a.4.13 Utility Staff Cost 31,082 4,662 35,745 35,745 423,400 1a.4 Subtotal Period 1a Period-Dependent Costs 792 2

1 34 35,736 5,433 41,997 40,726 1,271 610 12,190 3

435,664 1a.0 TOTAL PERIOD 1a COST 792 2

1 34 59,769 9,098 69,695 46,114 23,581 610 12,190 3

471,554 PERIOD 1b - SAFSTOR Limited DECON Activities Period 1b Direct Decommissioning Activities Decontamination of Site Buildings 1b.1.1.1 Reactor Building 2,820 1,410 4,230 4,230 49,197 1b.1.1.2 Auxiliary Building 311 155 466 466 5,731 1b.1.1.3 Off Gas Building 139 69 208 208 2,566 1b.1.1.4 Turbine Building 1,631 816 2,447 2,447 30,081 1b.1.1 Totals 4,901 2,450 7,351 7,351 87,576 1b.1 Subtotal Period 1b Activity Costs 4,901 2,450 7,351 7,351 87,576 Period 1b Collateral Costs 1b.3.1 Decon equipment 763 114 877 877 1b.3.2 Process liquid waste 167 67 322 317 218 1,090 1,090 1,137 68,232 222 1b.3.3 Small tool allowance 75 11 86 86 1b.3.4 Spent Fuel Capital and Transfer 3,000 450 3,450 3,450 1b.3 Subtotal Period 1b Collateral Costs 930 75 67 322 317 3,000 793 5,503 2,053 3,450 1,137 68,232 222 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 1,260 315 1,576 1,576 1b.4.2 Insurance 105 11 116 116 1b.4.3 Property taxes 1,155 116 1,271 1,271 1b.4.4 Health physics supplies 421 105 527 527 1b.4.5 Heavy equipment rental 99 15 113 113 1b.4.6 Disposal of DAW generated 2

1 48 12 63 63 857 17,148 4

1b.4.7 Plant energy budget 342 51 393 393 1b.4.8 NRC Fees 176 18 194 194 1b.4.9 Emergency Planning Fees 78 8

86 86 1b.4.10 Site O&M Costs 31 5

36 36 1b.4.11 Spent Fuel Pool O&M 190 29 219 219 1b.4.12 ISFSI Operating Costs 11 2

13 13 1b.4.13 Security Staff Cost 114 17 131 131 3,058 1b.4.14 Utility Staff Cost 7,749 1,162 8,912 8,912 105,560 1b.4 Subtotal Period 1b Period-Dependent Costs 1,260 520 2

1 48 9,951 1,865 13,647 13,330 317 857 17,148 4

108,618 1b.0 TOTAL PERIOD 1b COST 7,091 595 69 322 364 12,951 5,108 26,501 22,734 3,767 1,995 85,381 87,801 108,618 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 432 65 496 496 3,000 1c.1.2 Install containment pressure equal. lines 42 6

48 48 700 1c.1.3 Interim survey prior to dormancy 733 220 953 953 13,416 1c.1.4 Secure building accesses a

TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 4 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours 1c.1.5 Prepare & submit interim report 69 10 79 79 583 1c.1 Subtotal Period 1c Activity Costs 473 802 301 1,576 1,576 17,116 583 Period 1c Additional Costs 1c.2.1 Spent Fuel Pool Isolation 9,690 1,453 11,143 11,143 1c.2 Subtotal Period 1c Additional Costs 9,690 1,453 11,143 11,143 Period 1c Collateral Costs 1c.3.1 Process liquid waste 158 64 305 300 206 1,033 1,033 1,078 64,659 210 1c.3.2 Small tool allowance 4

1 4

4 1c.3.3 Spent Fuel Capital and Transfer 3,000 450 3,450 3,450 1c.3 Subtotal Period 1c Collateral Costs 158 4

64 305 300 3,000 657 4,487 1,037 3,450 1,078 64,659 210 Period 1c Period-Dependent Costs 1c.4.1 Insurance 105 11 116 116 1c.4.2 Property taxes 1,155 116 1,271 1,271 1c.4.3 Health physics supplies 139 35 173 173 1c.4.4 Heavy equipment rental 99 15 113 113 1c.4.5 Disposal of DAW generated 0

0 6

2 8

8 107 2,132 0

1c.4.6 Plant energy budget 342 51 393 393 1c.4.7 NRC Fees 176 18 194 194 1c.4.8 Emergency Planning Fees 78 8

86 86 1c.4.9 Site O&M Costs 31 5

36 36 1c.4.10 Spent Fuel Pool O&M 190 29 219 219 1c.4.11 ISFSI Operating Costs 11 2

13 13 1c.4.12 Security Staff Cost 114 17 131 131 3,058 1c.4.13 Utility Staff Cost 2,147 322 2,468 2,468 27,040 1c.4 Subtotal Period 1c Period-Dependent Costs 237 0

0 6

4,349 628 5,220 4,903 317 107 2,132 0

30,098 1c.0 TOTAL PERIOD 1c COST 158 714 64 305 306 17,840 3,039 22,426 18,659 3,767 1,184 66,791 17,326 30,681 PERIOD 1 TOTALS 7,249 2,101 135 628 704 90,561 17,244 118,622 87,507 31,115 3,788 164,362 105,130 610,852 PERIOD 2a - SAFSTOR Dormancy with Wet Spent Fuel Storage Period 2a Direct Decommissioning Activities 2a.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 136 20 156 156 2a.1.5 Maintenance supplies 503 126 629 629 2a.1 Subtotal Period 2a Activity Costs 639 146 785 785 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 33,000 4,950 37,950 37,950 2a.3 Subtotal Period 2a Collateral Costs 33,000 4,950 37,950 37,950 Period 2a Period-Dependent Costs 2a.4.1 Insurance 1,688 169 1,857 1,685 172 2a.4.2 Property taxes 5,892 589 6,481 2,202 4,279 2a.4.3 Health physics supplies 305 76 381 381 2a.4.4 Disposal of DAW generated 4

2 85 22 113 113 1,532 30,639 7

2a.4.5 Plant energy budget 1,098 165 1,263 632 632 2a.4.6 NRC Fees 807 81 888 888 2a.4.7 Emergency Planning Fees 400 40 440 440 2a.4.8 Site O&M Costs 500 75 575 575 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 5 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 2a Period-Dependent Costs (continued) 2a.4.9 Spent Fuel Pool O&M 3,054 458 3,512 3,512 2a.4.10 ISFSI Operating Costs 176 26 202 202 2a.4.11 Security Staff Cost 1,831 275 2,106 2,106 49,123 2a.4.12 Utility Staff Cost 9,440 1,416 10,856 6,138 4,718 121,137 2a.4 Subtotal Period 2a Period-Dependent Costs 305 4

2 85 24,886 3,392 28,675 12,614 16,061 1,532 30,639 7

170,260 2a.0 TOTAL PERIOD 2a COST 305 4

2 85 58,526 8,488 67,410 13,399 54,011 1,532 30,639 7

170,260 PERIOD 2b - SAFSTOR Dormancy with Dry Spent Fuel Storage Period 2b Direct Decommissioning Activities 2b.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 278 42 320 320 2b.1.5 Maintenance supplies 1,032 258 1,290 1,290 2b.1 Subtotal Period 2b Activity Costs 1,310 300 1,610 1,610 Period 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 9,000 1,350 10,350 10,350 2b.3 Subtotal Period 2b Collateral Costs 9,000 1,350 10,350 10,350 Period 2b Period-Dependent Costs 2b.4.1 Insurance 3,214 321 3,535 3,453 81 2b.4.2 Property taxes 4,103 410 4,513 4,513 2b.4.3 Health physics supplies 597 149 746 746 2b.4.4 Disposal of DAW generated 8

3 172 44 228 228 3,085 61,704 14 2b.4.5 Plant energy budget 1,126 169 1,295 1,295 2b.4.6 NRC Fees 1,655 165 1,820 1,820 2b.4.7 Emergency Planning Fees 821 82 903 903 2b.4.8 Site O&M Costs 1,026 154 1,180 1,180 2b.4.9 ISFSI Operating Costs 361 54 415 415 2b.4.10 Security Staff Cost 13,744 2,062 15,805 7,261 8,544 368,374 2b.4.11 Utility Staff Cost 10,621 1,593 12,215 12,215 152,761 2b.4 Subtotal Period 2b Period-Dependent Costs 597 8

3 172 36,669 5,204 42,653 20,496 22,158 3,085 61,704 14 521,135 2b.0 TOTAL PERIOD 2b COST 597 8

3 172 46,979 6,854 54,613 22,106 32,508 3,085 61,704 14 521,135 PERIOD 2c - SAFSTOR Dormancy without Spent Fuel Storage Period 2c Direct Decommissioning Activities 2c.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 1,342 201 1,543 1,543 2c.1.5 Maintenance supplies 4,980 1,245 6,226 6,226 2c.1 Subtotal Period 2c Activity Costs 6,322 1,446 7,769 7,769 Period 2c Period-Dependent Costs 2c.4.1 Insurance 15,149 1,515 16,664 16,664 2c.4.2 Property taxes 19,798 1,980 21,778 21,778 2c.4.3 Health physics supplies 2,875 719 3,593 3,593 2c.4.4 Disposal of DAW generated 41 16 830 214 1,100 1,100 14,880 297,592 68 2c.4.5 Plant energy budget 5,432 815 6,247 6,247 2c.4.6 NRC Fees 7,230 723 7,953 7,953 2c.4.7 Site O&M Costs 4,949 742 5,692 5,692 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 6 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 2c Period-Dependent Costs (continued) 2c.4.8 Security Staff Cost 30,469 4,570 35,040 35,040 619,800 2c.4.9 Utility Staff Cost 52,801 7,920 60,721 60,721 723,100 2c.4 Subtotal Period 2c Period-Dependent Costs 2,875 41 16 830 135,829 19,198 158,788 158,788 14,880 297,592 68 1,342,900 2c.0 TOTAL PERIOD 2c COST 2,875 41 16 830 142,151 20,644 166,557 166,557 14,880 297,592 68 1,342,900 PERIOD 2 TOTALS 3,776 53 20 1,088 247,655 35,987 288,580 202,062 86,518 19,497 389,935 89 2,034,296 PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy Period 3a Direct Decommissioning Activities 3a.1.1 Prepare preliminary decommissioning cost 153 23 176 176 1,300 3a.1.2 Review plant dwgs & specs.

543 81 624 624 4,600 3a.1.3 Perform detailed rad survey a

3a.1.4 End product description 118 18 136 136 1,000 3a.1.5 Detailed by-product inventory 153 23 176 176 1,300 3a.1.6 Define major work sequence 885 133 1,018 1,018 7,500 3a.1.7 Perform SER and EA 366 55 421 421 3,100 3a.1.8 Perform Site-Specific Cost Study 590 89 679 679 5,000 3a.1.9 Prepare/submit License Termination Plan 483 73 556 556 4,096 3a.1.10 Receive NRC approval of termination plan a

Activity Specifications 3a.1.11.1 Re-activate plant & temporary facilities 870 130 1,000 900 100 7,370 3a.1.11.2 Plant systems 492 74 565 509 57 4,167 3a.1.11.3 Reactor internals 838 126 964 964 7,100 3a.1.11.4 Reactor vessel 767 115 882 882 6,500 3a.1.11.5 Sacrificial shield 59 9

68 68 500 3a.1.11.6 Moisture separators/reheaters 118 18 136 136 1,000 3a.1.11.7 Reinforced concrete 189 28 217 109 109 1,600 3a.1.11.8 Main Turbine 246 37 283 283 2,088 3a.1.11.9 Main Condensers 246 37 283 283 2,088 3a.1.11.10 Pressure suppression structure 236 35 271 271 2,000 3a.1.11.11 Drywell 189 28 217 217 1,600 3a.1.11.12 Plant structures & buildings 368 55 423 212 212 3,120 3a.1.11.13 Waste management 543 81 624 624 4,600 3a.1.11.14 Facility & site closeout 106 16 122 61 61 900 3a.1.11 Total 5,267 790 6,057 5,519 538 44,633 Planning & Site Preparations 3a.1.12 Prepare dismantling sequence 283 42 326 326 2,400 3a.1.13 Plant prep. & temp. svces 2,800 420 3,220 3,220 3a.1.14 Design water clean-up system 165 25 190 190 1,400 3a.1.15 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,200 330 2,530 2,530 3a.1.16 Procure casks/liners & containers 145 22 167 167 1,230 3a.1 Subtotal Period 3a Activity Costs 14,153 2,123 16,276 15,738 538 77,559 Period 3a Period-Dependent Costs 3a.4.1 Insurance 382 38 421 421 3a.4.2 Property taxes 500 50 550 550 3a.4.3 Health physics supplies 346 87 433 433 3a.4.4 Heavy equipment rental 396 59 455 455 3a.4.5 Disposal of DAW generated 1

1 29 7

38 38 514 10,287 2

3a.4.6 Plant energy budget 1,371 206 1,577 1,577 3a.4.7 NRC Fees 249 25 274 274 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 7 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 3a Period-Dependent Costs (continued) 3a.4.8 Site O&M Costs 125 19 144 144 3a.4.9 Security Staff Cost 2,802 420 3,223 3,223 65,179 3a.4.10 Utility Staff Cost 19,293 2,894 22,187 22,187 258,629 3a.4 Subtotal Period 3a Period-Dependent Costs 742 1

1 29 24,722 3,805 29,300 29,300 514 10,287 2

323,807 3a.0 TOTAL PERIOD 3a COST 742 1

1 29 38,875 5,928 45,575 45,038 538 514 10,287 2

401,366 PERIOD 3b - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 559 84 642 578 64 4,733 3b.1.1.2 Reactor internals 472 71 543 543 4,000 3b.1.1.3 Remaining buildings 159 24 183 46 137 1,350 3b.1.1.4 CRD housings & NIs 118 18 136 136 1,000 3b.1.1.5 Incore instrumentation 118 18 136 136 1,000 3b.1.1.6 Removal primary containment 236 35 271 271 2,000 3b.1.1.7 Reactor vessel 428 64 493 493 3,630 3b.1.1.8 Facility closeout 142 21 163 81 81 1,200 3b.1.1.9 Sacrificial shield 142 21 163 163 1,200 3b.1.1.10 Reinforced concrete 118 18 136 68 68 1,000 3b.1.1.11 Main Turbine 245 37 282 282 2,080 3b.1.1.12 Main Condensers 246 37 283 283 2,088 3b.1.1.13 Moisture separators & reheaters 236 35 271 271 2,000 3b.1.1.14 Radwaste building 322 48 370 333 37 2,730 3b.1.1.15 Reactor building 322 48 370 333 37 2,730 3b.1.1 Total 3,864 580 4,443 4,018 425 32,741 3b.1 Subtotal Period 3b Activity Costs 3,864 580 4,443 4,018 425 32,741 Period 3b Additional Costs 3b.2.1 Site Characterization 6,086 1,826 7,912 7,912 29,730 10,672 3b.2 Subtotal Period 3b Additional Costs 6,086 1,826 7,912 7,912 29,730 10,672 Period 3b Collateral Costs 3b.3.1 Decon equipment 763 114 877 877 3b.3.2 DOC 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 763 1,100 1,130 449 3,442 3,442 Period 3b Period-Dependent Costs 3b.4.1 Decon supplies 23 6

29 29 3b.4.2 Insurance 211 21 232 232 3b.4.3 Property taxes 251 25 276 276 3b.4.4 Health physics supplies 191 48 239 239 3b.4.5 Heavy equipment rental 198 30 228 228 3b.4.6 Disposal of DAW generated 1

0 16 4

22 22 292 5,834 1

3b.4.7 Plant energy budget 687 103 790 790 3b.4.8 NRC Fees 125 12 137 137 3b.4.9 Site O&M Costs 63 9

72 72 3b.4.10 Security Staff Cost 1,405 211 1,616 1,616 32,679 3b.4.11 DOC Staff Cost 4,781 717 5,498 5,498 58,560 3b.4.12 Utility Staff Cost 9,673 1,451 11,124 11,124 129,669 3b.4 Subtotal Period 3b Period-Dependent Costs 23 390 1

0 16 17,196 2,638 20,264 20,264 292 5,834 1

220,907 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 8 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours 3b.0 TOTAL PERIOD 3b COST 786 1,490 1

0 16 28,275 5,492 36,060 35,635 425 292 5,834 29,731 264,320 PERIOD 3 TOTALS 786 2,232 2

1 45 67,150 11,420 81,636 80,673 963 806 16,121 29,734 665,686 PERIOD 4a - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Recirculation System Piping & Valves 21 77 18 11 26 99 62 315 315 503 503 116,652 1,846 4a.1.1.2 Recirculation Pumps & Motors 11 43 14 22 54 156 68 370 370 1,416 1,178 211,420 1,136 4a.1.1.3 CRDMs & NIs Removal 48 177 492 88 166 172 1,143 1,143 5,536 141,063 4,118 4a.1.1.4 Reactor Vessel Internals 168 2,076 4,559 1,306 7,062 227 6,672 22,070 22,070 2,128 1,753 652 452,885 26,158 1,178 4a.1.1.5 Vessel & Internals GTCC Disposal 11,118 1,668 12,786 12,786 671 109,910 4a.1.1.6 Reactor Vessel 4,397 1,485 481 1,769 227 4,707 13,065 13,065 17,632 1,799,953 26,158 1,178 4a.1.1 Totals 248 6,770 6,568 1,908 80 20,371 454 13,350 49,749 49,749 1,919 26,978 1,753 652 671 2,831,883 59,417 2,357 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 480 2,215 424 2,633 800 6,551 6,551 124,489 5,601,986 8,748 4a.1.3 Main Condensers 921 1,579 302 1,877 715 5,393 5,393 88,729 3,992,800 16,783 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor Building 983 147 1,130 1,130 11,163 4a.1.4.2 Auxiliary Building 408 61 469 469 4,733 4a.1.4.3 Off Gas Building 71 11 82 82 920 4a.1.4.4 Turbine Building 597 90 687 687 7,337 4a.1.4 Totals 2,059 309 2,368 2,368 24,153 Disposal of Plant Systems 4a.1.5.1 Auxiliary Steam 108 2

4 24 31 169 169 1,250 50,766 1,862 4a.1.5.2 CSCS Equipment Cooling 6

1 7

7 122 4a.1.5.3 Circulating Water 175 26 201 201 3,464 4a.1.5.4 Circulating Water - RCA 225 4

8 50 65 353 353 2,599 105,533 3,802 4a.1.5.5 Clean Condensate Storage 83 12 95 95 1,677 4a.1.5.6 Clean Condensate Storage - RCA 25 0

0 3

7 36 36 150 6,112 419 4a.1.5.7 Condensate 841 42 78 487 299 1,748 1,748 25,514 1,036,129 15,392 4a.1.5.8 Condensate Booster 867 94 174 1,082 415 2,632 2,632 56,706 2,302,853 16,068 4a.1.5.9 Condensate Polishing Demineralizer 819 10 18 111 225 1,182 1,182 5,808 235,877 14,440 4a.1.5.10 Containment Combustible Gas Control 85 1

2 13 24 124 124 671 27,268 1,436 4a.1.5.11 Cycled Condensate Storage 269 4

7 46 76 403 403 2,421 98,310 4,774 4a.1.5.12 Drywell Instrument Nitrogen 61 1

2 12 18 94 94 646 26,238 1,070 4a.1.5.13 Extraction Steam 322 11 20 125 103 582 582 6,547 265,890 5,933 4a.1.5.14 Feedwater 534 26 48 297 188 1,093 1,093 15,570 632,298 9,816 4a.1.5.15 Feedwater Heater Vents & Drains 2,557 74 137 854 795 4,418 4,418 44,739 1,816,866 46,568 4a.1.5.16 Gland Steam 229 3

6 36 64 338 338 1,878 76,265 4,100 4a.1.5.17 HVAC-River\\Lake Screen House 8

1 9

9 151 4a.1.5.18 HVAC-Service Building 12 2

14 14 221 4a.1.5.19 Hydrogen & Carbon Dioxide 110 2

4 23 32 171 171 1,214 49,318 1,878 4a.1.5.20 Main Steam 125 1

3 17 34 179 179 866 35,179 2,211 4a.1.5.21 Misc Bldgs Floor Drains 0

0 1

1 9

4a.1.5.22 Screen Wash 25 4

29 29 506 4a.1.5.23 Service Air 11 2

13 13 222 4a.1.5.24 Standby Gas Treatment 51 2

3 20 17 93 93 1,049 42,596 932 4a.1.5.25 Station Heat Recovery 252 4

6 40 70 373 373 2,104 85,433 4,310 4a.1.5.26 Switchgear Heat Removal 10 1

11 11 180 4a.1.5.27 Turbine Bldg Closed Cooling Water 471 14 26 164 148 823 823 8,615 349,869 8,388 4a.1.5.28 Turbine Building Equip Drains 87 2

3 20 25 137 137 1,035 42,020 1,562 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 9 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Disposal of Plant Systems (continued) 4a.1.5.29 Turbine Building Floor Drains 34 0

0 3

9 46 46 150 6,104 598 4a.1.5.30 Turbine Generator 178 9

17 103 63 370 370 5,416 219,950 3,324 4a.1.5.31 Turbine Oil 529 21 26 112 50 167 904 904 5,855 519 280,058 9,595 4a.1.5 Totals 9,111 327 594 3,642 50 2,925 16,649 16,269 380 190,804 519 7,790,930 165,027 4a.1.6 Scaffolding in support of decommissioning 2,111 39 9

43 14 543 2,758 2,758 2,054 128 103,876 43,646 4a.1 Subtotal Period 4a Activity Costs 248 21,451 10,728 3,237 8,275 20,434 454 18,642 83,468 83,089 380 407,994 27,624 1,753 652 671 20,321,470 317,774 2,357 Period 4a Collateral Costs 4a.3.1 Process liquid waste 25 12 56 56 36 185 185 200 11,978 39 4a.3.2 Small tool allowance 266 40 305 275 31 4a.3 Subtotal Period 4a Collateral Costs 25 266 12 56 56 76 491 460 31 200 11,978 39 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 58 15 73 73 4a.4.2 Insurance 528 53 580 580 4a.4.3 Property taxes 626 63 688 619 69 4a.4.4 Health physics supplies 1,656 414 2,069 2,069 4a.4.5 Heavy equipment rental 2,090 313 2,403 2,403 4a.4.6 Disposal of DAW generated 16 6

318 82 422 422 5,708 114,158 26 4a.4.7 Plant energy budget 1,631 245 1,875 1,875 4a.4.8 NRC Fees 824 82 906 906 4a.4.9 Site O&M Costs 156 23 180 180 4a.4.10 Liquid Radwaste Processing Equipment/Services 480 72 552 552 4a.4.11 Security Staff Cost 2,891 434 3,324 3,324 77,481 4a.4.12 DOC Staff Cost 14,402 2,160 16,563 16,563 179,875 4a.4.13 Utility Staff Cost 24,153 3,623 27,776 27,776 324,339 4a.4 Subtotal Period 4a Period-Dependent Costs 58 3,745 16 6

318 45,690 7,579 57,413 57,344 69 5,708 114,158 26 581,696 4a.0 TOTAL PERIOD 4a COST 332 25,462 10,755 3,299 8,275 20,808 46,144 26,296 141,371 140,892 479 407,994 33,532 1,753 652 671 20,447,610 317,839 584,052 PERIOD 4b - Site Decontamination Period 4b Direct Decommissioning Activities 4b.1.1 Remove spent fuel racks 832 82 166 157 1,030 734 3,001 3,001 9,726 872,665 1,631 Disposal of Plant Systems 4b.1.2.1 Aux Diesel Bldg Floor Drains 4

1 5

5 86 4b.1.2.2 Auxiliary Diesel Generator 52 8

59 59 1,006 4b.1.2.3 Containment Monitoring 20 0

0 1

5 27 27 78 3,169 392 4b.1.2.4 Control Rod Drive 194 2

3 19 52 270 270 1,006 40,845 3,622 4b.1.2.5 Diesel Oil 43 6

50 50 823 4b.1.2.6 Electrical 273 41 314 314 5,201 4b.1.2.7 Electrical - Contaminated 676 9

17 105 188 995 995 5,509 223,712 11,889 4b.1.2.8 Electrical - RCA 4,641 86 155 962 1,337 7,182 7,182 50,427 2,047,847 79,254 4b.1.2.9 Fire Protection 116 17 134 134 2,339 4b.1.2.10 Fire Protection - RCA 664 13 23 143 192 1,035 1,035 7,493 304,287 11,294 4b.1.2.11 Fuel Pool Cooling & Cleanup 732 22 41 254 229 1,279 1,279 13,307 540,403 13,138 4b.1.2.12 HVAC-Auxiliary Building 198 5

9 55 60 326 326 2,889 117,333 3,260 4b.1.2.13 HVAC-Diesel Generator Room 7

1 8

8 127 4b.1.2.14 HVAC-Off Gas Building 20 0

1 5

6 31 31 237 9,643 326 4b.1.2.15 HVAC-Primary Containment 865 19 36 225 257 1,403 1,403 11,773 478,116 14,924 4b.1.2.16 HVAC-Radwaste Building 5

0 0

2 2

10 10 110 4,453 97 4b.1.2.17 HVAC-Turbine Building 731 15 28 177 215 1,166 1,166 9,260 376,037 11,966 4b.1.2.18 High Pressure Core Spray 316 29 36 134 94 131 739 739 7,014 889 364,579 5,729 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 10 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Disposal of Plant Systems (continued) 4b.1.2.19 Instrument Air 5

1 5

5 94 4b.1.2.20 Instrument Air - RCA 134 1

2 12 36 185 185 629 25,528 2,372 4b.1.2.21 Low Pressure Core Spray 151 13 17 62 43 62 347 347 3,225 410 167,703 2,731 4b.1.2.22 Nuclear Boiler 1,533 109 129 409 415 579 3,174 3,174 21,452 3,922 1,222,966 28,205 4b.1.2.23 Off Gas 598 34 37 101 139 209 1,118 1,118 5,271 1,319 332,284 10,737 4b.1.2.24 Primary Containment Vent & Purge 406 19 35 219 142 821 821 11,470 465,819 7,544 4b.1.2.25 Process Radiation Monitoring 20 0

0 1

5 26 26 42 1,697 393 4b.1.2.26 Process Sampling 27 0

0 2

7 36 36 90 3,660 528 4b.1.2.27 Radioactive Waste Disposal 1,459 54 57 189 174 450 2,383 2,383 9,882 1,711 548,907 26,040 4b.1.2.28 Reactor Bldg Closed Cooling Water 339 21 37 230 127 753 753 12,027 488,418 5,945 4b.1.2.29 Reactor Building Equipment Drains 64 2

2 7

7 19 101 101 344 68 19,878 1,152 4b.1.2.30 Reactor Building Floor Drains 6

0 0

0 0

2 8

8 17 2

897 108 4b.1.2.31 Reactor Core Isolation Cooling 214 8

9 24 33 67 354 354 1,237 309 77,945 3,847 4b.1.2.32 Reactor Recirculation 40 1

1 2

3 11 57 57 103 26 6,479 732 4b.1.2.33 Reactor Water Clean-up 831 28 23 37 110 247 1,276 1,276 1,958 1,041 172,819 14,701 4b.1.2.34 Residual Heat Removal 1,546 135 171 633 456 635 3,575 3,575 33,146 4,305 1,732,275 28,360 4b.1.2.35 Service Air - RCA 234 2

4 25 63 328 328 1,326 53,837 3,994 4b.1.2.36 Service Water 48 7

55 55 938 4b.1.2.37 Service Water - RCA 683 22 40 247 216 1,208 1,208 12,930 525,074 11,877 4b.1.2.38 Standby Liquid Control 51 1

1 7

14 73 73 341 13,830 854 4b.1.2 Totals 17,944 651 915 4,287 1,475 5,645 30,917 30,286 631 224,591 14,002 10,370,440 316,624 4b.1.3 Scaffolding in support of decommissioning 3,166 58 14 65 20 814 4,138 4,138 3,080 192 155,814 65,468 Decontamination of Site Buildings 4b.1.4.1 Reactor Building 2,568 3,069 300 338 239 838 2,377 9,729 9,729 12,516 15,511 2,051,621 99,078 4b.1.4.2 Auxiliary Building 287 56 8

9 2

24 166 553 553 100 459 49,865 6,152 4b.1.4.3 Off Gas Building 129 28 6

7 1

17 78 266 266 46 326 34,435 2,805 4b.1.4.4 Turbine Building 1,521 629 77 88 98 207 1,005 3,624 3,624 5,149 3,809 584,008 38,010 4b.1.4 Totals 4,506 3,783 391 442 340 1,086 3,626 14,173 14,173 17,812 20,105 2,719,928 146,046 4b.1 Subtotal Period 4b Activity Costs 5,338 24,975 1,266 1,527 4,692 3,611 10,820 52,228 51,597 631 245,483 44,025 14,118,850 529,770 Period 4b Additional Costs 4b.2.1 License Termination Survey Planning 940 282 1,222 1,222 6,240 4b.2.2 ISFSI License Termination 57 1

38 153 749 171 1,168 1,168 2,905 244,104 3,498 1,280 4b.2 Subtotal Period 4b Additional Costs 57 1

38 153 1,689 453 2,391 1,222 1,168 2,905 244,104 3,498 7,520 Period 4b Collateral Costs 4b.3.1 Process liquid waste 85 40 192 189 123 629 629 679 40,768 132 4b.3.2 Small tool allowance 445 67 511 511 4b.3.3 Decommissioning Equipment Disposition 114 31 127 40 45 356 356 6,000 373 303,507 88 4b.3 Subtotal Period 4b Collateral Costs 85 445 154 223 127 229 234 1,496 1,496 6,000 1,053 344,275 221 Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 1,352 338 1,690 1,690 4b.4.2 Insurance 935 94 1,029 1,029 4b.4.3 Property taxes 1,109 111 1,220 1,220 4b.4.4 Health physics supplies 2,738 684 3,422 3,422 4b.4.5 Heavy equipment rental 3,674 551 4,225 4,225 4b.4.6 Disposal of DAW generated 24 9

495 128 657 657 8,878 177,563 41 4b.4.7 Plant energy budget 2,282 342 2,624 2,624 4b.4.8 NRC Fees 1,461 146 1,607 1,607 4b.4.9 Site O&M Costs 277 42 319 319 4b.4.10 Liquid Radwaste Processing Equipment/Services 850 128 978 978 4b.4.11 Security Staff Cost 950 142 1,092 1,092 25,457 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 11 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 4b Period-Dependent Costs (continued) 4b.4.12 DOC Staff Cost 16,451 2,468 18,919 18,919 217,543 4b.4.13 Utility Staff Cost 27,655 4,148 31,803 31,803 388,800 4b.4 Subtotal Period 4b Period-Dependent Costs 1,352 6,412 24 9

495 51,969 9,321 69,584 69,584 8,878 177,563 41 631,800 4b.0 TOTAL PERIOD 4b COST 6,775 31,888 1,445 1,798 4,819 4,488 53,658 20,828 125,699 123,899 1,168 631 251,483 56,861 14,884,790 533,529 639,320 PERIOD 4d - Delay before License Termination Period 4d Direct Decommissioning Activities Period 4d Period-Dependent Costs 4d.4.1 Insurance 4d.4.2 Property taxes 482 48 530 530 4d.4.3 Health physics supplies 69 17 86 86 4d.4.4 Disposal of DAW generated 0

0 5

1 7

7 96 1,923 0

4d.4.5 Plant energy budget 4d.4.6 NRC Fees 176 18 194 194 4d.4.7 Site O&M Costs 120 18 139 139 4d.4.8 Utility Staff Cost 991 149 1,140 1,140 14,080 4d.4 Subtotal Period 4d Period-Dependent Costs 69 0

0 5

1,769 251 2,095 2,095 96 1,923 0

14,080 4d.0 TOTAL PERIOD 4d COST 69 0

0 5

1,769 251 2,095 2,095 96 1,923 0

14,080 PERIOD 4e - License Termination Period 4e Direct Decommissioning Activities 4e.1.1 ORISE confirmatory survey 151 45 197 197 4e.1.2 Terminate license a

4e.1 Subtotal Period 4e Activity Costs 151 45 197 197 Period 4e Additional Costs 4e.2.1 License Termination Survey 10,410 3,123 13,533 13,533 191,885 3,120 4e.2 Subtotal Period 4e Additional Costs 10,410 3,123 13,533 13,533 191,885 3,120 Period 4e Collateral Costs 4e.3.1 DOC staff relocation expenses 1,130 169 1,299 1,299 4e.3 Subtotal Period 4e Collateral Costs 1,130 169 1,299 1,299 Period 4e Period-Dependent Costs 4e.4.1 Insurance 4e.4.2 Property taxes 382 38 420 420 4e.4.3 Health physics supplies 942 235 1,177 1,177 4e.4.4 Disposal of DAW generated 1

0 19 5

25 25 340 6,795 2

4e.4.5 Plant energy budget 210 31 241 241 4e.4.6 NRC Fees 539 54 593 593 4e.4.7 Site O&M Costs 95 14 110 110 4e.4.8 Security Staff Cost 540 81 620 620 11,957 4e.4.9 DOC Staff Cost 3,856 578 4,434 4,434 47,430 4e.4.10 Utility Staff Cost 4,617 693 5,310 5,310 57,793 4e.4 Subtotal Period 4e Period-Dependent Costs 942 1

0 19 10,239 1,730 12,931 12,931 340 6,795 2

117,180 4e.0 TOTAL PERIOD 4e COST 942 1

0 19 21,931 5,068 27,960 27,960 340 6,795 191,887 120,300 PERIOD 4 TOTALS 7,107 58,360 12,201 5,097 13,094 25,320 123,502 52,444 297,126 294,847 1,168 1,110 659,477 90,829 1,753 652 671 35,341,120 1,043,256 1,357,752 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 12 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours PERIOD 5b - Site Restoration Period 5b Direct Decommissioning Activities Demolition of Remaining Site Buildings 5b.1.1.1 Reactor Building 5,664 850 6,514 6,514 64,472 5b.1.1.2 Auxiliary Building 3,692 554 4,246 4,246 43,048 5b.1.1.3 Diesel Generator Room 468 70 538 538 6,000 5b.1.1.4 Off Gas Building 648 97 745 745 8,484 5b.1.1.5 Turbine Building 5,501 825 6,326 6,326 68,584 5b.1.1.6 Turbine Pedestal 2,881 432 3,313 3,313 30,829 5b.1.1 Totals 18,854 2,828 21,682 21,682 221,416 Site Closeout Activities 5b.1.2 Grade & landscape site 149 22 171 171 499 5b.1.3 Final report to NRC 184 28 212 212 1,560 5b.1 Subtotal Period 5b Activity Costs 19,003 184 2,878 22,065 212 21,853 221,916 1,560 Period 5b Additional Costs 5b.2.1 Concrete Crushing 776 4

117 897 897 3,936 5b.2.2 ISFSI Demolition and Site Restoration 1,604 24 244 1,872 1,872 21,545 80 5b.2 Subtotal Period 5b Additional Costs 2,380 28 361 2,769 1,872 897 25,481 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 212 32 244 244 5b.3 Subtotal Period 5b Collateral Costs 212 32 244 244 Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property taxes 998 100 1,098 1,098 5b.4.3 Heavy equipment rental 4,728 709 5,437 5,437 5b.4.4 Plant energy budget 274 41 315 315 5b.4.5 Site O&M Cost 249 37 287 287 5b.4.6 Security Staff Cost 1,274 191 1,465 1,465 27,619 5b.4.7 DOC Staff Cost 9,384 1,408 10,792 10,792 110,391 5b.4.8 Utility Staff Cost 4,478 672 5,149 5,149 54,154 5b.4 Subtotal Period 5b Period-Dependent Costs 4,728 16,657 3,158 24,542 24,542 192,164 5b.0 TOTAL PERIOD 5b COST 26,322 16,869 6,429 49,620 212 1,872 47,536 247,397 193,804 PERIOD 5 TOTALS 26,322 16,869 6,429 49,620 212 1,872 47,536 247,397 193,804 TOTAL COST TO DECOMMISSION 15,142 92,792 12,392 5,746 13,094 27,157 545,737 123,523 835,583 665,300 120,674 49,609 659,477 114,920 1,753 652 671 35,911,540 1,425,606 4,862,391 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 13 of 25 Table E-1 LaSalle County Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:08:41 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours TOTAL COST TO DECOMMISSION WITH 17.35% CONTINGENCY:

$835,583 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 79.62% OR:

$665,300 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 14.44% OR:

$120,674 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 5.94% OR:

$49,609 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

117,325 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

671 cubic feet TOTAL SCRAP METAL REMOVED:

51,885 tons TOTAL CRAFT LABOR REQUIREMENTS:

1,425,606 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.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 14 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs 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 Activities 1a.1.1 SAFSTOR site characterization survey 398 119 517 517 1a.1.2 Prepare preliminary decommissioning cost 64 10 74 74 545 1a.1.3 Notification of Cessation of Operations a

1a.1.4 Remove fuel & source material n/a 1a.1.5 Notification of Permanent Defueling a

1a.1.6 Deactivate plant systems & process waste a

1a.1.7 Prepare and submit PSDAR 99 15 114 114 838 1a.1.8 Review plant dwgs & specs.

64 10 74 74 545 1a.1.9 Perform detailed rad survey a

1a.1.10 Estimate by-product inventory 49 7

57 57 419 1a.1.11 End product description 49 7

57 57 419 1a.1.12 Detailed by-product inventory 74 11 85 85 629 1a.1.13 Define major work sequence 49 7

57 57 419 1a.1.14 Perform SER and EA 153 23 176 176 1,299 1a.1.15 Perform Site-Specific Cost Study 247 37 284 284 2,095 Activity Specifications 1a.1.16.1 Prepare plant and facilities for SAFSTOR 243 36 280 280 2,061 1a.1.16.2 Plant systems 206 31 237 237 1,746 1a.1.16.3 Plant structures and buildings 154 23 177 177 1,307 1a.1.16.4 Waste management 99 15 114 114 838 1a.1.16.5 Facility and site dormancy 99 15 114 114 838 1a.1.16 Total 801 120 922 922 6,791 Detailed Work Procedures 1a.1.17.1 Plant systems 59 9

67 67 496 1a.1.17.2 Facility closeout & dormancy 59 9

68 68 503 1a.1.17 Total 118 18 136 136 999 1a.1.18 Procure vacuum drying system 5

1 6

6 42 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 2,172 386 2,558 2,558 15,038 Period 1a Additional Costs 1a.2.1 ISFSI Expansion 10,400 1,560 11,960 11,960 1a.2 Subtotal Period 1a Additional Costs 10,400 1,560 11,960 11,960 Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 9,000 1,350 10,350 10,350 1a.3 Subtotal Period 1a Collateral Costs 9,000 1,350 10,350 10,350 Period 1a Period-Dependent Costs 1a.4.1 Insurance 876 88 964 964 1a.4.2 Property taxes 1a.4.3 Health physics supplies 396 99 495 495 1a.4.4 Heavy equipment rental 396 59 455 455 1a.4.5 Disposal of DAW generated 2

1 34 9

45 45 610 12,190 3

1a.4.6 Plant energy budget 1,371 206 1,577 1,577 1a.4.7 NRC Fees 471 47 518 518 1a.4.8 Emergency Planning Fees 313 31 344 344 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 15 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 1a Period-Dependent Costs (continued) 1a.4.9 Site O&M Costs 125 19 144 144 1a.4.10 Spent Fuel Pool O&M 762 114 877 877 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 6,245 937 7,182 7,182 157,471 1a.4.13 Utility Staff Cost 31,082 4,662 35,745 35,745 423,400 1a.4 Subtotal Period 1a Period-Dependent Costs 792 2

1 34 41,289 6,278 48,395 47,124 1,271 610 12,190 3

580,871 1a.0 TOTAL PERIOD 1a COST 792 2

1 34 62,862 9,573 73,263 49,682 23,581 610 12,190 3

595,909 PERIOD 1b - SAFSTOR Limited DECON Activities Period 1b Direct Decommissioning Activities Decontamination of Site Buildings 1b.1.1.1 Reactor Building 2,820 1,410 4,230 4,230 49,197 1b.1.1.2 Auxiliary Building 1,385 692 2,077 2,077 24,021 1b.1.1.3 IRSF Building 67 33 100 100 1,210 1b.1.1.4 Service Building 92 46 139 139 1,692 1b.1.1.5 Solid Radwaste Building 417 208 625 625 7,355 1b.1.1.6 Turbine Building 1,484 742 2,227 2,227 27,018 1b.1.1 Totals 6,265 3,132 9,397 9,397 110,493 1b.1 Subtotal Period 1b Activity Costs 6,265 3,132 9,397 9,397 110,493 Period 1b Collateral Costs 1b.3.1 Decon equipment 763 114 877 877 1b.3.2 Process liquid waste 176 71 339 334 229 1,148 1,148 1,198 71,877 234 1b.3.3 Small tool allowance 96 14 111 111 1b.3.4 Spent Fuel Capital and Transfer 3,000 450 3,450 3,450 1b.3 Subtotal Period 1b Collateral Costs 939 96 71 339 334 3,000 808 5,586 2,136 3,450 1,198 71,877 234 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 1,420 355 1,774 1,774 1b.4.2 Insurance 105 11 116 116 1b.4.3 Property taxes 1,155 116 1,271 1,271 1b.4.4 Health physics supplies 505 126 632 632 1b.4.5 Heavy equipment rental 99 15 113 113 1b.4.6 Disposal of DAW generated 2

1 49 13 65 65 876 17,516 4

1b.4.7 Plant energy budget 342 51 393 393 1b.4.8 NRC Fees 117 12 129 129 1b.4.9 Emergency Planning Fees 78 8

86 86 1b.4.10 Site O&M Costs 31 5

36 36 1b.4.11 Spent Fuel Pool O&M 190 29 219 219 1b.4.12 ISFSI Operating Costs 11 2

13 13 1b.4.13 Security Staff Cost 1,557 234 1,791 1,791 39,260 1b.4.14 Utility Staff Cost 7,749 1,162 8,912 8,912 105,560 1b.4 Subtotal Period 1b Period-Dependent Costs 1,420 604 2

1 49 11,336 2,136 15,548 15,231 317 876 17,516 4

144,820 1b.0 TOTAL PERIOD 1b COST 8,623 700 73 340 382 14,336 6,077 30,531 26,764 3,767 2,074 89,394 110,731 144,820 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 432 65 496 496 3,000 1c.1.2 Install containment pressure equal. lines 42 6

48 48 700 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 16 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours 1c.1.3 Interim survey prior to dormancy 733 220 953 953 13,416 1c.1.4 Secure building accesses a

1c.1.5 Prepare & submit interim report 29 4

33 33 244 1c.1 Subtotal Period 1c Activity Costs 473 762 295 1,530 1,530 17,116 244 Period 1c Additional Costs 1c.2.1 Spent Fuel Pool Isolation 6,460 969 7,429 7,429 1c.2 Subtotal Period 1c Additional Costs 6,460 969 7,429 7,429 Period 1c Collateral Costs 1c.3.1 Process liquid waste 158 64 305 300 206 1,033 1,033 1,078 64,659 210 1c.3.2 Small tool allowance 4

1 4

4 1c.3.3 Spent Fuel Capital and Transfer 3,000 450 3,450 3,450 1c.3 Subtotal Period 1c Collateral Costs 158 4

64 305 300 3,000 657 4,487 1,037 3,450 1,078 64,659 210 Period 1c Period-Dependent Costs 1c.4.1 Insurance 105 11 116 116 1c.4.2 Property taxes 1,155 116 1,271 1,271 1c.4.3 Health physics supplies 139 35 173 173 1c.4.4 Heavy equipment rental 99 15 113 113 1c.4.5 Disposal of DAW generated 0

0 6

2 8

8 107 2,132 0

1c.4.6 Plant energy budget 342 51 393 393 1c.4.7 NRC Fees 117 12 129 129 1c.4.8 Emergency Planning Fees 78 8

86 86 1c.4.9 Site O&M Costs 31 5

36 36 1c.4.10 Spent Fuel Pool O&M 190 29 219 219 1c.4.11 ISFSI Operating Costs 11 2

13 13 1c.4.12 Security Staff Cost 1,557 234 1,791 1,791 39,260 1c.4.13 Utility Staff Cost 2,147 322 2,468 2,468 27,040 1c.4 Subtotal Period 1c Period-Dependent Costs 237 0

0 6

5,733 838 6,815 6,498 317 107 2,132 0

66,300 1c.0 TOTAL PERIOD 1c COST 158 714 64 305 306 15,955 2,759 20,261 16,494 3,767 1,184 66,791 17,326 66,544 PERIOD 1 TOTALS 8,781 2,207 138 645 722 93,152 18,409 124,055 92,940 31,115 3,868 168,375 128,060 807,274 PERIOD 2a - SAFSTOR Dormancy with Wet Spent Fuel Storage Period 2a Direct Decommissioning Activities 2a.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 604 91 694 694 2a.1.5 Maintenance supplies 504 126 630 630 2a.1 Subtotal Period 2a Activity Costs 1,108 217 1,324 1,324 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 38,000 5,700 43,700 43,700 2a.3 Subtotal Period 2a Collateral Costs 38,000 5,700 43,700 43,700 Period 2a Period-Dependent Costs 2a.4.1 Insurance 1,689 169 1,858 1,686 172 2a.4.2 Property taxes 5,893 589 6,482 2,203 4,279 2a.4.3 Health physics supplies 305 76 382 382 2a.4.4 Disposal of DAW generated 4

2 86 22 113 113 1,533 30,660 7

2a.4.5 Plant energy budget 1,099 165 1,264 632 632 2a.4.6 NRC Fees 716 72 788 788 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 17 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 2a Period-Dependent Costs (continued) 2a.4.7 Emergency Planning Fees 401 40 441 441 2a.4.8 Site O&M Costs 501 75 576 576 2a.4.9 Spent Fuel Pool O&M 3,056 458 3,514 3,514 2a.4.10 ISFSI Operating Costs 176 26 203 203 2a.4.11 Security Staff Cost 18,093 2,714 20,807 3,545 17,262 445,170 2a.4.12 Utility Staff Cost 9,447 1,417 10,864 2,512 8,352 121,220 2a.4 Subtotal Period 2a Period-Dependent Costs 305 4

2 86 41,070 5,824 47,291 12,436 34,854 1,533 30,660 7

566,390 2a.0 TOTAL PERIOD 2a COST 305 4

2 86 80,178 11,740 92,315 13,760 78,554 1,533 30,660 7

566,390 PERIOD 2b - SAFSTOR Dormancy with Dry Spent Fuel Storage Period 2b Direct Decommissioning Activities 2b.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 985 148 1,133 1,133 2b.1.5 Maintenance supplies 822 206 1,028 1,028 2b.1 Subtotal Period 2b Activity Costs 1,808 353 2,161 2,161 Period 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 9,000 1,350 10,350 10,350 2b.3 Subtotal Period 2b Collateral Costs 9,000 1,350 10,350 10,350 Period 2b Period-Dependent Costs 2b.4.1 Insurance 2,561 256 2,817 2,752 65 2b.4.2 Property taxes 3,269 327 3,596 3,596 2b.4.3 Health physics supplies 455 114 569 569 2b.4.4 Disposal of DAW generated 7

3 135 35 179 179 2,420 48,390 11 2b.4.5 Plant energy budget 897 135 1,031 1,031 2b.4.6 NRC Fees 1,169 117 1,286 1,286 2b.4.7 Emergency Planning Fees 654 65 719 719 2b.4.8 Site O&M Costs 817 123 940 940 2b.4.9 ISFSI Operating Costs 288 43 331 331 2b.4.10 Utility Staff Cost 3,565 535 4,100 4,100 54,583 2b.4 Subtotal Period 2b Period-Dependent Costs 455 7

3 135 13,220 1,749 15,568 14,453 1,115 2,420 48,390 11 54,583 2b.0 TOTAL PERIOD 2b COST 455 7

3 135 24,027 3,452 28,079 16,614 11,465 2,420 48,390 11 54,583 PERIOD 2c - SAFSTOR Dormancy without Spent Fuel Storage Period 2c Direct Decommissioning Activities 2c.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 6,112 917 7,028 7,028 2c.1.5 Maintenance supplies 5,101 1,275 6,376 6,376 2c.1 Subtotal Period 2c Activity Costs 11,212 2,192 13,404 13,404 Period 2c Period-Dependent Costs 2c.4.1 Insurance 15,515 1,551 17,066 17,066 2c.4.2 Property taxes 20,276 2,028 22,303 22,303 2c.4.3 Health physics supplies 2,822 706 3,528 3,528 2c.4.4 Disposal of DAW generated 41 16 837 216 1,110 1,110 15,007 300,130 69 2c.4.5 Plant energy budget 5,563 834 6,398 6,398 2c.4.6 NRC Fees 6,922 692 7,614 7,614 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 18 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 2c Period-Dependent Costs (continued) 2c.4.7 Site O&M Costs 5,069 760 5,829 5,829 2c.4.8 Security Staff Cost 31,205 4,681 35,885 35,885 634,757 2c.4.9 Utility Staff Cost 22,113 3,317 25,430 25,430 338,537 2c.4 Subtotal Period 2c Period-Dependent Costs 2,822 41 16 837 106,662 14,785 125,163 125,163 15,007 300,130 69 973,294 2c.0 TOTAL PERIOD 2c COST 2,822 41 16 837 117,874 16,977 138,568 138,568 15,007 300,130 69 973,294 PERIOD 2 TOTALS 3,583 52 20 1,058 222,079 32,170 258,961 168,942 90,019 18,959 379,181 87 1,594,267 PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy Period 3a Direct Decommissioning Activities 3a.1.1 Prepare preliminary decommissioning cost 64 10 74 74 545 3a.1.2 Review plant dwgs & specs.

227 34 262 262 1,927 3a.1.3 Perform detailed rad survey a

3a.1.4 End product description 49 7

57 57 419 3a.1.5 Detailed by-product inventory 64 10 74 74 545 3a.1.6 Define major work sequence 371 56 426 426 3,143 3a.1.7 Perform SER and EA 153 23 176 176 1,299 3a.1.8 Perform Site-Specific Cost Study 247 37 284 284 2,095 3a.1.9 Prepare/submit License Termination Plan 203 30 233 233 1,716 3a.1.10 Receive NRC approval of termination plan a

Activity Specifications 3a.1.11.1 Re-activate plant & temporary facilities 364 55 419 377 42 3,088 3a.1.11.2 Plant systems 206 31 237 213 24 1,746 3a.1.11.3 Reactor internals 351 53 404 404 2,975 3a.1.11.4 Reactor vessel 321 48 370 370 2,724 3a.1.11.5 Sacrificial shield 25 4

28 28 210 3a.1.11.6 Moisture separators/reheaters 49 7

57 57 419 3a.1.11.7 Reinforced concrete 79 12 91 45 45 670 3a.1.11.8 Main Turbine 103 15 119 119 875 3a.1.11.9 Main Condensers 103 15 119 119 875 3a.1.11.10 Pressure suppression structure 99 15 114 114 838 3a.1.11.11 Drywell 79 12 91 91 670 3a.1.11.12 Plant structures & buildings 154 23 177 89 89 1,307 3a.1.11.13 Waste management 227 34 262 262 1,927 3a.1.11.14 Facility & site closeout 45 7

51 26 26 377 3a.1.11 Total 2,207 331 2,538 2,313 225 18,701 Planning & Site Preparations 3a.1.12 Prepare dismantling sequence 119 18 136 136 1,006 3a.1.13 Plant prep. & temp. svces 2,800 420 3,220 3,220 3a.1.14 Design water clean-up system 69 10 80 80 587 3a.1.15 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,200 330 2,530 2,530 3a.1.16 Procure casks/liners & containers 61 9

70 70 515 3a.1 Subtotal Period 3a Activity Costs 8,835 1,325 10,160 9,935 225 32,497 Period 3a Period-Dependent Costs 3a.4.1 Insurance 382 38 421 421 3a.4.2 Property taxes 500 50 550 550 3a.4.3 Health physics supplies 329 82 411 411 3a.4.4 Heavy equipment rental 396 59 455 455 3a.4.5 Disposal of DAW generated 1

1 27 7

36 36 481 9,613 2

3a.4.6 Plant energy budget 1,371 206 1,577 1,577 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 19 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 3a Period-Dependent Costs (continued) 3a.4.7 NRC Fees 214 21 236 236 3a.4.8 Site O&M Costs 125 19 144 144 3a.4.9 Security Staff Cost 233 35 268 268 6,257 3a.4.10 Utility Staff Cost 14,259 2,139 16,398 16,398 200,229 3a.4 Subtotal Period 3a Period-Dependent Costs 724 1

1 27 17,085 2,656 20,495 20,495 481 9,613 2

206,486 3a.0 TOTAL PERIOD 3a COST 724 1

1 27 25,920 3,982 30,655 30,429 225 481 9,613 2

238,983 PERIOD 3b - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 234 35 269 242 27 1,983 3b.1.1.2 Reactor internals 198 30 227 227 1,676 3b.1.1.3 Remaining buildings 67 10 77 19 58 566 3b.1.1.4 CRD housings & NIs 49 7

57 57 419 3b.1.1.5 Incore instrumentation 49 7

57 57 419 3b.1.1.6 Removal primary containment 99 15 114 114 838 3b.1.1.7 Reactor vessel 179 27 206 206 1,521 3b.1.1.8 Facility closeout 59 9

68 34 34 503 3b.1.1.9 Sacrificial shield 59 9

68 68 503 3b.1.1.10 Reinforced concrete 49 7

57 28 28 419 3b.1.1.11 Main Turbine 103 15 118 118 872 3b.1.1.12 Main Condensers 103 15 119 119 875 3b.1.1.13 Moisture separators & reheaters 99 15 114 114 838 3b.1.1.14 Radwaste building 135 20 155 140 16 1,144 3b.1.1.15 Reactor building 135 20 155 140 16 1,144 3b.1.1 Total 1,619 243 1,862 1,684 178 13,718 3b.1 Subtotal Period 3b Activity Costs 1,619 243 1,862 1,684 178 13,718 Period 3b Additional Costs 3b.2.1 Site Characterization 2,550 765 3,315 3,315 12,457 4,471 3b.2 Subtotal Period 3b Additional Costs 2,550 765 3,315 3,315 12,457 4,471 Period 3b Collateral Costs 3b.3.1 Decon equipment 763 114 877 877 3b.3.2 DOC 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 763 1,100 1,130 449 3,442 3,442 Period 3b Period-Dependent Costs 3b.4.1 Decon supplies 24 6

29 29 3b.4.2 Insurance 214 21 235 235 3b.4.3 Property taxes 253 25 279 279 3b.4.4 Health physics supplies 180 45 225 225 3b.4.5 Heavy equipment rental 201 30 231 231 3b.4.6 Disposal of DAW generated 1

0 15 4

20 20 269 5,373 1

3b.4.7 Plant energy budget 695 104 799 799 3b.4.8 NRC Fees 109 11 120 120 3b.4.9 Site O&M Costs 63 9

73 73 3b.4.10 Security Staff Cost 118 18 136 136 3,171 3b.4.11 DOC Staff Cost 3,332 500 3,832 3,832 43,343 3b.4.12 Utility Staff Cost 7,227 1,084 8,312 8,312 101,486 3b.4 Subtotal Period 3b Period-Dependent Costs 24 380 1

0 15 12,011 1,858 14,289 14,289 269 5,373 1

148,000 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 20 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours 3b.0 TOTAL PERIOD 3b COST 786 1,480 1

0 15 17,310 3,314 22,907 22,729 178 269 5,373 12,458 166,190 PERIOD 3 TOTALS 786 2,205 2

1 42 43,230 7,296 53,562 53,158 403 749 14,985 12,460 405,172 PERIOD 4a - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Recirculation System Piping & Valves 21 77 18 11 26 99 62 315 315 503 503 116,652 1,846 4a.1.1.2 Recirculation Pumps & Motors 11 43 14 22 54 156 68 370 370 1,416 1,178 211,420 1,136 4a.1.1.3 CRDMs & NIs Removal 48 177 492 88 166 172 1,143 1,143 5,536 141,063 4,118 4a.1.1.4 Reactor Vessel Internals 168 2,076 4,559 1,306 7,102 227 6,692 22,129 22,129 2,128 1,753 652 452,885 26,158 1,178 4a.1.1.5 Vessel & Internals GTCC Disposal 11,118 1,668 12,786 12,786 671 109,910 4a.1.1.6 Reactor Vessel 4,397 1,485 481 1,769 227 4,707 13,065 13,065 17,632 1,799,953 26,158 1,178 4a.1.1 Totals 248 6,770 6,568 1,908 80 20,410 454 13,370 49,809 49,809 1,919 26,978 1,753 652 671 2,831,883 59,417 2,357 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 480 2,215 424 2,633 800 6,551 6,551 124,489 5,601,986 8,748 4a.1.3 Main Condensers 921 1,579 302 1,877 715 5,393 5,393 88,729 3,992,800 16,783 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor Building 985 148 1,132 1,132 11,181 4a.1.4.2 Auxiliary Building 407 61 468 468 4,723 4a.1.4.3 IRSF Building 74 11 85 85 939 4a.1.4.4 Service Building 162 24 187 187 2,230 4a.1.4.5 Solid Radwaste Building 224 34 258 258 2,559 4a.1.4.6 Turbine Building 597 90 687 687 7,337 4a.1.4 Totals 2,449 367 2,816 2,816 28,970 Disposal of Plant Systems 4a.1.5.1 Acid & Caustic 17 2

19 19 317 4a.1.5.2 Auxiliary Steam 304 7

12 74 89 486 486 3,882 157,664 5,230 4a.1.5.3 CSCS Equipment Cooling 7

1 9

9 141 4a.1.5.4 Chemical Feed 34 5

39 39 638 4a.1.5.5 Circulating Water 158 24 182 182 3,125 4a.1.5.6 Circulating Water - RCA 218 3

6 36 61 324 324 1,874 76,117 3,663 4a.1.5.7 Clean Condensate Storage 146 22 168 168 2,875 4a.1.5.8 Clean Condensate Storage - RCA 68 1

1 8

18 96 96 429 17,422 1,131 4a.1.5.9 Condensate 721 39 72 449 262 1,542 1,542 23,501 954,377 13,200 4a.1.5.10 Condensate Booster 811 92 171 1,064 397 2,535 2,535 55,734 2,263,391 15,040 4a.1.5.11 Condensate Polishing Demineralizer 811 10 18 111 223 1,173 1,173 5,810 235,956 14,279 4a.1.5.12 Containment Combustible Gas Control 69 1

2 11 19 101 101 567 23,007 1,161 4a.1.5.13 Cycled Condensate Storage 480 11 21 131 144 788 788 6,857 278,483 8,725 4a.1.5.14 Drywell Instrument Nitrogen 59 1

2 12 17 90 90 613 24,892 1,048 4a.1.5.15 Extraction Steam 265 9

17 107 86 485 485 5,615 228,022 4,883 4a.1.5.16 Feedwater 457 24 45 277 165 968 968 14,520 589,682 8,412 4a.1.5.17 Feedwater Heater Vents & Drains 2,119 66 123 762 669 3,738 3,738 39,902 1,620,422 38,608 4a.1.5.18 Gland Steam 190 3

5 32 53 283 283 1,669 67,764 3,394 4a.1.5.19 HVAC-Machine Shop\\TB Sandblast 29 0

1 5

8 44 44 270 10,961 531 4a.1.5.20 HVAC-River\\Lake Screen House 21 3

24 24 422 4a.1.5.21 HVAC-Service Building 54 8

63 63 1,072 4a.1.5.22 Hydrogen & Carbon Dioxide 36 5

41 41 708 4a.1.5.23 Lake Makeup & Blowdown 214 32 246 246 4,257 4a.1.5.24 Main Steam 103 1

2 15 28 150 150 775 31,473 1,824 4a.1.5.25 Makeup Demineralizer 622 14 26 163 185 1,010 1,010 8,552 347,300 11,294 4a.1.5.26 Misc Bldgs Floor Drains 1,156 66 58 125 250 386 2,041 2,041 6,544 2,367 477,918 19,530 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 21 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Disposal of Plant Systems (continued) 4a.1.5.27 Refrigeration 55 8

63 63 1,110 4a.1.5.28 Refrigeration - RCA 40 0

1 5

11 57 57 245 9,954 666 4a.1.5.29 Screen Wash 20 3

23 23 407 4a.1.5.30 Service Air 22 3

25 25 427 4a.1.5.31 Sewage Treatment 87 13 100 100 1,741 4a.1.5.32 Standby Gas Treatment 42 1

3 17 14 77 77 901 36,604 761 4a.1.5.33 Station Heat Recovery 581 18 31 195 181 1,007 1,007 10,223 415,159 10,039 4a.1.5.34 Switchgear Heat Removal 10 1

11 11 180 4a.1.5.35 Turbine Bldg Closed Cooling Water 415 14 25 157 133 744 744 8,238 334,542 7,401 4a.1.5.36 Turbine Building Equipment Drains 73 1

3 17 21 116 116 898 36,485 1,308 4a.1.5.37 Turbine Building Floor Drains 74 1

1 6

20 102 102 325 13,189 1,313 4a.1.5.38 Turbine Generator 212 10 19 115 74 431 431 6,046 245,513 3,970 4a.1.5.39 Turbine Oil 619 24 28 115 64 195 1,047 1,047 6,048 656 300,237 11,160 4a.1.5.40 Wastewater Treatment 129 19 148 148 2,499 4a.1.5 Totals 11,548 418 693 4,009 315 3,612 20,595 19,434 1,161 210,037 3,023 8,796,532 208,490 4a.1.6 Scaffolding in support of decommissioning 2,452 43 10 48 15 630 3,197 3,197 2,253 140 113,977 50,760 4a.1 Subtotal Period 4a Activity Costs 248 24,620 10,822 3,337 8,647 20,740 454 19,493 88,361 87,200 1,161 427,427 30,141 1,753 652 671 21,337,180 373,168 2,357 Period 4a Collateral Costs 4a.3.1 Process liquid waste 27 12 59 59 38 195 195 210 12,621 41 4a.3.2 Small tool allowance 310 47 357 321 36 4a.3 Subtotal Period 4a Collateral Costs 27 310 12 59 59 85 552 516 36 210 12,621 41 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 58 15 73 73 4a.4.2 Insurance 529 53 582 582 4a.4.3 Property taxes 627 63 690 621 69 4a.4.4 Health physics supplies 1,859 465 2,324 2,324 4a.4.5 Heavy equipment rental 2,094 314 2,409 2,409 4a.4.6 Disposal of DAW generated 17 7

349 90 463 463 6,261 125,217 29 4a.4.7 Plant energy budget 1,634 245 1,879 1,879 4a.4.8 NRC Fees 565 57 622 622 4a.4.9 Site O&M Costs 157 24 180 180 4a.4.10 Liquid Radwaste Processing Equipment/Services 481 72 553 553 4a.4.11 Security Staff Cost 2,623 393 3,016 3,016 70,296 4a.4.12 DOC Staff Cost 14,361 2,154 16,515 16,515 179,693 4a.4.13 Utility Staff Cost 23,813 3,572 27,385 27,385 321,359 4a.4 Subtotal Period 4a Period-Dependent Costs 58 3,953 17 7

349 44,790 7,516 56,690 56,621 69 6,261 125,217 29 571,348 4a.0 TOTAL PERIOD 4a COST 333 28,883 10,851 3,403 8,647 21,148 45,243 27,094 145,603 144,338 1,265 427,427 36,612 1,753 652 671 21,475,020 373,238 573,705 PERIOD 4b - Site Decontamination Period 4b Direct Decommissioning Activities 4b.1.1 Remove spent fuel racks 832 82 166 157 1,030 734 3,001 3,001 9,726 872,665 1,631 Disposal of Plant Systems 4b.1.2.1 Aux Diesel Bldg Floor Drains 8

1 9

9 147 4b.1.2.2 Auxiliary Diesel Generator 69 10 79 79 1,341 4b.1.2.3 Containment Monitoring 21 0

0 2

6 28 28 81 3,296 407 4b.1.2.4 Control Rod Drive 185 2

3 18 50 258 258 961 39,042 3,464 4b.1.2.5 Diesel Oil 58 9

67 67 1,104 4b.1.2.6 Domestic Water 25 4

29 29 499 4b.1.2.7 Domestic Water - RCA 39 0

1 5

11 56 56 263 10,694 653 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 22 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Disposal of Plant Systems (continued) 4b.1.2.8 Electrical 518 78 596 596 9,872 4b.1.2.9 Electrical - Contaminated 749 10 18 114 208 1,099 1,099 5,977 242,742 13,169 4b.1.2.10 Electrical - RCA 5,152 94 168 1,047 1,480 7,941 7,941 54,830 2,226,676 87,927 4b.1.2.11 Fire Protection 214 32 246 246 4,263 4b.1.2.12 Fire Protection - RCA 1,033 22 39 244 303 1,641 1,641 12,787 519,289 17,581 4b.1.2.13 Fuel Pool Cooling & Cleanup 703 22 40 249 221 1,235 1,235 13,068 530,713 12,596 4b.1.2.14 HVAC-Auxiliary Building 261 7

12 76 79 434 434 3,972 161,301 4,427 4b.1.2.15 HVAC-Control Rm\\Aux Equip Area 38 6

44 44 729 4b.1.2.16 HVAC-Diesel Generator Room 14 2

16 16 284 4b.1.2.17 HVAC-Off Gas Building 61 3

5 30 21 119 119 1,548 62,855 1,100 4b.1.2.18 HVAC-Primary Containment 800 19 35 219 240 1,313 1,313 11,460 465,384 13,770 4b.1.2.19 HVAC-Radwaste Building 97 2

4 23 28 154 154 1,200 48,728 1,667 4b.1.2.20 HVAC-Turbine Building 731 15 28 177 215 1,166 1,166 9,260 376,037 11,966 4b.1.2.21 High Pressure Core Spray 268 27 34 127 87 115 657 657 6,654 818 343,590 4,869 4b.1.2.22 Instrument Air 7

1 9

9 152 4b.1.2.23 Instrument Air - RCA 142 1

2 13 38 197 197 681 27,654 2,514 4b.1.2.24 Low Pressure Core Spray 128 12 15 59 40 54 308 308 3,069 376 158,310 2,315 4b.1.2.25 Nuclear Boiler 1,271 95 112 354 359 487 2,677 2,677 18,553 3,390 1,057,552 23,399 4b.1.2.26 Off Gas 504 30 34 90 126 179 962 962 4,693 1,189 297,108 9,052 4b.1.2.27 Primary Containment Vent & Purge 395 18 33 208 137 791 791 10,887 442,119 7,350 4b.1.2.28 Process Radiation Monitoring 13 0

0 1

3 17 17 33 1,355 253 4b.1.2.29 Process Sampling 46 0

1 4

12 64 64 210 8,527 895 4b.1.2.30 Radioactive Waste Disposal 2,225 85 93 328 261 693 3,685 3,685 17,201 2,582 919,500 39,849 4b.1.2.31 Radwaste Area Floor Drains 2

0 0

0 0

0 2

2 5

1 256 31 4b.1.2.32 Reactor Bldg Closed Cooling Water 355 21 37 231 131 774 774 12,081 490,626 6,182 4b.1.2.33 Reactor Building Equipment Drains 57 2

2 6

6 17 91 91 330 61 18,672 1,038 4b.1.2.34 Reactor Building Floor Drains 6

0 0

0 0

2 8

8 17 2

897 108 4b.1.2.35 Reactor Core Isolation Cooling 178 7

8 21 28 57 300 300 1,099 269 68,725 3,218 4b.1.2.36 Reactor Recirculation 102 9

11 35 34 42 232 232 1,858 321 104,233 1,910 4b.1.2.37 Reactor Water Clean-up 675 23 19 31 92 202 1,042 1,042 1,618 874 144,057 11,928 4b.1.2.38 Residual Heat Removal 1,324 129 163 608 429 567 3,220 3,220 31,857 4,053 1,657,265 24,347 4b.1.2.39 Service Air - RCA 325 3

6 37 88 459 459 1,953 79,314 5,520 4b.1.2.40 Service Water 82 12 95 95 1,595 4b.1.2.41 Service Water - RCA 749 24 44 271 237 1,325 1,325 14,208 577,006 12,979 4b.1.2.42 Standby Liquid Control 42 0

1 6

12 60 60 291 11,832 702 4b.1.2.43 Well Water 91 14 104 104 1,732 4b.1.2 Totals 19,765 682 968 4,633 1,462 6,103 33,612 32,319 1,293 242,706 13,935 11,095,350 348,903 4b.1.3 Scaffolding in support of decommissioning 3,678 64 15 71 22 944 4,795 4,795 3,380 210 170,965 76,140 Decontamination of Site Buildings 4b.1.4.1 Reactor Building 2,568 3,065 300 338 238 837 2,376 9,721 9,721 12,446 15,506 2,048,598 99,006 4b.1.4.2 Auxiliary Building 1,250 543 44 54 275 66 831 3,062 3,062 14,385 856 665,655 31,725 4b.1.4.3 IRSF Building 69 18 3

4 1

9 42 146 146 26 174 18,472 1,537 4b.1.4.4 Service Building 95 19 4

5 1

13 57 194 194 34 243 25,654 2,032 4b.1.4.5 Solid Radwaste Building 423 297 12 14 19 32 300 1,097 1,097 984 574 96,903 12,864 4b.1.4.6 Turbine Building 1,528 630 77 88 98 208 1,009 3,638 3,638 5,149 3,826 585,724 38,151 4b.1.4 Totals 5,933 4,573 440 502 630 1,165 4,615 17,858 17,858 33,023 21,181 3,441,006 185,317 4b.1 Subtotal Period 4b Activity Costs 6,765 28,097 1,353 1,642 5,334 3,679 12,396 59,267 57,974 1,293 279,109 45,052 15,579,990 611,991 Period 4b Additional Costs 4b.2.1 License Termination Survey Planning 940 282 1,222 1,222 6,240 4b.2.2 ISFSI License Termination 57 1

38 153 749 171 1,168 1,168 2,905 244,104 3,498 1,280 4b.2.3 Soil Remediation 29 1

216 706 216 1,168 1,168 13,453 1,119,288 367 4b.2 Subtotal Period 4b Additional Costs 86 2

254 859 1,689 669 3,559 2,391 1,168 16,358 1,363,392 3,865 7,520 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 23 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours Period 4b Collateral Costs 4b.3.1 Process liquid waste 90 42 203 199 129 663 663 717 42,995 140 4b.3.2 Small tool allowance 515 77 592 592 4b.3.3 Decommissioning Equipment Disposition 114 31 127 40 45 356 356 6,000 373 303,507 88 4b.3 Subtotal Period 4b Collateral Costs 90 515 156 234 127 239 252 1,612 1,612 6,000 1,090 346,502 228 Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 1,511 378 1,889 1,889 4b.4.2 Insurance 935 94 1,029 1,029 4b.4.3 Property taxes 1,109 111 1,220 1,220 4b.4.4 Health physics supplies 3,117 779 3,896 3,896 4b.4.5 Heavy equipment rental 3,674 551 4,225 4,225 4b.4.6 Disposal of DAW generated 27 10 558 144 740 740 10,002 200,042 46 4b.4.7 Plant energy budget 2,282 342 2,624 2,624 4b.4.8 NRC Fees 1,000 100 1,100 1,100 4b.4.9 Site O&M Costs 277 42 319 319 4b.4.10 Liquid Radwaste Processing Equipment/Services 850 128 978 978 4b.4.11 Security Staff Cost 6,219 933 7,152 7,152 144,643 4b.4.12 DOC Staff Cost 24,954 3,743 28,697 28,697 310,114 4b.4.13 Utility Staff Cost 41,070 6,161 47,231 47,231 546,171 4b.4 Subtotal Period 4b Period-Dependent Costs 1,511 6,791 27 10 558 78,696 13,504 101,098 101,098 10,002 200,042 46 1,000,929 4b.0 TOTAL PERIOD 4b COST 8,366 35,489 1,538 2,140 5,461 5,335 80,385 26,821 165,536 163,074 1,168 1,293 285,109 72,502 17,489,930 616,130 1,008,449 PERIOD 4e - License Termination Period 4e Direct Decommissioning Activities 4e.1.1 ORISE confirmatory survey 151 45 197 197 4e.1.2 Terminate license a

4e.1 Subtotal Period 4e Activity Costs 151 45 197 197 Period 4e Additional Costs 4e.2.1 License Termination Survey 11,748 3,524 15,272 15,272 217,865 3,120 4e.2 Subtotal Period 4e Additional Costs 11,748 3,524 15,272 15,272 217,865 3,120 Period 4e Collateral Costs 4e.3.1 DOC staff relocation expenses 1,130 169 1,299 1,299 4e.3 Subtotal Period 4e Collateral Costs 1,130 169 1,299 1,299 Period 4e Period-Dependent Costs 4e.4.1 Insurance 4e.4.2 Property taxes 382 38 420 420 4e.4.3 Health physics supplies 1,037 259 1,296 1,296 4e.4.4 Disposal of DAW generated 1

0 19 5

25 25 340 6,795 2

4e.4.5 Plant energy budget 210 31 241 241 4e.4.6 NRC Fees 360 36 396 396 4e.4.7 Site O&M Costs 95 14 110 110 4e.4.8 Security Staff Cost 540 81 620 620 11,957 4e.4.9 DOC Staff Cost 3,856 578 4,434 4,434 47,430 4e.4.10 Utility Staff Cost 4,617 693 5,310 5,310 57,793 4e.4 Subtotal Period 4e Period-Dependent Costs 1,037 1

0 19 10,060 1,736 12,853 12,853 340 6,795 2

117,180 4e.0 TOTAL PERIOD 4e COST 1,037 1

0 19 23,089 5,475 29,621 29,621 340 6,795 217,867 120,300 PERIOD 4 TOTALS 8,700 65,409 12,391 5,544 14,108 26,502 148,717 59,390 340,760 337,033 1,168 2,559 712,536 109,454 1,753 652 671 38,971,740 1,207,234 1,702,454 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 24 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours PERIOD 5b - Site Restoration Period 5b Direct Decommissioning Activities Demolition of Remaining Site Buildings 5b.1.1.1 Reactor Building 5,667 850 6,518 6,518 64,458 5b.1.1.2 Auxiliary Building 3,686 553 4,239 4,239 42,962 5b.1.1.3 Capital Improvements 2009 1,314 197 1,511 1,511 20,778 5b.1.1.4 Chemical Feed Building 32 5

36 36 482 5b.1.1.5 Diesel Generator Room 468 70 538 538 6,000 5b.1.1.6 Discharge Structure 20 3

23 23 190 5b.1.1.7 IRSF Building 691 104 794 794 8,924 5b.1.1.8 ISFSI Haul Path 651 98 748 748 9,520 5b.1.1.9 Lake Screen House 1,102 165 1,267 1,267 13,877 5b.1.1.10 Main Access Facility 390 58 448 448 5,396 5b.1.1.11 Miscellaneous Yard Structures 1,946 292 2,238 2,238 27,034 5b.1.1.12 New Service Building 1,840 276 2,116 2,116 23,587 5b.1.1.13 Outfall Structure 8

1 9

9 113 5b.1.1.14 River Screen House 330 50 380 380 4,230 5b.1.1.15 Security Modifications 677 102 778 778 3,834 5b.1.1.16 Service Building 1,534 230 1,764 1,764 21,582 5b.1.1.17 Sewage Treatment Plant 36 5

41 41 591 5b.1.1.18 Sewage Treatment Plant Upgrades 263 39 302 302 3,306 5b.1.1.19 Solid Radwaste Building 2,029 304 2,333 2,333 23,167 5b.1.1.20 Training Center 1,222 183 1,406 1,406 16,863 5b.1.1.21 Turbine Building 5,501 825 6,326 6,326 68,584 5b.1.1.22 Turbine Pedestal 2,102 315 2,418 2,418 22,592 5b.1.1.23 Wastewater Treatment Plant 59 9

68 68 911 5b.1.1 Totals 31,566 4,735 36,300 748 35,552 388,980 Site Closeout Activities 5b.1.2 BackFill Site 522 78 600 600 1,485 5b.1.3 Grade & landscape site 149 22 171 171 499 5b.1.4 Final report to NRC 77 12 89 89 654 5b.1 Subtotal Period 5b Activity Costs 32,236 77 4,847 37,160 89 748 36,323 390,964 654 Period 5b Additional Costs 5b.2.1 Concrete Crushing 1,155 5

174 1,333 1,333 5,855 5b.2.2 ISFSI Demolition and Site Restoration 1,604 24 244 1,872 1,872 21,545 80 5b.2.3 Cofferdam Construction and Teardown 389 58 447 447 3,896 5b.2 Subtotal Period 5b Additional Costs 3,147 29 476 3,652 1,872 1,780 31,296 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 359 54 413 413 5b.3 Subtotal Period 5b Collateral Costs 359 54 413 413 Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property taxes 998 100 1,098 1,098 5b.4.3 Heavy equipment rental 4,728 709 5,437 5,437 5b.4.4 Plant energy budget 274 41 315 315 5b.4.5 Site O&M Cost 249 37 287 287 5b.4.6 Security Staff Cost 1,274 191 1,465 1,465 27,619 5b.4.7 DOC Staff Cost 9,384 1,408 10,792 10,792 110,391 5b.4.8 Utility Staff Cost 4,478 672 5,149 5,149 54,154 5b.4 Subtotal Period 5b Period-Dependent Costs 4,728 16,657 3,158 24,542 24,542 192,164 TLG Services, Inc.

LaSalle County Station Decommissioning Cost Analysis Document E16-1555-012, Rev. 0 Appendix E, Page 25 of 25 Table E-2 LaSalle County Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Mon, Jun 1, 2009 at 10:09:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2007.02.18c Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

Management Restoration Volume Class A Class B Class C GTCC Processed Craft Contractor Index Activity Description Cost Cost Costs Costs Costs Costs Costs Contingency Costs Costs Costs Costs Cu. Feet Cu. Feet Cu. Feet Cu. Feet Cu. Feet Wt., Lbs.

Manhours Manhours 5b.0 TOTAL PERIOD 5b COST 40,470 16,763 8,535 65,768 89 2,621 63,059 422,260 192,898 PERIOD 5 TOTALS 40,470 16,763 8,535 65,768 89 2,621 63,059 422,260 192,898 TOTAL COST TO DECOMMISSION 18,267 113,873 12,583 6,210 14,108 28,324 523,942 125,800 843,106 652,162 124,923 66,021 712,536 133,030 1,753 652 671 39,534,280 1,770,102 4,702,065 TOTAL COST TO DECOMMISSION WITH 17.54% CONTINGENCY:

$843,106 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 77.35% OR:

$652,162 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 14.82% OR:

$124,923 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 7.83% OR:

$66,021 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

135,435 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

671 cubic feet TOTAL SCRAP METAL REMOVED:

67,666 Tons TOTAL CRAFT LABOR REQUIREMENTS:

1,770,102 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.

ATTACHMENT 2 LaSalle County Station, Units 1 and 2 Radiological Decommissioning Projected SAFSTOR Cash Flow (dollars, thousands)

LCS Unit 1 LCS Unit 1 Radiological Decommissioning Cost Radiological Decommissioning Cost less Year (July 31,2009 dollars)

Decommissioning Period Credit 2022

$33,216

$33,216 2023

$56,329

$55,224 2024

$3,405

$3,273 2025

$3,396

$3,200 2026

$3,396

$3,137 2027

$3,258

$2,951 2028

$2,740

$2,433 2029

$2,733

$2,379

ATTACHMENT 2 LaSalle County Station Units 1 and 2 Radiological Decommissioning Projected SAFSTOR Cash Flow (continued)

(dollars, thousands)

LCS Unit 1 LCS Unit 1 Radiological Decommissioning Cost Radiological Decommissioning Cost less Year (July 31,2009 dollars)

Decommissioning Period Credit 2061

$4,267

$1,971 2062

$4,267

$1,933 2063

$4,267

$1,895 2064

$4,279

$1,863 2065

$4,267

$1,821 2066

$4,267

$1,785 2067

$4,267

$1,750 2068

$4,279

$1,721 Total

$675,346

$335,107 Total Decommissioning Period Credit:

$340,240

ATTACHMENT 2 LaSalle County Station, Units 1 and 2 Radiological Decommissioning Projected SAFSTOR Cash Flow (dollars, thousands)

LCS Unit 2 LCS Unit 2 Radiological Decommissioning Cost Radiological Decommissioning Cost less Year (July 31,2009 dollars)

Decommissioninq Period Credit 2023

$2,210

$2,210 2024

$53,286

$52,242 2025

$40,737

$39,155 2026

$3,484

$3,283 2027

$3,484

$3,219

ATTACHMENT 2 LaSalle County Station Units 1 and 2 Radiological Decommissioning Projected SAFSTOR Cash Flow (continued)

(dollars, thousands)

LCS Unit 2 LCS Unit 2 Radiological Decommissionlng Cost Radiological Decommissioning Cost less Year (July 31,2009 dollars)

Decommissioning Period Credit 2062

$3,466

$1,601 2063

$3,466

$1,570 Total

$661,879

$324,990 Total Decommissioning Period Credit:

$336,889

ATTACHMENT 3 LaSalle County Station, Units 1 and 2 NRC Funding Assurance Calculations July 31, 2009 (dollars, thousands)

Required Minimum at July 31,2009 (A)

Trust Fund Amount at July 31,2009 (B)

Shutdown Date Years to Shutdown (C)

Earnings Credit to shutdown (D) = (B) x ((1 + 2%) A (C) -1)

Projected Trust Fund Amount at shutdown (E) = (8) + (D)

Decommissioning Period Earnings Credit (F)

Total Projected Trust Fund Amount (G) = (E) + (F)

Difference (H) = (G) - (A)

Prepayment Difference - Surplus/(Shortfall)

(J) = (H) / ( I + 2%) A (C)

Required Minimum at July 31,2009 (A)

Trust Fund Amount at July 31,2009 (B)

Shutdown Date Years to Shutdown (C)

Earnings Credit to shutdown (D) = (B) x ((1 + 2%) A (C) -1)

Projected Trust Fund Amount at shutdown (E) = (8) + (D)

Decommissioning Period Earnings Credit (F)

Total Projected Trust Fund Amount (G) = (E) + (F)

Difference (H) = (G) - (A)

Prepayment Difference - Surplusl(Shortfail)

(J) = (H) /(I + 2%) A (C)

LCS, Unit 1 NRC Generic Formula

$576,567

$291,096 411 712022 12.721

$83,390

$374,486

$27,840

$402,326

($174,241)

($135,441)

LCS, Unit 1 Site-Specific SAFSTOR Decommissioning Cost Estimate

$675,346

$291,096 411 712022 12.721

$83,390

$374,486

$340,240

$714,725

$39,379

$30,610 LCS, Unit 2 NRC Generic Formula

$576,567

$284,257 1211 612023 14.386

$93,694

$377,951

$28,098

$406,049

($1 70,518)

($128,246)

LCS, Unit 2 Site-Specific SAFSTOR Decommissioning Cost Estimate

$661,879

$284,257 12/16/2023 14.386

$93,694

$377,951

$336,889

$71 4,840

$52,962

$39,832