RS-09-157, Submittal of Site-Specific Safstor Decommissioning Cost Estimate

Submittal of Site-Specific Safstor Decommissioning Cost Estimate

ML093210130
Person / Time
Site:	Byron
Issue date:	11/16/2009
From:	Simpson P Exelon Generation Co, Exelon Nuclear
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
RS-09-157
Download: ML093210130 (177)

Text

Fxelon (;encration 4300 Winfield Road Warrerivrlle, li 60555 Nuclear 10 CFR 50.75(f)(1)

November 16,2009 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Byron Station, Units 1 and 2 Facility Operating License Nos. NPF-37 and NPF-66 NRC Docket Nos. STN 50-454 and STN 50-455

Subject:

Submittal of Byron 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 Byron Station, 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 Byron Station, Units 1 and 2 are granted license extension, since it is intended to reflect the most likely decommissioning scenario for Byron Station. 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 Byron Station. 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.

November 16,2009 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 October 31, 2009 by using the latest site-specific escalation factor, which is re-calculated on an annual basis.

For Byron Station 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 Byron Station, nor are there any contracts relied upon to pursuant to 10 CFR 50.75(e)(l)(v).

Per the referenced letter, EGC will perform a calculation of radiological decommissioning funding assurance as of December 31, 2009 based on this site-specific SAFSTOR estimate. If this calculation does not show adequate decommissioning funding assurance, EGC will obtain approval from the EGC Board of Directors for, and establish an additional funding assurance mechanism by April 1, 201 0.

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.

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Patrick R. Simpson Manager - Licensing Exelon Generation Company, LLC Attachments: 1. Byron Station, Units 1 and 2, Decommissioning Cost Estimate

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

ATTACHMENT 1 Byron Station, Units 1 and 2 Decommissioning Cost Estimate

Document E16-1555-013, Rev. 0 DECOMMISSIONING COST ANALYSIS for the BYRON NUCLEAR POWER STATION prepared for Exelon Generation Company LLC prepared by TLG Services, Inc.

Bridgewater, Connecticut September 2009

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APPROVALS

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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....................................1-7

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 Plant Inventory.................................................................................................3-3 3.3.1 Plant Systems........................................................................................3-3 3.3.2 Plant Structures....................................................................................3-3 3.4 Impact of Decommissioning Multiple Reactor Units.....................................3-4 3.5 Financial Components of the Cost Model.......................................................3-5 3.5.1 Contingency...........................................................................................3-5 3.5.2 Financial Risk........................................................................................3-8 3.6 Site-Specific Considerations.............................................................................3-9 3.6.1 Spent Fuel Management.......................................................................3-9 3.6.2 Reactor Vessel and Internal Components.........................................3-12 3.6.3 Primary System Components.............................................................3-13 3.6.4 Main Turbine and Condenser.............................................................3-14

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TABLE OF CONTENTS (continued)

SECTION PAGE 3.6.5 Transportation Methods.....................................................................3-14 3.6.6 Low-Level Radioactive Waste Disposal.............................................3-15 3.6.7 Site Conditions Following Decommissioning....................................3-16 3.7 Assumptions....................................................................................................3-17 3.7.1 Estimating Basis.................................................................................3-17 3.7.2 Labor Costs..........................................................................................3-17 3.7.3 Design Conditions................................................................................3-18 3.7.4 General.................................................................................................3-18 3.8 Cost Estimate Summary...............................................................................3-20

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............................ 3-21 3.1b Schedule of Total Annual Expenditures, DECON Unit 2............................ 3-22 3.2a Schedule of Total Annual Expenditures, Delayed DECON Unit 1.............. 3-23 3.2b Schedule of Total Annual Expenditures, Delayed DECON Unit 2.............. 3-24 3.3a Schedule of Total Annual Expenditures, SAFSTOR Unit 1......................... 3-25 3.3b Schedule of Total Annual Expenditures, SAFSTOR Unit 2......................... 3-28 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.............................................................. 4-5 4.3 Decommissioning Timeline, Delayed DECON................................................ 4-6 4.4 Decommissioning Timeline, SAFSTOR.......................................................... 4-7 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

09-14-2009 Original Issue

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EXECUTIVE

SUMMARY

This report presents estimates of the cost to decommission the Byron Nuclear Power Station (Byron) 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. Additionally, the plant systems inventory was completely regenerated from the stations site-specific database. The updated estimates are designed to provide Exelon Generation Company LLC (Exelon) with sufficient information to assess its financial obligations, as they pertain 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 pool 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 pool at the cessation of Unit 2 operations. In the DECON and SAFSTOR scenarios, any residual fuel remaining in the pool 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 pool for the Delayed DECON scenario and transferred directly from the pool 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 Byron Nuclear Power Station, Document No. E16-1455-012, 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,

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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 Number 123 (p 24018 et seq.), June 27, 1988 3

Ibid. Page FR24022, Column 3 4

Ibid.

5 Ibid. Page FR24023, Column 2

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

The Commission concurred with the staffs recommendation.

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 is relocated from the wet storage pool to the ISFSI so as to facilitate decontamination and dismantling activities within the fuel handling building. 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 2062. 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 fuel handling buildings storage pool, remains in the pool until it can be transferred to the DOE (i.e., the ISFSI is not used to off-load the pool following the cessation of operations). Spent fuel placed at the ISFSI during operations remains in storage until the pool is 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 2062).

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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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 in the wet storage pool 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-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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scale construction and demolition projects. It should be noted that contingency, as used in this analysis, does not account for price escalation and inflation in the cost of decommissioning over the remaining operating life of the station.

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 Byron. 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 pool and/or ISFSI.

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

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 Unit 2 operations is provided for the final core to meet the conditions for dry storage.

Once the storage pool is emptied, the fuel handling building 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 pool. In the Delayed DECON scenario, the storage pool remains 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 pool 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 Byron storage pool at the time of shutdown would be scheduled for pickup in the years 2057 through 2062 (assuming the cessation of plant operations in 2044 and 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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2046 for Units 1 and 2, respectively). This equates to 92 multi-purpose canisters (at 32 assemblies per canister), in addition to the 34 on the pad from operations.

Exelons strongly held position is that the DOE has a contractual obligation to accept Byrons 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 Byron 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 13,495 20,267 33,761 Removal 101,779 140,577 242,355 Packaging 15,566 14,027 29,594 Transportation 11,230 9,271 20,501 Waste Disposal 60,756 58,722 119,478 Off-site Waste Processing 3,959 4,044 8,002 Program Management [1]

270,064 320,213 590,277 Spent Fuel Pool Isolation 0

11,143 11,143 Spent Fuel Management [2]

76,838 86,598 163,436 Insurance and Regulatory Fees 12,357 10,476 22,834 Energy 6,029 6,290 12,320 Characterization and Licensing Surveys 16,792 14,659 31,452 Property Taxes 24,861 23,752 48,613 Miscellaneous Equipment 6,307 6,579 12,886 Site O&M 2,688 2,399 5,087 Total [3]

622,721 729,017 1,351,738 Cost Element NRC License Termination 448,221 521,395 969,616 Spent Fuel Management 108,376 118,136 226,513 Site Restoration 66,124 89,486 155,609 Total [3]

622,721 729,017 1,351,738

[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 11,759 17,304 29,063 Removal 100,477 138,090 238,567 Packaging 12,021 10,475 22,496 Transportation 9,958 7,755 17,713 Waste Disposal 42,207 39,128 81,335 Off-site Waste Processing 4,467 4,919 9,386 Program Management [1]

325,510 363,716 689,226 Spent Fuel Pool Isolation 0

11,143 11,143 Spent Fuel Management [2]

24,955 27,878 52,833 Insurance and Regulatory Fees 17,808 15,425 33,232 Energy 9,864 10,089 19,953 Characterization and Licensing Surveys 18,262 16,129 34,391 Property Taxes 29,836 28,729 58,566 Miscellaneous Equipment 10,020 10,203 20,223 Site O&M 3,987 3,698 7,685 Total [3]

621,131 704,681 1,325,812 Cost Element NRC License Termination 420,024 500,309 920,333 Spent Fuel Management 133,669 113,664 247,333 Site Restoration 67,438 90,708 158,146 Total [3]

621,131 704,681 1,325,812

[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 11,611 17,044 28,655 Removal 104,294 141,956 246,250 Packaging 11,916 10,337 22,253 Transportation 9,695 7,335 17,030 Waste Disposal 40,477 37,125 77,601 Off-site Waste Processing 4,543 4,992 9,535 Program Management [1]

368,123 411,270 779,393 Spent Fuel Pool Isolation 0

11,143 11,143 Spent Fuel Management [2]

75,159 84,919 160,078 Insurance and Regulatory Fees 35,666 32,819 68,485 Energy 12,550 12,773 25,323 Characterization and Licensing Surveys 18,262 16,129 34,391 Property Taxes 48,939 47,832 96,771 Miscellaneous Equipment 15,653 16,237 31,890 Site O&M 8,981 8,691 17,672 Total [3]

765,867 860,604 1,626,471 Cost Element NRC License Termination 588,038 638,996 1,227,034 Spent Fuel Management 110,342 130,850 241,192 Site Restoration 67,487 90,758 158,245 Total [3]

765,867 860,604 1,626,471

[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 Byron Nuclear Power Station (Byron), 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 Byron, 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 October 31, 1984, for Unit 1 and November 6, 1986, 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 October 31, 2044, for Unit 1 and November 6, 2046, for Units 1 and 2, respectively. These dates were used to schedule the decommissioning activities.

1.2 SITE DESCRIPTION Byron is located in northern Illinois. The site is situated in a predominately agricultural area approximately 3.7 miles southwest of the city of Byron and 2.2 miles east of Rock River, in Ogle County. The station is comprised of two essentially identical pressurized water reactors with supporting facilities.

The primary coolant system for each unit consists of a pressurized water reactor system designed by the Westinghouse Corporation. The reactor coolant system is comprised of the reactor vessel and four heat transfer loops. Each loop contains a reactor coolant pump, steam generator, and associated piping and valves. In addition, the system includes a pressurizer, a pressurizer relief tank, interconnected piping, and instrumentation necessary for operational control.

Components of the reactor coolant system are located in the containment building. The design reactor thermal power level is 3,587 Megawatts thermal

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(MWth). The corresponding electrical output is approximately 1,242 megawatts electric (MWe) for both Units 1 and 2.

The containment structure at Byron Station is a prestressed concrete shell structure made up of a cylinder with a shallow dome roof and a flat foundation slab. The entire structure is lined on the inside with steel plate, which acts as a leaktight membrane. The containment completely encloses the entire primary coolant system, including portions of the auxiliary and engineered safety features systems.

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 is 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 essential service 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 Rock River by the circulating water pumps via the intake pipes. After passing through the plant condensers, the heat added to the circulating water is the rejected to a natural draft cooling tower.

1.3 REGULATORY GUIDANCE The Nuclear Regulatory Commission (NRC or Commission) provided initial decommissioning requirements in its rule "General Requirements for Decommissioning Nuclear Facilities," issued in June 1988.[2]* This rule set forth financial criteria for decommissioning licensed nuclear power facilities.

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

Subsequent to the rule, the NRC issued Regulatory Guide 1.159, Assuring the Availability of Funds for Decommissioning Nuclear Reactors,[3] which provided additional guidance to the licensees of nuclear facilities on the financial methods acceptable to the NRC staff for complying with the

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

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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 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

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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.

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]

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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 pool and ISFSI.

At shutdown, the fuel storage pool is 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 (from the cessation of Unit 2 operations) the assemblies are packaged into multipurpose canisters for transfer to the ISFSI. It is assumed that this period provides the necessary cooling for the final core to meet on site storage system requirements for decay heat.

An independent spent fuel storage installation (ISFSI) has been 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 pool at the conclusion of the required cooling period. Once emptied, the fuel handling building can be either decontaminated and dismantled or prepared for long-term storage.

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In the Delayed DECON scenario, the storage pool remains operational and is 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 Byron site for approximately 16 years after the cessation of operations at Unit 2. Consequently, costs are included within the analysis for the continued operation of the storage pool and the expansion of the ISFSI, as required, and for the long-term caretaking of the spent fuel at the site until the year 2062.

Exelons strongly held position is that the DOE has a contractual obligation to accept Byrons 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 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 Byron. As of July 1,

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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.

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).

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The decommissioning estimates for Byron 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 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 Byron 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 in the wet storage pool is relocated to the ISFSI so as to facilitate decontamination and dismantling activities within the fuel handling building. 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 2062. 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 fuel handling buildings storage pool, remains in the pool until it can be transferred to the DOE (i.e., the ISFSI is not used to off-load the pool following the cessation of operations). Spent fuel placed at the ISFSI during operations remains in storage until the pool is 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 2062).

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 in the wet storage pool 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 Byron 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 coolant system piping, and other large components that are radioactive. The NRC includes the following additional criteria for use of the §50.59 process in decommissioning. The proposed activity must not:



foreclose release of the site for possible unrestricted use,



significantly increase decommissioning costs,



cause any significant environmental impact, or



violate the terms of the 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.

The decommissioning program outlined in the PSDAR will be designed to accomplish the required tasks within the ALARA guidelines (as

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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 biological shield cores.



Isolation of the spent fuel storage pool and fuel handling systems, such that decommissioning operations can commence on the balance of the plant. 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 pool remains operational for approximately five and one-half years following the cessation of Unit 2 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 10 CFR §50 operating license. Significant decommissioning activities in this phase include:

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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 building to support the segmentation of the reactor vessel internals and component extraction.



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



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.



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



Removal and segmentation of the upper internals assemblies.

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



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



Segmentation of the reactor vessel. A shielded platform is installed for segmentation as cutting operations are performed in-air using remotely operated equipment within a contamination control envelope. The water level is maintained just below the cut to

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minimize the working area dose rates. Segments are transferred in-air to containers that are stored under water, for example, in an isolated area of the refueling canal.



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



Removal of the steam generators and pressurizer for material recovery and controlled disposal. These components can serve as their own burial containers provided that all penetrations are properly sealed and the internal contaminants are stabilized (e.g.,

with lightweight grout). Steel shielding is added, as necessary, to those external areas of the package to meet transportation limits and regulations.



Transfer of the spent fuel from the storage pool to the ISFSI pad for interim storage.



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

Fuel transfer is expected to begin in 2057 and to be completed by the end of the year 2062.

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

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



Surveys of the decontaminated areas of the containment structures.



Removal of the contaminated equipment and material from the auxiliary and fuel buildings, and any other contaminated facility.

Use radiation and contamination control techniques until radiation surveys indicate that the structures and equipment can be released for unrestricted access and conventional demolition. This activity may necessitate the dismantling and disposition of most of the systems and components (both clean and contaminated) located within these buildings. This activity 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 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.

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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 and auxiliary 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.

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

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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 Byron is anticipated to begin in 2057 and continue through the year 2062.

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 safely stored and subsequently decontaminated (deferred decontamination) to levels that permit release for unrestricted use." The facility is left intact (during the dormancy period), with structures maintained in a sound condition. Systems not required to operate in support of the spent fuel pool or

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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 fuel handling buildings storage pool 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 the ISFSI. The plant remains in safe-storage even 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 fuel handling building so that safe-storage operations may commence on the balance of the plant. This activity may be carried out by plant personnel in accordance with existing operating technical specifications. Activities are scheduled around the fuel handling systems to the greatest extent possible.



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

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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.

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

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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 pool 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 the availability of the fuel storage facilities located within the fuel handling building for decommissioning.

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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 biological shield will still be radioactive due to the presence of activated trace elements with long half-lives (152Eu and 154Eu). Decontamination will require controlled removal and disposal. It is assumed that radioactive corrosion products on inner surfaces of piping and components will not have decayed to levels that will permit unrestricted use or allow conventional removal.

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

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 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 Byron 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 PLANT INVENTORY The basis for any site-specific decommissioning estimate is the plant inventory. The inventory dictates the decontamination, removal, packaging, transport and disposal requirements and the associated performance cost.

Material disposition requirements impact the project schedule and are reflected in the level of management needed to support the project.

Consequently, it is important to delineate the inventory of material and components to be dispositioned during decommissioning, which in most instances is a subset of the total quantity of material placed during construction. In addition, the plant inventory needs to be defined in units that are compatible with the intended removal methods. For example, while sample panels may contain hundreds of subassemblies, the panels are removed in bulk. The disposition cost may be based upon the total weight of the panel and the lifting devices required rather than by disassembly of the individual components. In contrast to plant operations, the most important parameter in decommissioning can be the components mass or materials of construction and not its design performance.

3.3.1 Plant Systems Plant system inventories were regenerated for purposes of this analysis from a plant data base, piping and instrument drawings and from other available information. Where new information was not available, the basis for the previous estimate was reviewed and, once validated, used to supplement the new inventory.

3.3.2 Plant Structures Structure inventories for the major power block structures relied upon the data from the 2004 study. A site inspection conducted in 2009 identified new buildings and security improvements at the site since the previous study was performed. These structures and site improvements were incorporated into the current estimate.

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3.4 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 estimates do 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 (~ 43%).



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 pool and subsequent decontamination of the fuel handling building is coordinated so as to synchronize the final status survey for the station.

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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.

3.5 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.

3.5.1 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; 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

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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.

Contingency funds are an integral part of the total cost to complete the decommissioning process. Exclusion of this component puts at risk a

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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 18.2% and 18.1% 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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3.5.2 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.

3.6 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.

3.6.1 Spent Fuel Management The cost to dispose of spent fuel generated from plant operations is not reflected within the estimates to decommission the Byron 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 Byron site by the year 2062. In the Delayed DECON scenario, the ISFSI is only used to store fuel placed during plant operations. Spent fuel off-loaded from the reactors after operations cease, remains in the pool during the transfer period. The inventory of fuel assemblies located in the spent fuel pool is preferentially off-loaded as the allocations permit.

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Operation and maintenance costs for the storage facilities (the ISFSI and the pool 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 32-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 pool 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 pool 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 vertical, reinforced concrete storage module is used as a basis for the cost analysis. The final core off load from each unit, equivalent to 14 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 cost of the disposition of this material, as well as the demolition of the ISFSI facility, is included in the estimate.

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3.6.2 Reactor Vessel and Internal Components The NSSS (reactor vessel and reactor coolant 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 refueling canal, where a turntable and remote cutter are installed. The vessel is segmented in place, using a mast-mounted cutter supported off the lower head and directed from a shielded work platform installed overhead in the reactor cavity. Transportation cask specifications and transportation regulations 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 Byron 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:



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

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

3.6.3 Primary System Components The following discussion deals with the removal and disposition of the steam generators, but the techniques involved are also applicable to other large components, such as heat exchangers, component coolers, and the pressurizer. The steam generators size and weight, as well as their location within the reactor building, will ultimately determine the removal strategy.

A trolley crane will be set up for the removal of the generators. It can also be used to move portions of the steam generator cubicle walls and floor slabs from the reactor building to a location where they can be decontaminated and transported to the material handling area.

Interferences within the work area, such as grating, piping and other components, will be removed to create sufficient laydown space for processing these large components.

The generators will be rigged for removal, disconnected from the surrounding piping and supports, and maneuvered into the open area where they will be lowered onto a dolly. Once each steam generator has been placed in the horizontal position, nozzles and other openings will be welded closed. The lower shell will have a carbon steel membrane welded to its outside surface for shielding, if required, during transport.

The interior volume will be filled with low-density cellular concrete for

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stabilization of the internal contamination and to satisfy burial ground packaging requirements. When this stage has been completed, each generator will be moved out of containment and lowered onto a multi-wheeled transporter to be staged at an on-site storage area and await transport to the disposal facility. The pressurizer will be removed using the same technique. Each component will then be loaded onto a railcar for transport to the disposal facility.

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

Byron Unit 1 has replaced its original set of steam generators; this original set is still on site, stored within a concrete protective structure.

The cost for transportation and disposal of this original set of Unit 1 steam generators has been included in this analysis.

3.6.4 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. Clean material is released on site as scrap metal; radioactive or potentially radioactive 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 packaged and readied for transport in accordance with the intended disposition.

3.6.5 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

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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]

3.6.6 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.

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.

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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.

3.6.7 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

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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.

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

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

3.7.2 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.

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3.7.3 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 Byron 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 control elements are disposed of along with the spent fuel (i.e., there is no additional cost provided for their disposal).

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

3.7.4 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.

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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 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.

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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.

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.

3.8 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.

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TABLE 3.1a BYRON NUCLEAR POWER STATION, UNIT 1 DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2044 9,133 1,439 180 7

2,355 13,114 2045 56,857 9,987 1,238 1,475 15,141 84,699 2046 63,860 21,836 1,374 21,149 17,336 125,555 2047 56,336 21,543 964 22,529 12,966 114,338 2048 42,156 11,429 796 2,575 3,372 60,328 2049 42,041 11,397 794 2,568 3,363 60,163 2050 14,800 3,810 261 849 2,061 21,781 2051 1,458 94 0

7 1,423 2,981 2052 2,474 133 9

8 1,460 4,084 2053 23,533 2,845 181 22 1,965 28,546 2054 17,176 7,302 106 0

1,297 25,881 2055 17,176 7,302 106 0

1,297 25,881 2056 4,983 1,400 20 0

1,377 7,782 2057 2,191 323 0

0 1,392 3,906 2058 2,514 1,294 0

0 1,392 5,200 2059 2,514 1,294 0

0 1,392 5,200 2060 2,520 1,294 0

0 1,396 5,209 2061 2,514 1,294 0

0 1,392 5,200 2062 2,514 1,323 0

0 2,350 6,188 2063 1,636 1,088 0

112 13,849 16,685 Total 368,388 108,428 6,029 51,301 88,575 622,721

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TABLE 3.1b BYRON NUCLEAR POWER STATION, UNIT 2 DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2046 7,362 1,427 162 6

2,087 11,045 2047 49,529 10,778 1,221 1,215 17,534 80,276 2048 64,318 22,563 1,395 17,906 22,063 128,245 2049 66,160 22,460 967 19,648 11,207 120,442 2050 60,711 13,811 794 3,608 3,867 82,791 2051 60,711 13,811 794 3,608 3,867 82,791 2052 48,602 8,109 544 3,226 3,723 64,203 2053 27,409 4,030 181 22 1,781 33,424 2054 22,154 10,841 106 0

1,298 34,398 2055 22,154 10,841 106 0

1,298 34,398 2056 5,938 2,079 20 0

1,378 9,415 2057 2,191 323 0

0 1,392 3,906 2058 2,514 1,294 0

0 1,392 5,200 2059 2,514 1,294 0

0 1,392 5,200 2060 2,520 1,294 0

0 1,396 5,209 2061 2,514 1,294 0

0 1,392 5,200 2062 2,514 1,323 0

0 2,350 6,188 2063 1,636 1,088 0

112 13,849 16,685 Total 451,453 128,659 6,290 49,351 93,264 729,017

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

Equipment &

Year Labor Materials Energy Burial Other Total 2044 7,059 187 180 7

440 7,873 2045 43,018 2,722 1,059 357 4,711 51,867 2046 11,154 1,995 490 533 6,649 20,821 2047 5,018 259 212 27 2,643 8,159 2048 5,031 260 212 27 2,650 8,181 2049 5,018 259 212 27 2,643 8,159 2050 5,018 259 212 27 2,643 8,159 2051 5,018 259 212 27 2,643 8,159 2052 5,031 260 212 27 2,650 8,181 2053 5,018 259 212 27 2,643 8,159 2054 5,018 259 212 27 2,643 8,159 2055 5,018 259 212 27 2,643 8,159 2056 5,031 260 212 27 2,650 8,181 2057 5,449 1,553 212 27 2,643 9,884 2058 6,743 5,434 212 27 2,643 15,059 2059 4,945 2,845 158 27 2,018 9,992 2060 3,181 256 106 26 1,414 4,983 2061 3,352 794 106 26 1,410 5,688 2062 3,707 1,552 108 26 1,409 6,803 2063 40,898 1,516 1,059 36 1,321 44,830 2064 55,045 11,322 1,035 10,272 13,486 91,160 2065 49,158 15,047 970 17,289 15,821 98,286 2066 32,939 4,674 794 2,099 3,104 43,610 2067 32,939 4,674 794 2,099 3,104 43,610 2068 2,841 332 41 116 1,012 4,342 2069 16,767 723 140 23 1,456 19,109 2070 16,433 6,819 115 3

800 24,170 2071 15,613 7,393 106 0

706 23,818 2072 8,897 4,213 60 0

402 13,573 Total 410,353 76,651 9,864 33,260 91,003 621,131

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

Equipment &

Year Labor Materials Energy Burial Other Total 2046 6,969 169 162 7

358 7,664 2047 48,137 2,813 1,059 360 4,276 56,645 2048 15,339 2,514 505 823 18,185 37,365 2049 5,877 262 212 27 2,685 9,062 2050 5,877 262 212 27 2,685 9,062 2051 5,877 262 212 27 2,685 9,062 2052 5,893 263 212 27 2,692 9,087 2053 5,877 262 212 27 2,685 9,062 2054 5,877 262 212 27 2,685 9,062 2055 5,877 262 212 27 2,685 9,062 2056 5,893 263 212 27 2,692 9,087 2057 5,877 262 212 27 2,685 9,062 2058 5,877 262 212 27 2,685 9,062 2059 6,740 2,850 212 27 2,685 12,512 2060 7,618 5,438 212 27 2,692 15,987 2061 5,925 3,818 167 27 2,137 12,073 2062 3,604 1,551 106 26 1,386 6,673 2063 4,193 424 239 27 1,214 6,098 2064 27,345 2,037 1,061 34 1,706 32,184 2065 48,745 12,487 1,025 10,208 11,672 84,137 2066 54,727 13,164 941 11,952 11,887 92,670 2067 50,211 5,573 794 2,914 2,997 62,489 2068 50,348 5,588 796 2,922 3,006 62,660 2069 35,623 2,737 410 1,010 1,997 41,777 2070 21,292 10,032 116 3

779 32,222 2071 20,591 10,932 106 0

707 32,335 2072 11,790 6,259 61 0

405 18,515 Total 478,002 91,008 10,089 30,633 94,950 704,681

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TABLE 3.3a BYRON NUCLEAR POWER STATION, UNIT 1 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2044 7,452 1,359 180 7

2,355 11,352 2045 45,333 9,626 1,059 357 14,066 70,440 2046 12,346 8,610 490 533 7,817 29,796 2047 5,658 6,725 212 27 4,383 17,004 2048 5,673 6,743 212 27 4,395 17,051 2049 5,658 6,725 212 27 4,383 17,004 2050 3,894 2,382 141 26 2,387 8,830 2051 3,030 254 106 26 1,410 4,826 2052 3,038 255 106 26 1,414 4,839 2053 3,030 254 106 26 1,410 4,826 2054 3,030 254 106 26 1,410 4,826 2055 3,030 254 106 26 1,410 4,826 2056 3,038 255 106 26 1,414 4,839 2057 3,138 578 106 26 1,410 5,257 2058 3,461 1,548 106 26 1,410 6,551 2059 3,461 1,548 106 26 1,410 6,551 2060 3,469 1,549 106 26 1,414 6,564 2061 3,461 1,548 106 26 1,410 6,551 2062 3,458 1,548 106 26 1,409 6,548 2063 1,992 252 106 26 1,218 3,594 2064 1,998 253 106 26 1,221 3,604 2065 1,992 252 106 26 1,218 3,594 2066 1,992 252 106 26 1,218 3,594 2067 1,992 252 106 26 1,218 3,594 2068 1,998 253 106 26 1,221 3,604 2069 1,992 252 106 26 1,218 3,594 2070 1,992 252 106 26 1,218 3,594 2071 1,992 252 106 26 1,218 3,594 2072 1,998 253 106 26 1,221 3,604 2073 1,992 252 106 26 1,218 3,594

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TABLE 3.3a (continued)

BYRON NUCLEAR POWER STATION, UNIT 1 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2074 1,992 252 106 26 1,218 3,594 2075 1,992 252 106 26 1,218 3,594 2076 1,998 253 106 26 1,221 3,604 2077 1,992 252 106 26 1,218 3,594 2078 1,992 252 106 26 1,218 3,594 2079 1,992 252 106 26 1,218 3,594 2080 1,998 253 106 26 1,221 3,604 2081 1,992 252 106 26 1,218 3,594 2082 1,992 252 106 26 1,218 3,594 2083 1,992 252 106 26 1,218 3,594 2084 1,998 253 106 26 1,221 3,604 2085 1,992 252 106 26 1,218 3,594 2086 1,992 252 106 26 1,218 3,594 2087 1,992 252 106 26 1,218 3,594 2088 1,998 253 106 26 1,221 3,604 2089 1,992 252 106 26 1,218 3,594 2090 1,992 252 106 26 1,218 3,594 2091 1,992 252 106 26 1,218 3,594 2092 1,998 253 106 26 1,221 3,604 2093 1,992 252 106 26 1,218 3,594 2094 1,992 252 106 26 1,218 3,594 2095 1,992 252 106 26 1,218 3,594 2096 1,998 253 106 26 1,221 3,604 2097 8,858 475 276 28 1,231 10,867 2098 43,490 2,197 1,059 37 2,569 49,352 2099 53,952 13,527 1,023 12,949 15,356 96,808 2100 45,185 12,653 927 12,726 12,857 84,347 2101 32,950 4,635 794 1,966 3,109 43,454 2102 28,076 3,938 672 1,665 2,769 37,121 2103 1,182 94 0

7 894 2,176

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TABLE 3.3a (continued)

BYRON NUCLEAR POWER STATION, UNIT 1 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2104 21,410 2,057 177 24 1,503 25,171 2105 15,910 7,438 106 0

706 24,160 2106 15,910 7,438 106 0

706 24,160 2107 4,926 2,303 33 0

219 7,480 Total 464,295 117,349 12,550 31,605 140,068 765,867

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TABLE 3.3b BYRON NUCLEAR POWER STATION, UNIT 2 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2046 7,398 1,360 162 7

2,087 11,014 2047 50,892 10,446 1,059 360 13,817 76,574 2048 18,725 10,148 505 823 19,431 49,632 2049 9,706 8,238 212 27 4,581 22,764 2050 9,706 8,238 212 27 4,581 22,764 2051 9,706 8,238 212 27 4,581 22,764 2052 5,465 3,013 143 27 2,493 11,140 2053 3,215 258 106 26 1,386 4,991 2054 3,215 258 106 26 1,386 4,991 2055 3,215 258 106 26 1,386 4,991 2056 3,224 258 106 26 1,390 5,005 2057 3,323 581 106 26 1,386 5,422 2058 3,646 1,551 106 26 1,386 6,716 2059 3,646 1,551 106 26 1,386 6,716 2060 3,655 1,552 106 26 1,390 6,730 2061 3,646 1,551 106 26 1,386 6,716 2062 3,643 1,551 106 26 1,386 6,712 2063 1,970 255 106 26 1,206 3,562 2064 1,975 255 106 26 1,209 3,572 2065 1,970 255 106 26 1,206 3,562 2066 1,970 255 106 26 1,206 3,562 2067 1,970 255 106 26 1,206 3,562 2068 1,975 255 106 26 1,209 3,572 2069 1,970 255 106 26 1,206 3,562 2070 1,970 255 106 26 1,206 3,562 2071 1,970 255 106 26 1,206 3,562 2072 1,975 255 106 26 1,209 3,572 2073 1,970 255 106 26 1,206 3,562 2074 1,970 255 106 26 1,206 3,562

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TABLE 3.3b (continued)

BYRON NUCLEAR POWER STATION, UNIT 2 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2075 1,970 255 106 26 1,206 3,562 2076 1,975 255 106 26 1,209 3,572 2077 1,970 255 106 26 1,206 3,562 2078 1,970 255 106 26 1,206 3,562 2079 1,970 255 106 26 1,206 3,562 2080 1,975 255 106 26 1,209 3,572 2081 1,970 255 106 26 1,206 3,562 2082 1,970 255 106 26 1,206 3,562 2083 1,970 255 106 26 1,206 3,562 2084 1,975 255 106 26 1,209 3,572 2085 1,970 255 106 26 1,206 3,562 2086 1,970 255 106 26 1,206 3,562 2087 1,970 255 106 26 1,206 3,562 2088 1,975 255 106 26 1,209 3,572 2089 1,970 255 106 26 1,206 3,562 2090 1,970 255 106 26 1,206 3,562 2091 1,970 255 106 26 1,206 3,562 2092 1,975 255 106 26 1,209 3,572 2093 1,970 255 106 26 1,206 3,562 2094 1,970 255 106 26 1,206 3,562 2095 1,970 255 106 26 1,206 3,562 2096 1,975 255 106 26 1,209 3,572 2097 1,970 255 106 26 1,206 3,562 2098 11,215 725 471 29 1,224 13,664 2099 29,299 2,958 1,059 35 2,434 35,784 2100 53,037 15,268 1,012 12,634 14,475 96,425 2101 52,596 10,342 886 7,803 8,573 80,199 2102 50,293 5,488 794 2,741 2,944 62,259 2103 50,293 5,488 794 2,741 2,944 62,259 2104 28,823 3,248 242 249 1,477 34,039

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TABLE 3.3b (continued)

BYRON NUCLEAR POWER STATION, UNIT 2 SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (thousands, 2009 dollars)

Equipment &

Year Labor Materials Energy Burial Other Total 2105 20,888 10,976 106 0

707 32,677 2106 20,888 10,976 106 0

707 32,677 2107 6,524 3,428 33 0

221 10,206 Total 538,870 136,868 12,773 28,702 143,390 860,604

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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 pool within the first five and one-half 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 fuel handling building is isolated until such time that all spent fuel has been discharged to the ISFSI. Decontamination and dismantling of the storage pool 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 Byron.

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 fuel handling 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 4.2 DECOMMISSIONING TIMELINE DECON (not to scale)

Unit 1 (Shutdown October 31, 2044)

Unit 2 (Shutdown November 06, 2046)

ISFSI Operations Pool and ISFSI Operations Storage Pool Empty 05/2052 Period 1 Transition and Preparations 10/2044 05/2046 03/2056 07/2063 Period 2 Decommissioning Period 3 Site Restoration ISFSI Operations 12/2062 ISFSI D&D 09/2053 Period 1 Transition and Preparations 11/2046 05/2048 03/2056 07/2063 Period 2 Decommissioning Period 3 Site Restoration ISFSI Operations 12/2062 ISFSI D&D 09/2053

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FIGURE 4.3 DECOMMISSIONING TIMELINE DELAYED DECON (not to scale)

Unit 1 (Shutdown October 31, 2044)

Unit 2 (Shutdown November 06, 2046)

Spent Fuel Storage ISFSI/ Storage Pool Empty 12/2062 Period 1 Transition and Preparations 10/2044 05/2046 02/2070 07/2072 07/2064 Period 2 Dormancy 12/2062 Period 3 Delayed Preparations Period 4 Decommissioning Period 5 Site Restoration Period 1 Transition and Preparations 11/2046 05/2048 02/2070 07/2072 05/2065 Period 2 Dormancy 11/2063 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 October 31, 2044)

Unit 2 (Shutdown November 06, 2046)

ISFSI Empty 12/2062 Spent Fuel Storage Storage Pool Empty 05/2052 Period 1 Transition and Preparations 10/2044 05/2046 10/2104 04/2107 04/2099 Period 2 Dormancy 10/2097 Period 3 Delayed Preparations Period 4 Decommissioning Period 5 Site Restoration Period 1 Transition and Preparations 11/2046 05/2048 10/2104 04/2107 02/2100 Period 2 Dormancy 08/2098 Period 3 Delayed Preparations Period 4 Decommissioning Period 5 Site Restoration Storage Pool Empty 05/2052

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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 Byron 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

222,339 20,932,728 Barnwell B

8,007 997,337 Low-Level Radioactive Waste (near-surface disposal)

Barnwell C

918 96,896 Greater than Class C (geologic repository)

Spent Fuel Equivalent GTCC 1,010 208,292 Processed/Conditioned (off-site recycling center)

Recycling Vendors A

378,839 14,650,380 Total [2]

611,113 36,885,633 Scrap Metal 267,118,000

[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

186,367 16,600,261 Barnwell B

6,260 803,190 Low-Level Radioactive Waste (near-surface disposal)

Barnwell C

918 96,896 Greater than Class C (geologic repository)

Spent Fuel Equivalent GTCC 1,010 208,292 Processed/Conditioned (off-site recycling center)

Recycling Vendors A

441,235 17,211,193 Total [2]

635,790 34,919,832 Scrap Metal 267,298,000

[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

206,908 16,786,199 Barnwell B

5,258 692,576 Low-Level Radioactive Waste (near-surface disposal)

Barnwell C

939 95,516 Greater than Class C (geologic repository)

Spent Fuel Equivalent GTCC 1,010 208,292 Processed/Conditioned (off-site recycling center)

Recycling Vendors A

444,712 17,485,754 Total [2]

658,828 35,268,337 Scrap Metal 267,298,000

[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 Byron 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 pool 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 pool in the Delayed-DECON alternative.

The cost projected to promptly decommission (DECON) Byron is estimated to be

$1,351.7 million. The majority of this cost (approximately 71.7%) is associated with the physical decontamination and dismantling of the nuclear units so that the licenses can be terminated. Another 16.8% is associated with the management, interim storage, and eventual transfer of the spent fuel. The remaining 11.5% 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 pool will remain operational for a minimum of five and one-half years following the cessation of operations. The pool

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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 future 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 33,761 2.5 Removal 242,355 17.9 Packaging 29,594 2.2 Transportation 20,501 1.5 Waste Disposal 119,478 8.8 Off-site Waste Processing 8,002 0.6 Program Management [1]

590,277 43.7 Spent Fuel Pool Isolation 11,143 0.8 Spent Fuel Management [2]

163,436 12.1 Insurance and Regulatory Fees 22,834 1.7 Energy 12,320 0.9 Characterization and Licensing Surveys 31,452 2.3 Property Taxes 48,613 3.6 Miscellaneous Equipment 12,886 1.0 Site O&M 5,087 0.4 Total [3]

1,351,738 100.0 Cost Element Total Percentage NRC License Termination 969,616 71.7 Spent Fuel Management 226,513 16.8 Site Restoration 155,609 11.5 Total [3]

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 29,063 2.2 Removal 238,567 18.0 Packaging 22,496 1.7 Transportation 17,713 1.3 Waste Disposal 81,335 6.1 Off-site Waste Processing 9,386 0.7 Program Management [1]

689,226 52.0 Spent Fuel Pool Isolation 11,143 0.8 Spent Fuel Management [2]

52,833 4.0 Insurance and Regulatory Fees 33,232 2.5 Energy 19,953 1.5 Characterization and Licensing Surveys 34,391 2.6 Property Taxes 58,566 4.4 Miscellaneous Equipment 20,223 1.5 Site O&M 7,685 0.6 Total [3]

1,325,812 100.0 Cost Element Total Percentage NRC License Termination 920,333 69.4 Spent Fuel Management 247,333 18.7 Site Restoration 158,146 11.9 Total [3]

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 28,655 1.8 Removal 246,250 15.1 Packaging 22,253 1.4 Transportation 17,030 1.0 Waste Disposal 77,601 4.8 Off-site Waste Processing 9,535 0.6 Program Management [1]

779,393 47.9 Spent Fuel Pool Isolation 11,143 0.7 Spent Fuel Management [2]

160,078 9.8 Insurance and Regulatory Fees 68,485 4.2 Energy 25,323 1.6 Characterization and Licensing Surveys 34,391 2.1 Property Taxes 96,771 5.9 Miscellaneous Equipment 31,890 2.0 Site O&M 17,672 1.1 Total [3]

1,626,471 100.0 Cost Element Total Percentage NRC License Termination 1,227,034 75.4 Spent Fuel Management 241,192 14.8 Site Restoration 158,245 9.7 Total [3]

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 Byron Nuclear Power Station, Document No. E16-1455-012, 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

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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

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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-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

Byron Nuclear Power Station Document E16-1555-013, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 3 of 4 TLG Services, Inc.

APPENDIX A (Continued)

3.

LABOR REQUIRED Duration Rate Crew Number (Hours)

($/hr)

Cost Laborers 3.00 11.217 49.58 1668.42 Craftsmen 2.00 11.217 59.41 1332.80 Foreman 1.00 11.217 63.69 714.41 General Foreman 0.25 11.217 64.84 181.83 Fire Watch 0.05 11.217 49.58 27.81 Health Physics Technician 1.00 11.217 51.42 576.78 Total labor cost

$4,502.05

4.

EQUIPMENT & CONSUMABLES COSTS Equipment Costs none Consumables/Materials Costs



Blotting paper 50 @ $0.52/sq ft {1}

$26.00



Plastic sheets/bags 50 @ $0.39/sq ft {2}

$19.50



Gas torch consumables 1 @ $9.10 x 1 /hr {3}

$9.10 Subtotal cost of equipment and materials

$54.60 Overhead & profit on equipment and materials @ 16.25 %

$8.87 Total costs, equipment & material

$63.47 TOTAL COST:

Removal of contaminated heat exchanger <3000 pounds:

$4,565.52 Total labor cost:

$4,502.05 Total equipment/material costs:

$63.47 Total craft labor man-hours required per unit:

81.88

Byron Nuclear Power Station Document E16-1555-013, 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 658



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

Byron Nuclear Power Station Document E16-1555-013, 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)

Byron Nuclear Power Station Document E16-1555-013, 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 0.53 Removal of clean pipe 0.25 to 2 inches diameter, $/linear foot 5.71 Removal of clean pipe >2 to 4 inches diameter, $/linear foot 8.08 Removal of clean pipe >4 to 8 inches diameter, $/linear foot 15.49 Removal of clean pipe >8 to 14 inches diameter, $/linear foot 30.16 Removal of clean pipe >14 to 20 inches diameter, $/linear foot 39.10 Removal of clean pipe >20 to 36 inches diameter, $/linear foot 57.56 Removal of clean pipe >36 inches diameter, $/linear foot 68.44 Removal of clean valve >2 to 4 inches 103.46 Removal of clean valve >4 to 8 inches 154.89 Removal of clean valve >8 to 14 inches 301.57 Removal of clean valve >14 to 20 inches 391.05 Removal of clean valve >20 to 36 inches 575.58 Removal of clean valve >36 inches 684.35 Removal of clean pipe hanger for small bore piping 33.83 Removal of clean pipe hanger for large bore piping 124.83 Removal of clean pump, <300 pound 259.08 Removal of clean pump, 300-1000 pound 714.59 Removal of clean pump, 1000-10,000 pound 2,848.15 Removal of clean pump, >10,000 pound 5,500.79 Removal of clean pump motor, 300-1000 pound 301.00 Removal of clean pump motor, 1000-10,000 pound 1,186.77 Removal of clean pump motor, >10,000 pound 2,670.24 Removal of clean heat exchanger <3000 pound 1,526.87 Removal of clean heat exchanger >3000 pound 3,833.21 Removal of clean feedwater heater/deaerator 10,823.57 Removal of clean moisture separator/reheater 22,275.78 Removal of clean tank, <300 gallons 333.53 Removal of clean tank, 300-3000 gallon 1,055.77 Removal of clean tank, >3000 gallons, $/square foot surface area 8.74

Byron Nuclear Power Station Document E16-1555-013, 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 142.34 Removal of clean electrical equipment, 300-1000 pound 490.07 Removal of clean electrical equipment, 1000-10,000 pound 980.14 Removal of clean electrical equipment, >10,000 pound 2,323.47 Removal of clean electrical transformer < 30 tons 1,613.62 Removal of clean electrical transformer > 30 tons 4,646.93 Removal of clean standby diesel generator, <100 kW 1,648.17 Removal of clean standby diesel generator, 100 kW to 1 MW 3,678.82 Removal of clean standby diesel generator, >1 MW 7,615.89 Removal of clean electrical cable tray, $/linear foot 13.24 Removal of clean electrical conduit, $/linear foot 5.78 Removal of clean mechanical equipment, <300 pound 142.34 Removal of clean mechanical equipment, 300-1000 pound 490.07 Removal of clean mechanical equipment, 1000-10,000 pound 980.14 Removal of clean mechanical equipment, >10,000 pound 2,323.47 Removal of clean HVAC equipment, <300 pound 172.12 Removal of clean HVAC equipment, 300-1000 pound 588.85 Removal of clean HVAC equipment, 1000-10,000 pound 1,173.58 Removal of clean HVAC equipment, >10,000 pound 2,323.47 Removal of clean HVAC ductwork, $/pound 0.56 Removal of contaminated instrument and sampling tubing, $/linear foot 1.64 Removal of contaminated pipe 0.25 to 2 inches diameter, $/linear foot 23.00 Removal of contaminated pipe >2 to 4 inches diameter, $/linear foot 39.35 Removal of contaminated pipe >4 to 8 inches diameter, $/linear foot 61.60 Removal of contaminated pipe >8 to 14 inches diameter, $/linear foot 121.41 Removal of contaminated pipe >14 to 20 inches diameter, $/linear foot 145.75 Removal of contaminated pipe >20 to 36 inches diameter, $/linear foot 201.70 Removal of contaminated pipe >36 inches diameter, $/linear foot 238.43 Removal of contaminated valve >2 to 4 inches 469.60 Removal of contaminated valve >4 to 8 inches 561.54

Byron Nuclear Power Station Document E16-1555-013, 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 1,161.22 Removal of contaminated valve >14 to 20 inches 1,474.93 Removal of contaminated valve >20 to 36 inches 1,964.14 Removal of contaminated valve >36 inches 2,331.38 Removal of contaminated pipe hanger for small bore piping 153.30 Removal of contaminated pipe hanger for large bore piping 514.71 Removal of contaminated pump, <300 pound 999.58 Removal of contaminated pump, 300-1000 pound 2,300.95 Removal of contaminated pump, 1000-10,000 pound 7,550.63 Removal of contaminated pump, >10,000 pound 18,387.13 Removal of contaminated pump motor, 300-1000 pound 982.18 Removal of contaminated pump motor, 1000-10,000 pound 3,076.84 Removal of contaminated pump motor, >10,000 pound 6,907.88 Removal of contaminated heat exchanger <3000 pound 4,565.52 Removal of contaminated heat exchanger >3000 pound 13,230.07 Removal of contaminated tank, <300 gallons 1,663.46 Removal of contaminated tank, >300 gallons, $/square foot 32.22 Removal of contaminated electrical equipment, <300 pound 777.90 Removal of contaminated electrical equipment, 300-1000 pound 1,880.72 Removal of contaminated electrical equipment, 1000-10,000 pound 3,622.51 Removal of contaminated electrical equipment, >10,000 pound 7,096.37 Removal of contaminated electrical cable tray, $/linear foot 37.48 Removal of contaminated electrical conduit, $/linear foot 18.33 Removal of contaminated mechanical equipment, <300 pound 865.36 Removal of contaminated mechanical equipment, 300-1000 pound 2,076.85 Removal of contaminated mechanical equipment, 1000-10,000 pound 3,993.74 Removal of contaminated mechanical equipment, >10,000 pound 7,096.37 Removal of contaminated HVAC equipment, <300 pound 865.36 Removal of contaminated HVAC equipment, 300-1000 pound 2,076.85 Removal of contaminated HVAC equipment, 1000-10,000 pound 3,993.74

Byron Nuclear Power Station Document E16-1555-013, 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, >10,000 pound 7,096.37 Removal of contaminated HVAC ductwork, $/pound 2.24 Removal/plasma arc cut of contaminated thin metal components, $/linear in.

4.14 Additional decontamination of surface by washing, $/square foot 8.72 Additional decontamination of surfaces by hydrolasing, $/square foot 35.95 Decontamination rig hook up and flush, $/ 250 foot length 7,294.00 Chemical flush of components/systems, $/gallon 15.15 Removal of clean standard reinforced concrete, $/cubic yard 139.10 Removal of grade slab concrete, $/cubic yard 189.47 Removal of clean concrete floors, $/cubic yard 362.61 Removal of sections of clean concrete floors, $/cubic yard 1,090.16 Removal of clean heavily rein concrete w/#9 rebar, $/cubic yard 236.32 Removal of contaminated heavily rein concrete w/#9 rebar, $/cubic yard 2,177.81 Removal of clean heavily rein concrete w/#18 rebar, $/cubic yard 298.70 Removal of contaminated heavily rein concrete w/#18 rebar, $/cubic yard 2,880.30 Removal heavily rein concrete w/#18 rebar & steel embedments, $/cubic yard 463.41 Removal of below-grade suspended floors, $/cubic yard 362.61 Removal of clean monolithic concrete structures, $/cubic yard 921.99 Removal of contaminated monolithic concrete structures, $/cubic yard 2,168.42 Removal of clean foundation concrete, $/cubic yard 722.53 Removal of contaminated foundation concrete, $/cubic yard 2,019.76 Explosive demolition of bulk concrete, $/cubic yard 30.96 Removal of clean hollow masonry block wall, $/cubic yard 102.57 Removal of contaminated hollow masonry block wall, $/cubic yard 339.31 Removal of clean solid masonry block wall, $/cubic yard 102.57 Removal of contaminated solid masonry block wall, $/cubic yard 339.31 Backfill of below-grade voids, $/cubic yard 21.91 Removal of subterranean tunnels/voids, $/linear foot 116.60 Placement of concrete for below-grade voids, $/cubic yard 129.61 Excavation of clean material, $/cubic yard 2.87

Byron Nuclear Power Station Document E16-1555-013, 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.

Excavation of contaminated material, $/cubic yard 39.98 Removal of clean concrete rubble (tipping fee included), $/cubic yard 22.39 Removal of contaminated concrete rubble, $/cubic yard 25.54 Removal of building by volume, $/cubic foot 0.30 Removal of clean building metal siding, $/square foot 1.25 Removal of contaminated building metal siding, $/square foot 4.30 Removal of standard asphalt roofing, $/square foot 2.50 Removal of transite panels, $/square foot 2.23 Scarifying contaminated concrete surfaces (drill & spall), $/square foot 12.96 Scabbling contaminated concrete floors, $/square foot 8.13 Scabbling contaminated concrete walls, $/square foot 21.63 Scabbling contaminated ceilings, $/square foot 74.39 Scabbling structural steel, $/square foot 6.59 Removal of clean overhead crane/monorail < 10 ton capacity 677.14 Removal of contaminated overhead crane/monorail < 10 ton capacity 1,896.33 Removal of clean overhead crane/monorail >10-50 ton capacity 1,625.13 Removal of contaminated overhead crane/monorail >10-50 ton capacity 4,550.39 Removal of polar crane > 50 ton capacity 6,778.59 Removal of gantry crane > 50 ton capacity 29,043.29 Removal of structural steel, $/pound 0.22 Removal of clean steel floor grating, $/square foot 4.67 Removal of contaminated steel floor grating, $/square foot 13.54 Removal of clean free standing steel liner, $/square foot 13.10 Removal of contaminated free standing steel liner, $/square foot 37.73 Removal of clean concrete-anchored steel liner, $/square foot 6.55 Removal of contaminated concrete-anchored steel liner, $/square foot 43.94 Placement of scaffolding in clean areas, $/square foot 17.02 Placement of scaffolding in contaminated areas, $/square foot 27.95 Landscaping with topsoil, $/acre 18,899.01 Cost of CPC B-88 LSA box & preparation for use 2,034.80

Byron Nuclear Power Station Document E16-1555-013, 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.

Cost of CPC B-25 LSA box & preparation for use 1,683.27 Cost of CPC B-12V 12 gauge LSA box & preparation for use 1,519.56 Cost of CPC B-144 LSA box & preparation for use 8,836.80 Cost of LSA drum & preparation for use 180.73 Cost of cask liner for CNSI 14 195 cask 257.57 Cost of cask liner for CNSI 8 120A cask (resins) 7,454.81 Cost of cask liner for CNSI 8 120A cask (filters) 7,928.96 Decontamination of surfaces with vacuuming, $/square foot 0.81

Byron Nuclear Power Station Document E16-1555-013, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 1 of 22 TLG Services, Inc.

APPENDIX C DETAILED COST ANALYSIS DECON Page Byron Nuclear Power Station, Unit 1...........................................................................C-2 Byron Nuclear Power Station, Unit 2........................................................................C-12

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 2 of 22 Table C-1 Byron Nuclear Power Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:02:56 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 Biological shield 59 9

68 68 500 1a.1.17.7 Steam generators 368 55 423 423 3,120 1a.1.17.8 Reinforced concrete 189 28 217 109 109 1,600 1a.1.17.9 Main Turbine 47 7

54 54 400 1a.1.17.10 Main Condensers 47 7

54 54 400 1a.1.17.11 Plant structures & buildings 368 55 423 212 212 3,120 1a.1.17.12 Waste management 543 81 624 624 4,600 1a.1.17.13 Facility & site closeout 106 16 122 61 61 900 1a.1.17 Total 4,464 670 5,134 4,520 613 37,827 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 13,704 2,056 15,759 15,146 613 73,753 Period 1a Additional Costs 1a.2.1 ISFSI Expansion 9,800 1,470 11,270 11,270 1a.2 Subtotal Period 1a Additional Costs 9,800 1,470 11,270 11,270 Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 8,000 1,200 9,200 9,200 1a.3 Subtotal Period 1a Collateral Costs 8,000 1,200 9,200 9,200 Period 1a Period-Dependent Costs 1a.4.1 Insurance 769 77 846 846 1a.4.2 Property taxes 1a.4.3 Health physics supplies 414 104 518 518 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 3 of 22 Table C-1 Byron Nuclear Power Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:02:56 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.4.4 Heavy equipment rental 414 62 476 476 1a.4.5 Disposal of DAW generated 2

1 34 9

45 45 610 12,190 3

1a.4.6 Plant energy budget 921 138 1,059 1,059 1a.4.7 NRC Fees 706 71 776 776 1a.4.8 Emergency Planning Fees 306 31 337 337 1a.4.9 Site O&M Costs 125 19 144 144 1a.4.10 Spent Fuel Pool O&M 381 57 438 438 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 470 71 541 541 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 828 2

1 34 34,805 5,306 40,975 40,149 826 610 12,190 3

435,664 1a.0 TOTAL PERIOD 1a COST 828 2

1 34 66,308 10,032 77,204 55,295 21,296 613 610 12,190 3

509,417 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 295 44 339 339 2,500 1b.1.1.4 Remaining buildings 159 24 183 46 137 1,350 1b.1.1.5 CRD cooling assembly 118 18 136 136 1,000 1b.1.1.6 CRD housings & ICI tubes 118 18 136 136 1,000 1b.1.1.7 Incore instrumentation 118 18 136 136 1,000 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 Missile shields 53 8

61 61 450 1b.1.1.11 Biological shield 142 21 163 163 1,200 1b.1.1.12 Steam generators 543 81 624 624 4,600 1b.1.1.13 Reinforced concrete 118 18 136 68 68 1,000 1b.1.1.14 Main Turbine 184 28 212 212 1,560 1b.1.1.15 Main Condensers 184 28 212 212 1,560 1b.1.1.16 Auxiliary building 322 48 370 333 37 2,730 1b.1.1.17 Reactor building 322 48 370 333 37 2,730 1b.1.1 Total 3,923 588 4,511 3,663 848 33,243 1b.1.2 Decon primary loop 614 307 921 921 1,067 1b.1 Subtotal Period 1b Activity Costs 614 3,923 896 5,433 4,584 848 1,067 33,243 Period 1b Additional Costs 1b.2.1 Site Characterization 6,341 1,902 8,243 8,243 30,500 10,852 1b.2 Subtotal Period 1b Additional Costs 6,341 1,902 8,243 8,243 30,500 10,852 Period 1b Collateral Costs 1b.3.1 Decon equipment 797 120 917 917 1b.3.2 DOC staff relocation expenses 1,130 169 1,299 1,299 1b.3.3 Process liquid waste 57 79 371 3,379 937 4,823 4,823 375 889 121,195 246 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 1b.3.7 Spent Fuel Capital and Transfer 4,000 600 4,600 4,600 1b.3 Subtotal Period 1b Collateral Costs 2,254 1,102 79 371 3,379 5,130 2,201 14,516 9,916 4,600 375 889 121,195 246 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 4 of 22 Table C-1 Byron Nuclear Power Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:02:56 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 Period-Dependent Costs 1b.4.1 Decon supplies 24 6

31 31 1b.4.2 Insurance 386 39 424 424 1b.4.3 Property taxes 4,927 493 5,420 5,420 1b.4.4 Health physics supplies 233 58 292 292 1b.4.5 Heavy equipment rental 207 31 238 238 1b.4.6 Disposal of DAW generated 1

0 20 5

27 27 358 7,159 2

1b.4.7 Plant energy budget 923 138 1,061 1,061 1b.4.8 NRC Fees 354 35 389 389 1b.4.9 Emergency Planning Fees 154 15 169 169 1b.4.10 Site O&M Costs 63 9

72 72 1b.4.11 Spent Fuel Pool O&M 191 29 220 220 1b.4.12 ISFSI Operating Costs 22 3

25 25 1b.4.13 Security Staff Cost 236 35 271 271 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 24 441 1

0 20 28,123 4,028 32,638 32,224 414 358 7,159 2

283,263 1b.0 TOTAL PERIOD 1b COST 2,893 1,543 80 372 3,399 43,517 9,027 60,830 54,967 5,014 848 733 889 128,354 31,815 327,358 PERIOD 1 TOTALS 2,893 2,371 81 372 3,433 109,825 19,059 138,034 110,262 26,310 1,462 1,342 889 140,544 31,818 836,775 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.1 Reactor Coolant Piping 181 154 31 37 331 220 955 955 1,677 202,809 5,830 2a.1.1.2 Pressurizer Relief Tank 32 29 6

7 60 40 174 174 329 36,553 1,072 2a.1.1.3 Reactor Coolant Pumps & Motors 103 106 91 180 1,272 432 2,184 2,184 4,796 780,540 4,291 100 2a.1.1.4 Pressurizer 48 59 394 96 412 196 1,205 1,205 3,033 252,826 2,482 938 2a.1.1.5 Steam Generators 387 4,096 2,982 2,549 667 4,349 3,085 18,115 18,115 45,513 17,817 4,035,428 23,233 2,125 2a.1.1.6 Retired Steam Generator Units 1,475 2,644 580 3,416 1,485 9,600 9,600 39,289 14,064 3,041,432 10,800 1,500 2a.1.1.7 CRDMs/ICIs/Service Structure Removal 161 91 194 45 102 155 747 747 3,881 86,025 4,285 2a.1.1.8 Reactor Vessel Internals 125 2,193 4,483 876 8,058 233 7,111 23,078 23,078 1,377 903 459 326,029 26,933 1,209 2a.1.1.9 Reactor Vessel 95 4,162 1,498 675 7,844 233 7,669 22,176 22,176 6,606 2,254 978,589 26,933 1,209 2a.1.1 Totals 1,132 10,889 11,154 7,110 1,247 25,843 466 20,393 78,234 78,234 84,802 53,580 3,156 459 9,740,230 105,861 7,082 Removal of Major Equipment 2a.1.2 Main Turbine/Generator 578 378 30 203 284 288 1,762 1,762 5,088 2,833 686,663 10,223 2a.1.3 Main Condensers 1,163 166 58 143 211 390 2,131 2,131 6,756 1,992 482,702 20,428 Cascading Costs from Clean Building Demolition 2a.1.4.1 Reactor 1,076 161 1,237 1,237 12,130 2a.1.4.2 Auxiliary Building 594 89 683 683 6,810 2a.1.4.3 Refueling Water Storage Tank 104 16 120 120 1,299 2a.1.4 Totals 1,773 266 2,039 2,039 20,238 Disposal of Plant Systems 2a.1.5.1 Auxiliary Feedwater 69 10 79 79 1,244 2a.1.5.2 Auxiliary Steam 61 9

71 71 1,126 2a.1.5.3 Auxiliary Steam RCA 122 6

5 9

21 38 200 200 448 197 35,862 1,946 2a.1.5.4 Boric Acid Processing 451 492 51 39 57 182 414 1,686 1,686 2,981 2,231 275,609 15,951 2a.1.5.5 CO2 & H2 23 3

26 26 419 2a.1.5.6 CO2 & H2 RCA 35 1

1 1

5 11 55 55 67 50 7,168 575 2a.1.5.7 Chemical Feed 51 8

58 58 934 2a.1.5.8 Chilled Water 63 9

72 72 1,142 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 5 of 22 Table C-1 Byron Nuclear Power Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:02:56 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.1.5.9 Circulating Water 279 42 321 321 5,150 2a.1.5.10 Condensate 331 50 381 381 6,023 2a.1.5.11 Condensate Booster 299 45 344 344 5,428 2a.1.5.12 Condensate Cleanup 58 9

67 67 1,060 2a.1.5.13 Containment Spray 233 17 18 49 57 84 458 458 2,566 543 152,670 3,755 2a.1.5.14 Diesel Fuel Oil 90 13 103 103 1,615 2a.1.5.15 Essential Service Water 208 31 239 239 3,837 2a.1.5.16 Extraction Steam 167 25 192 192 3,089 2a.1.5.17 Feedwater 278 42 320 320 5,142 2a.1.5.18 Feedwater Drains 668 100 768 768 12,366 2a.1.5.19 Gland Steam 50 8

58 58 932 2a.1.5.20 Gland Water 44 7

51 51 828 2a.1.5.21 Main Steam 284 43 326 326 5,216 2a.1.5.22 Main Steam RCA 46 4

4 9

16 18 97 97 468 148 32,263 745 2a.1.5.23 Nitrogen 3

0 0

1 0

1 5

5 49 2

2,118 49 2a.1.5.24 Non-Essential Service Water 157 23 180 180 2,916 2a.1.5.25 Non-Essential Service Water RCA 86 8

8 17 30 34 182 182 897 287 62,152 1,308 2a.1.5.26 Off Gas 566 27 28 71 101 184 976 976 3,698 953 235,620 9,534 2a.1.5.27 Process Radiation Monitoring 41 1

1 1

2 11 57 57 75 19 4,792 748 2a.1.5.28 Process Sampling 120 2

3 9

8 34 176 176 466 76 25,755 2,166 2a.1.5.29 Station Air 27 4

31 31 498 2a.1.5.30 Station Heating 96 14 111 111 1,771 2a.1.5.31 Switchgear Heat Removal 8

1 9

9 139 2a.1.5.32 Turbine Bldg Equip Drains 1

0 1

1 17 2a.1.5.33 Turbine Generator 50 8

58 58 901 2a.1.5.34 Turbine Oil 77 12 88 88 1,399 2a.1.5.35 Waste Oil Sumps 26 4

30 30 483 2a.1.5 Totals 451 5,208 116 106 224 423 1,348 7,876 3,893 3,984 11,715 4,504 834,009 100,448 2a.1.6 Scaffolding in support of decommissioning 980 6

1 6

2 247 1,243 1,243 306 19 15,459 18,871 2a.1 Subtotal Period 2a Activity Costs 1,584 20,592 11,820 7,306 1,823 26,763 466 22,933 93,285 89,302 3,984 108,666 62,929 3,156 459 11,759,060 276,069 7,082 Period 2a Collateral Costs 2a.3.1 Process liquid waste 206 94 434 449 290 1,473 1,473 1,518 96,822 296 2a.3.2 Small tool allowance 243 36 279 251 28 2a.3.3 Spent Fuel Capital and Transfer 11,000 1,650 12,650 12,650 2a.3 Subtotal Period 2a Collateral Costs 206 243 94 434 449 11,000 1,976 14,402 1,724 12,650 28 1,518 96,822 296 Period 2a Period-Dependent Costs 2a.4.1 Decon supplies 72 18 90 90 2a.4.2 Insurance 493 49 542 542 2a.4.3 Property taxes 9,808 981 10,788 9,710 1,079 2a.4.4 Health physics supplies 1,685 421 2,106 2,106 2a.4.5 Heavy equipment rental 2,568 385 2,953 2,953 2a.4.6 Disposal of DAW generated 11 4

219 57 291 291 3,928 78,550 18 2a.4.7 Plant energy budget 1,287 193 1,480 1,480 2a.4.8 NRC Fees 968 97 1,065 1,065 2a.4.9 Emergency Planning Fees 147 15 162 162 2a.4.10 Site O&M Costs 184 28 211 211 2a.4.11 Spent Fuel Pool O&M 561 84 645 645 2a.4.12 ISFSI Operating Costs 65 10 74 74 2a.4.13 Security Staff Cost 648 97 745 745 16,877 2a.4.14 DOC Staff Cost 18,869 2,830 21,699 21,699 233,211 2a.4.15 Utility Staff Cost 32,405 4,861 37,265 37,265 434,203 2a.4 Subtotal Period 2a Period-Dependent Costs 72 4,253 11 4

219 65,432 10,125 80,116 78,157 881 1,079 3,928 78,550 18 684,291 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 6 of 22 Table C-1 Byron Nuclear Power Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:02:56 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 2a.0 TOTAL PERIOD 2a COST 1,861 25,087 11,925 7,744 1,823 27,431 76,898 35,034 187,804 169,183 13,531 5,090 108,666 68,374 3,156 459 11,934,440 276,383 691,373 PERIOD 2b - Site Decontamination Disposal of Plant Systems 2b.1.2.1 Chemical & Volume Control 817 1,101 71 50 17 302 777 3,136 3,136 868 2,895 291,539 31,015 2b.1.2.2 Chilled Water RCA 282 20 23 64 72 104 565 565 3,376 680 198,114 4,761 2b.1.2.3 Component Cooling RCA 604 42 43 110 152 216 1,167 1,167 5,759 1,439 362,801 9,740 2b.1.2.4 Electrical 2,682 402 3,085 3,085 48,490 2b.1.2.5 Electrical - Contaminated 1,136 14 24 122 18 312 1,626 1,626 6,385 170 274,560 19,147 2b.1.2.6 Electrical - RCA 1,706 38 64 318 47 499 2,673 2,673 16,677 444 717,088 29,114 2b.1.2.7 Emergency Diesel Generator 113 17 130 130 2,066 2b.1.2.8 Essential Service Water RCA 271 21 24 72 74 103 565 565 3,797 699 216,933 4,447 2b.1.2.9 Fire Protection 108 16 124 124 1,984 2b.1.2.10 Fire Protection RCA 165 8

6 10 29 52 269 269 500 274 44,875 2,593 2b.1.2.11 HVAC-Auxiliary Building 494 11 18 91 15 145 775 775 4,772 143 206,582 8,219 2b.1.2.12 HVAC-Diesel Generator Room 38 6

44 44 682 2b.1.2.13 HVAC-Miscellaneous 37 5

42 42 656 2b.1.2.14 HVAC-Primary Containment 598 22 39 194 29 194 1,076 1,076 10,145 270 436,230 9,906 2b.1.2.15 HVAC-Turbine Building 164 25 188 188 3,177 2b.1.2.16 Instrument Air Supply 41 6

47 47 760 2b.1.2.17 Instrument Air Supply RCA 67 4

3 2

15 22 112 112 86 143 16,339 1,082 2b.1.2.18 Miscellaneous Drains 39 2

2 3

7 12 65 65 176 69 13,320 655 2b.1.2.19 Primary Containment Purge 275 22 26 87 70 105 586 586 4,544 664 244,109 4,845 2b.1.2.20 Primary Water 60 2

1 2

7 17 90 90 90 69 9,849 1,024 2b.1.2.21 Radioactive Waste Disposal 427 906 61 46 53 231 519 2,244 2,244 2,795 2,520 309,487 22,364 2b.1.2.22 Reactor Building Equipment Drains 82 97 8

6 2

34 76 304 304 82 330 32,558 2,742 2b.1.2.23 Reactor Building Floor Drains 18 45 3

2 1

11 24 104 104 76 102 12,182 1,034 2b.1.2.24 Reactor Coolant 170 10 7

2 40 55 284 284 101 378 38,001 2,806 2b.1.2.25 Residual Heat Removal 143 191 16 15 17 76 144 601 601 867 716 99,415 4,227 2b.1.2.26 Safety Injection 866 63 60 128 236 310 1,663 1,663 6,698 2,507 472,191 15,122 2b.1.2.27 Station Air RCA 33 2

1 1

7 10 54 54 39 69 7,800 525 2b.1.2.28 Station Heating RCA 109 7

7 15 25 38 201 201 789 238 53,393 1,772 2b.1.2.29 Waste Oil Sumps RCA 7

1 0

0 2

2 12 12 13 20 2,298 93 2b.1.2 Totals 1,487 12,405 448 468 1,310 1,501 4,213 21,832 18,171 3,660 68,636 14,839 4,059,664 235,048 2b.1.3 Scaffolding in support of decommissioning 1,470 9

2 10 3

371 1,865 1,865 458 29 23,188 28,306 Decontamination of Site Buildings 2b.1.4.1 Reactor 1,947 1,478 195 205 134 786 1,610 6,355 6,355 7,022 9,990 1,229,614 57,952 2b.1.4.2 Auxiliary Building 196 123 10 11 17 23 140 519 519 866 426 76,820 5,405 2b.1.4.3 Refueling Water Storage Tank 354 422 5

6 22 9

290 1,108 1,108 1,146 142 60,367 13,578 2b.1.4 Totals 2,498 2,022 210 222 172 819 2,039 7,983 7,983 9,034 10,558 1,366,802 76,935 2b.1 Subtotal Period 2b Activity Costs 3,984 15,898 667 692 1,492 2,323 6,623 31,679 28,019 3,660 78,128 25,425 5,449,654 340,289 Period 2b Additional Costs 2b.2.1 License Termination Survey Planning 940 282 1,222 1,222 6,240 2b.2.2 Soil Remediation 17 0

52 143 48 260 260 2,730 207,480 99 2b.2 Subtotal Period 2b Additional Costs 17 0

52 143 940 330 1,482 1,482 2,730 207,480 99 6,240 Period 2b Collateral Costs 2b.3.1 Process liquid waste 206 151 706 922 455 2,440 2,440 2,433 198,741 474 2b.3.2 Small tool allowance 308 46 354 354 2b.3.3 Decommissioning Equipment Disposition 119 34 127 40 46 365 365 6,000 373 303,507 88 2b.3.4 Spent Fuel Capital and Transfer 19,000 2,850 21,850 21,850 2b.3 Subtotal Period 2b Collateral Costs 206 308 271 740 127 962 19,000 3,397 25,010 3,160 21,850 6,000 2,807 502,248 563 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 7 of 22 Table C-1 Byron Nuclear Power Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:02:56 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 696 174 870 870 2b.4.2 Insurance 847 85 932 932 2b.4.3 Property taxes 1,264 126 1,390 1,390 2b.4.4 Health physics supplies 2,296 574 2,870 2,870 2b.4.5 Heavy equipment rental 4,377 657 5,034 5,034 2b.4.6 Disposal of DAW generated 14 5

277 72 369 369 4,970 99,407 23 2b.4.7 Plant energy budget 1,746 262 2,008 2,008 2b.4.8 NRC Fees 1,664 166 1,831 1,831 2b.4.9 Emergency Planning Fees 253 25 278 278 2b.4.10 Site O&M Costs 316 47 363 363 2b.4.11 Spent Fuel Pool O&M 964 145 1,109 1,109 2b.4.12 Liquid Radwaste Processing Equipment/Services 484 73 557 557 2b.4.13 ISFSI Operating Costs 111 17 128 128 2b.4.14 Security Staff Cost 1,113 167 1,280 1,280 29,009 2b.4.15 DOC Staff Cost 23,989 3,598 27,587 27,587 306,436 2b.4.16 Utility Staff Cost 41,185 6,178 47,363 47,363 569,887 2b.4 Subtotal Period 2b Period-Dependent Costs 696 6,673 14 5

277 73,936 12,365 93,967 92,453 1,514 4,970 99,407 23 905,331 2b.0 TOTAL PERIOD 2b COST 4,887 22,895 952 1,489 1,619 3,706 93,876 22,715 152,138 125,113 23,364 3,660 84,128 35,932 6,258,789 340,974 911,571 PERIOD 2d - Delay before License Termination Period 2d Period-Dependent Costs 2d.4.1 Insurance 882 88 970 970 2d.4.2 Property taxes 1,316 132 1,447 1,447 2d.4.3 Health physics supplies 197 49 246 246 2d.4.4 Disposal of DAW generated 1

0 15 4

19 19 262 5,249 1

2d.4.5 Plant energy budget 2d.4.6 NRC Fees 480 48 528 528 2d.4.7 Emergency Planning Fees 263 26 289 289 2d.4.8 Site O&M Costs 329 49 378 378 2d.4.9 ISFSI Operating Costs 116 17 133 133 2d.4.10 Security Staff Cost 632 95 727 727 16,474 2d.4.11 Utility Staff Cost 2,705 406 3,111 3,111 38,440 2d.4 Subtotal Period 2d Period-Dependent Costs 197 1

0 15 6,723 914 7,850 7,427 422 262 5,249 1

54,914 2d.0 TOTAL PERIOD 2d COST 197 1

0 15 6,723 914 7,850 7,427 422 262 5,249 1

54,914 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 5,485 1,646 7,131 7,131 91,793 3,120 2e.2 Subtotal Period 2e Additional Costs 5,485 1,646 7,131 7,131 91,793 3,120 Period 2e Collateral Costs 2e.3.1 DOC staff relocation expenses 1,130 169 1,299 1,299 2e.3 Subtotal Period 2e Collateral Costs 1,130 169 1,299 1,299 Period 2e Period-Dependent Costs 2e.4.1 Insurance 228 23 251 251 2e.4.2 Property taxes 376 38 414 414 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 8 of 22 Table C-1 Byron Nuclear Power Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:02:56 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 598 149 747 747 2e.4.4 Disposal of DAW generated 1

0 19 5

25 25 337 6,734 2

2e.4.5 Plant energy budget 139 21 160 160 2e.4.6 NRC Fees 532 53 585 585 2e.4.7 Emergency Planning Fees 75 8

83 83 2e.4.8 Site O&M Costs 94 14 108 108 2e.4.9 ISFSI Operating Costs 33 5

38 38 2e.4.10 Security Staff Cost 1,214 182 1,396 1,396 27,893 2e.4.11 DOC Staff Cost 3,801 570 4,371 4,371 46,750 2e.4.12 Utility Staff Cost 4,795 719 5,514 5,514 60,107 2e.4 Subtotal Period 2e Period-Dependent Costs 598 1

0 19 11,287 1,787 13,691 13,570 121 337 6,734 2

134,750 2e.0 TOTAL PERIOD 2e COST 598 1

0 19 18,053 3,647 22,318 22,197 121 337 6,734 91,795 137,870 PERIOD 2 TOTALS 6,748 48,776 12,879 9,233 3,442 31,171 195,550 62,311 370,110 323,920 37,439 8,751 192,795 104,906 3,156 459 18,205,210 709,152 1,795,729 PERIOD 3b - Site Restoration Period 3b Direct Decommissioning Activities Demolition of Remaining Site Buildings 3b.1.1.1 Reactor 6,217 933 7,149 7,149 69,541 3b.1.1.2 Auxiliary Building 5,342 801 6,143 6,143 61,287 3b.1.1.3 Old Steam Generator Storage Facility 417 63 479 479 4,868 3b.1.1.4 Refueling Water Storage Tank 936 140 1,077 1,077 11,688 3b.1.1.5 Turbine Building 5,246 787 6,033 6,033 70,347 3b.1.1.6 Turbine Pedestal 1,250 187 1,437 1,437 12,628 3b.1.1 Totals 19,408 2,911 22,319 22,319 230,359 Site Closeout Activities 3b.1.2 Grade & landscape site 267 40 307 307 869 3b.1.3 Final report to NRC 184 28 212 212 1,560 3b.1 Subtotal Period 3b Activity Costs 19,675 184 2,979 22,838 212 22,626 231,228 1,560 Period 3b Additional Costs 3b.2.1 Concrete Crushing 574 3

87 664 664 2,798 3b.2.2 Hyberbolic Cooling Tower 3,461 519 3,980 3,980 18,598 3b.2 Subtotal Period 3b Additional Costs 4,035 3

606 4,644 4,644 21,396 Period 3b Collateral Costs 3b.3.1 Small tool allowance 241 36 277 277 3b.3 Subtotal Period 3b Collateral Costs 241 36 277 277 Period 3b Period-Dependent Costs 3b.4.1 Insurance 751 75 826 826 3b.4.2 Property taxes 1,239 124 1,363 1,363 3b.4.3 Heavy equipment rental 6,137 921 7,057 7,057 3b.4.4 Plant energy budget 228 34 262 (0) 52 210 3b.4.5 NRC ISFSI Fees 244 24 268 268 3b.4.6 Emergency Planning Fees 248 25 273 273 3b.4.7 ISFSI Operating Costs 109 16 125 125 3b.4.8 Site O&M Cost 310 46 356 356 3b.4.9 Security Staff Cost 3,821 573 4,394 0

3,603 791 87,294 3b.4.10 DOC Staff Cost 11,650 1,748 13,398 13,398 137,043 3b.4.11 Utility Staff Cost 7,035 1,055 8,090 (0) 1,537 6,553 87,294 3b.4 Subtotal Period 3b Period-Dependent Costs 6,137 25,634 4,642 36,413 (0) 8,048 28,365 311,630 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 9 of 22 Table C-1 Byron Nuclear Power Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:02:56 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 30,087 25,822 8,262 64,171 212 8,048 55,912 252,623 313,190 PERIOD 3c - Fuel Storage Operations/Shipping Period 3c Direct Decommissioning Activities Period 3c Collateral Costs 3c.3.1 Spent Fuel Capital and Transfer 7,875 1,181 9,056 9,056 3c.3 Subtotal Period 3c Collateral Costs 7,875 1,181 9,056 9,056 Period 3c Period-Dependent Costs 3c.4.1 Insurance 2,063 206 2,269 2,269 3c.4.2 Property taxes 3,403 340 3,744 3,744 3c.4.3 Plant energy budget 3c.4.4 NRC ISFSI Fees 1,269 127 1,396 1,396 3c.4.5 Emergency Planning Fees 681 68 749 749 3c.4.6 Site O&M Costs 851 128 978 978 3c.4.7 ISFSI Operating Costs 299 45 344 344 3c.4.8 Security Staff Cost 8,657 1,299 9,956 9,956 191,777 3c.4.9 Utility Staff Cost 3,679 552 4,231 4,231 48,015 3c.4 Subtotal Period 3c Period-Dependent Costs 20,903 2,765 23,667 23,667 239,792 3c.0 TOTAL PERIOD 3c COST 28,778 3,946 32,724 32,724 239,792 PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d.1.1.1 Vessel & Internals GTCC Disposal 375 11,665 1,787 13,827 13,827 505 104,146 3d.1.1 Totals 375 11,665 1,787 13,827 13,827 505 104,146 3d.1 Subtotal Period 3d Activity Costs 375 11,665 1,787 13,827 13,827 505 104,146 Period 3d Period-Dependent Costs 3d.4.1 Insurance 12 1

13 13 3d.4.2 Property taxes 19 2

21 21 3d.4.3 Plant energy budget 3d.4.4 NRC ISFSI Fees 7

1 8

8 3d.4.5 Emergency Planning Fees 4

0 4

4 3d.4.6 Site O&M Costs 5

1 6

6 3d.4.7 ISFSI Operating Costs 2

0 2

2 3d.4.8 Security Staff Cost 49 7

56 56 1,080 3d.4.9 Utility Staff Cost 21 3

24 24 270 3d.4 Subtotal Period 3d Period-Dependent Costs 118 16 133 133 1,350 3d.0 TOTAL PERIOD 3d COST 375 11,665 118 1,803 13,960 13,827 133 505 104,146 1,350 PERIOD 3e - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 3e Additional Costs 3e.2.1 ISFSI License Termination 38 1

23 90 727 143 1,021 1,021 1,705 142,596 2,873 1,280 3e.2 Subtotal Period 3e Additional Costs 38 1

23 90 727 143 1,021 1,021 1,705 142,596 2,873 1,280 Period 3e Collateral Costs 3e.3.1 Small tool allowance 0

0 1

1 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 10 of 22 Table C-1 Byron Nuclear Power Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:02:56 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 3e.3 Subtotal Period 3e Collateral Costs 0

0 1

1 Period 3e Period-Dependent Costs 3e.4.1 Insurance 99 10 109 109 3e.4.2 Property taxes 163 16 179 179 3e.4.3 Heavy equipment rental 219 33 251 251 3e.4.4 Plant energy budget 3e.4.5 Site O&M Costs 41 6

47 47 3e.4.6 Security Staff Cost 110 16 126 126 2,468 3e.4.7 Utility Staff Cost 147 22 169 169 1,870 3e.4 Subtotal Period 3e Period-Dependent Costs 219 559 104 882 882 4,338 3e.0 TOTAL PERIOD 3e COST 257 1

23 90 1,286 247 1,903 1,903 1,705 142,596 2,873 5,618 PERIOD 3f - ISFSI Site Restoration Period 3f Direct Decommissioning Activities Period 3f Additional Costs 3f.2.1 ISFSI Demolition and Site Restoration 1,227 24 188 1,439 1,439 17,085 80 3f.2 Subtotal Period 3f Additional Costs 1,227 24 188 1,439 1,439 17,085 80 Period 3f Collateral Costs 3f.3.1 Small tool allowance 16 2

18 18 3f.3 Subtotal Period 3f Collateral Costs 16 2

18 18 Period 3f Period-Dependent Costs 3f.4.1 Insurance 3f.4.2 Property taxes 86 9

95 95 3f.4.3 Heavy equipment rental 89 13 103 103 3f.4.4 Plant energy budget 3f.4.5 Site O&M Costs 22 3

25 25 3f.4.6 Security Staff Cost 58 9

67 67 1,307 3f.4.7 Utility Staff Cost 64 10 73 73 810 3f.4 Subtotal Period 3f Period-Dependent Costs 89 229 44 362 362 2,117 3f.0 TOTAL PERIOD 3f COST 1,332 253 234 1,820 1,820 17,085 2,197 PERIOD 3 TOTALS 31,677 376 23 11,754 56,257 14,491 114,578 14,039 44,628 55,912 1,705 505 246,742 272,581 562,148 TOTAL COST TO DECOMMISSION 9,641 82,823 13,336 9,628 3,442 46,358 361,632 95,861 622,721 448,221 108,376 66,124 192,795 107,953 4,045 459 505 18,592,490 1,013,551 3,194,652 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 11 of 22 Table C-1 Byron Nuclear Power Station, Unit 1 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:02:56 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 18.19% CONTINGENCY:

$622,721 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 71.98% OR:

$448,221 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 17.4% OR:

$108,376 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 10.62% OR:

$66,124 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

112,458 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

505 cubic feet TOTAL SCRAP METAL REMOVED:

58,878 tons TOTAL CRAFT LABOR REQUIREMENTS:

1,013,551 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.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 12 of 22 Table C-2 Byron Nuclear Power Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:29 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 66 10 76 76 556 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 101 15 116 116 856 1a.1.7 Review plant dwgs & specs.

232 35 267 267 1,969 1a.1.8 Perform detailed rad survey a

1a.1.9 Estimate by-product inventory 51 8

58 58 428 1a.1.10 End product description 51 8

58 58 428 1a.1.11 Detailed by-product inventory 66 10 76 76 556 1a.1.12 Define major work sequence 379 57 436 436 3,210 1a.1.13 Perform SER and EA 157 23 180 180 1,327 1a.1.14 Perform Site-Specific Cost Study 253 38 290 290 2,140 1a.1.15 Prepare/submit License Termination Plan 207 31 238 238 1,753 1a.1.16 Receive NRC approval of termination plan a

Activity Specifications 1a.1.17.1 Plant & temporary facilities 249 37 286 257 29 2,106 1a.1.17.2 Plant systems 210 32 242 218 24 1,783 1a.1.17.3 NSSS Decontamination Flush 25 4

29 29 214 1a.1.17.4 Reactor internals 359 54 412 412 3,039 1a.1.17.5 Reactor vessel 328 49 378 378 2,782 1a.1.17.6 Biological shield 25 4

29 29 214 1a.1.17.7 Steam generators 158 24 181 181 1,335 1a.1.17.8 Reinforced concrete 81 12 93 46 46 685 1a.1.17.9 Main Turbine 20 3

23 23 171 1a.1.17.10 Main Condensers 20 3

23 23 171 1a.1.17.11 Plant structures & buildings 158 24 181 91 91 1,335 1a.1.17.12 Waste management 232 35 267 267 1,969 1a.1.17.13 Facility & site closeout 45 7

52 26 26 385 1a.1.17 Total 1,911 287 2,197 1,935 262 16,190 Planning & Site Preparations 1a.1.18 Prepare dismantling sequence 121 18 139 139 1,027 1a.1.19 Plant prep. & temp. svces 2,800 420 3,220 3,220 1a.1.20 Design water clean-up system 71 11 81 81 599 1a.1.21 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,200 330 2,530 2,530 1a.1.22 Procure casks/liners & containers 62 9

71 71 526 1a.1 Subtotal Period 1a Activity Costs 8,725 1,309 10,034 9,771 262 31,566 Period 1a Additional Costs 1a.2.1 ISFSI Expansion 9,800 1,470 11,270 11,270 1a.2 Subtotal Period 1a Additional Costs 9,800 1,470 11,270 11,270 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 769 77 846 846 1a.4.2 Property taxes 1a.4.3 Health physics supplies 390 98 488 488 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 13 of 22 Table C-2 Byron Nuclear Power Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:29 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.4.4 Heavy equipment rental 414 62 476 476 1a.4.5 Disposal of DAW generated 2

1 32 8

42 42 565 11,299 3

1a.4.6 Plant energy budget 921 138 1,059 1,059 1a.4.7 NRC Fees 471 47 518 518 1a.4.8 Emergency Planning Fees 306 31 337 337 1a.4.9 Site O&M Costs 125 19 144 144 1a.4.10 Spent Fuel Pool O&M 381 57 438 438 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 6,424 964 7,387 7,387 157,471 1a.4.13 Utility Staff Cost 24,828 3,724 28,552 28,552 346,229 1a.4 Subtotal Period 1a Period-Dependent Costs 804 2

1 32 34,269 5,231 40,337 39,511 826 565 11,299 3

503,700 1a.0 TOTAL PERIOD 1a COST 804 2

1 32 61,794 9,359 71,991 49,283 22,446 262 565 11,299 3

535,266 PERIOD 1b - Decommissioning Preparations Period 1b Direct Decommissioning Activities Detailed Work Procedures 1b.1.1.1 Plant systems 239 36 275 247 27 2,026 1b.1.1.2 NSSS Decontamination Flush 51 8

58 58 428 1b.1.1.3 Reactor internals 126 19 145 145 1,070 1b.1.1.4 Remaining buildings 68 10 78 20 59 578 1b.1.1.5 CRD cooling assembly 51 8

58 58 428 1b.1.1.6 CRD housings & ICI tubes 51 8

58 58 428 1b.1.1.7 Incore instrumentation 51 8

58 58 428 1b.1.1.8 Reactor vessel 183 28 211 211 1,554 1b.1.1.9 Facility closeout 61 9

70 35 35 514 1b.1.1.10 Missile shields 23 3

26 26 193 1b.1.1.11 Biological shield 61 9

70 70 514 1b.1.1.12 Steam generators 232 35 267 267 1,969 1b.1.1.13 Reinforced concrete 51 8

58 29 29 428 1b.1.1.14 Main Turbine 79 12 91 91 668 1b.1.1.15 Main Condensers 79 12 91 91 668 1b.1.1.16 Auxiliary building 138 21 159 143 16 1,168 1b.1.1.17 Reactor building 138 21 159 143 16 1,168 1b.1.1 Total 1,679 252 1,931 1,568 363 14,228 1b.1.2 Decon primary loop 567 283 850 850 1,067 1b.1 Subtotal Period 1b Activity Costs 567 1,679 535 2,781 2,418 363 1,067 14,228 Period 1b Additional Costs 1b.2.1 Site Characterization 2,711 813 3,525 3,525 13,042 4,640 1b.2.2 Spent Fuel Pool Isolation 9,690 1,453 11,143 11,143 1b.2 Subtotal Period 1b Additional Costs 12,401 2,267 14,668 14,668 13,042 4,640 Period 1b Collateral Costs 1b.3.1 Decon equipment 797 120 917 917 1b.3.2 DOC staff relocation expenses 1,130 169 1,299 1,299 1b.3.3 Process liquid waste 56 73 345 3,070 855 4,400 4,400 371 806 111,694 229 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 1b.3.7 Spent Fuel Capital and Transfer 5,000 750 5,750 5,750 1b.3 Subtotal Period 1b Collateral Costs 2,254 1,102 73 345 3,070 6,130 2,269 15,243 9,493 5,750 371 806 111,694 229 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 14 of 22 Table C-2 Byron Nuclear Power Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:29 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 Period-Dependent Costs 1b.4.1 Decon supplies 24 6

31 31 1b.4.2 Insurance 386 39 424 424 1b.4.3 Property taxes 4,927 493 5,420 5,420 1b.4.4 Health physics supplies 215 54 269 269 1b.4.5 Heavy equipment rental 207 31 238 238 1b.4.6 Disposal of DAW generated 1

0 18 5

24 24 325 6,507 1

1b.4.7 Plant energy budget 923 138 1,061 1,061 1b.4.8 NRC Fees 236 24 260 260 1b.4.9 Emergency Planning Fees 154 15 169 169 1b.4.10 Site O&M Costs 63 9

72 72 1b.4.11 Spent Fuel Pool O&M 191 29 220 220 1b.4.12 ISFSI Operating Costs 22 3

25 25 1b.4.13 Security Staff Cost 3,221 483 3,704 3,704 78,951 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 24 423 1

0 18 26,259 3,749 30,475 30,061 414 325 6,507 1

299,597 1b.0 TOTAL PERIOD 1b COST 2,845 1,525 74 346 3,088 46,469 8,821 63,167 56,640 6,164 363 697 806 118,201 14,340 318,465 PERIOD 1 TOTALS 2,845 2,328 76 346 3,120 108,263 18,180 135,158 105,923 28,610 626 1,262 806 129,500 14,342 853,731 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.1 Reactor Coolant Piping 171 145 30 36 317 209 908 908 1,606 194,222 5,503 2a.1.1.2 Pressurizer Relief Tank 32 29 6

7 60 40 174 174 329 36,553 1,072 2a.1.1.3 Reactor Coolant Pumps & Motors 103 106 91 180 1,272 432 2,184 2,184 4,796 780,540 4,291 100 2a.1.1.4 Pressurizer 48 59 394 96 412 196 1,205 1,205 3,033 252,826 2,482 938 2a.1.1.5 Steam Generators 387 4,096 2,185 2,399 580 3,416 2,737 15,800 15,800 39,289 14,436 3,278,518 23,233 2,125 2a.1.1.6 CRDMs/ICIs/Service Structure Removal 161 91 194 45 102 155 747 747 3,881 86,025 4,285 2a.1.1.7 Reactor Vessel Internals 125 2,193 4,483 876 8,060 233 7,112 23,082 23,082 1,377 903 459 326,029 26,933 1,209 2a.1.1.8 Reactor Vessel 95 4,162 1,498 675 7,847 233 7,670 22,179 22,179 6,606 2,254 978,589 26,933 1,209 2a.1.1 Totals 1,122 10,881 8,881 4,314 580 21,485 466 18,550 66,279 66,279 39,289 36,065 3,156 459 5,933,302 94,734 5,582 Removal of Major Equipment 2a.1.2 Main Turbine/Generator 578 378 30 203 284 288 1,762 1,762 5,088 2,833 686,663 10,223 2a.1.3 Main Condensers 1,163 166 58 143 211 390 2,131 2,131 6,756 1,992 482,702 20,428 Cascading Costs from Clean Building Demolition 2a.1.4.1 Reactor 1,076 161 1,237 1,237 12,130 2a.1.4.2 Auxiliary Building 602 90 692 692 6,896 2a.1.4.3 Radwaste/Service Building 391 59 450 450 5,060 2a.1.4.4 Refueling Water Storage Tank 104 16 120 120 1,299 2a.1.4.5 Fuel Handling Building 309 46 355 355 3,690 2a.1.4 Totals 2,481 372 2,853 2,853 29,074 Disposal of Plant Systems 2a.1.5.1 Auxiliary Feedwater 63 9

72 72 1,143 2a.1.5.2 Auxiliary Steam 115 17 132 132 2,107 2a.1.5.3 Auxiliary Steam RCA 326 16 15 33 59 105 554 554 1,717 562 120,095 5,268 2a.1.5.4 Boric Acid Processing 424 464 35 26 20 145 375 1,490 1,490 1,071 1,516 166,316 14,426 2a.1.5.5 CO2 & H2 16 2

18 18 289 2a.1.5.6 CO2 & H2 RCA 31 2

2 3

6 10 54 54 170 61 12,266 482 2a.1.5.7 Chemical Feed 145 22 167 167 2,663 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 15 of 22 Table C-2 Byron Nuclear Power Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:29 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 Chilled Water 80 12 92 92 1,454 2a.1.5.9 Circulating Water 525 79 604 604 9,669 2a.1.5.10 Condensate 293 44 337 337 5,317 2a.1.5.11 Condensate Booster 293 44 336 336 5,314 2a.1.5.12 Condensate Cleanup 160 24 184 184 3,000 2a.1.5.13 Containment Spray 229 16 17 49 56 83 450 450 2,569 527 151,430 3,698 2a.1.5.14 Diesel Fuel Oil 158 24 182 182 2,848 2a.1.5.15 Essential Service Water 274 41 315 315 5,049 2a.1.5.16 Extraction Steam 196 29 226 226 3,637 2a.1.5.17 Feedwater 267 40 307 307 4,925 2a.1.5.18 Feedwater Drains 633 95 728 728 11,719 2a.1.5.19 Gland Steam 33 5

38 38 616 2a.1.5.20 Gland Water 24 4

28 28 458 2a.1.5.21 Main Steam 271 41 312 312 4,979 2a.1.5.22 Main Steam RCA 76 4

5 13 17 27 142 142 670 162 41,728 1,256 2a.1.5.23 Make-up Demineralizer 137 21 158 158 2,595 2a.1.5.24 Nitrogen 1

0 1

1 18 2a.1.5.25 Non-Essential Service Water 318 48 366 366 5,903 2a.1.5.26 Non-Essential Service Water RCA 163 18 20 50 70 71 391 391 2,611 658 165,090 2,562 2a.1.5.27 Off Gas 668 35 37 96 128 222 1,186 1,186 5,026 1,212 312,797 11,268 2a.1.5.28 Potable Water 4

1 5

5 75 2a.1.5.29 Process Radiation Monitoring 66 1

1 1

3 18 90 90 75 33 5,961 1,214 2a.1.5.30 Process Sampling 145 3

3 9

9 41 210 210 466 89 26,924 2,632 2a.1.5.31 Sewage Treatment Plant 85 13 98 98 1,579 2a.1.5.32 Station Air 38 6

44 44 705 2a.1.5.33 Station Heating 130 19 149 149 2,391 2a.1.5.34 Steam Humidification 6

1 7

7 115 2a.1.5.35 Switchgear Heat Removal 29 4

33 33 519 2a.1.5.36 Turbine Bldg Equip Drains 67 10 77 77 1,235 2a.1.5.37 Turbine Bldg Floor Drains 115 17 133 133 2,117 2a.1.5.38 Turbine Oil 73 11 84 84 1,359 2a.1.5.39 Turbine-Generator Auxilaries 49 7

57 57 884 2a.1.5.40 Waste Oil Sumps 28 4

32 32 517 2a.1.5.41 Well Water 69 10 79 79 1,247 2a.1.5 Totals 424 6,866 130 126 274 494 1,655 9,970 4,568 5,402 14,375 4,820 1,002,607 129,248 2a.1.6 Scaffolding in support of decommissioning 1,419 9

2 10 3

358 1,802 1,802 473 29 23,936 27,326 2a.1 Subtotal Period 2a Activity Costs 1,546 23,388 9,564 4,531 1,211 22,477 466 21,615 84,797 79,394 5,402 65,980 45,739 3,156 459 8,129,210 311,032 5,582 Period 2a Collateral Costs 2a.3.1 Process liquid waste 146 74 342 379 226 1,168 1,168 1,193 81,635 233 2a.3.2 Small tool allowance 283 42 326 293 33 2a.3.3 Spent Fuel Capital and Transfer 13,000 1,950 14,950 14,950 2a.3 Subtotal Period 2a Collateral Costs 146 283 74 342 379 13,000 2,219 16,443 1,461 14,950 33 1,193 81,635 233 Period 2a Period-Dependent Costs 2a.4.1 Decon supplies 72 18 90 90 2a.4.2 Insurance 493 49 542 542 2a.4.3 Property taxes 9,808 981 10,788 9,710 1,079 2a.4.4 Health physics supplies 1,819 455 2,274 2,274 2a.4.5 Heavy equipment rental 2,568 385 2,953 2,953 2a.4.6 Disposal of DAW generated 11 4

219 57 291 291 3,925 78,509 18 2a.4.7 Plant energy budget 1,287 193 1,480 1,480 2a.4.8 NRC Fees 663 66 729 729 2a.4.9 Emergency Planning Fees 147 15 162 162 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 16 of 22 Table C-2 Byron Nuclear Power Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:29 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.4.10 Site O&M Costs 184 28 211 211 2a.4.11 Spent Fuel Pool O&M 561 84 645 645 2a.4.12 ISFSI Operating Costs 65 10 74 74 2a.4.13 Security Staff Cost 8,008 1,201 9,210 9,210 194,087 2a.4.14 DOC Staff Cost 18,869 2,830 21,699 21,699 233,211 2a.4.15 Utility Staff Cost 32,405 4,861 37,265 37,265 434,203 2a.4 Subtotal Period 2a Period-Dependent Costs 72 4,387 11 4

219 72,488 11,232 88,413 86,453 881 1,079 3,925 78,509 18 861,501 2a.0 TOTAL PERIOD 2a COST 1,764 28,058 9,649 4,877 1,211 23,075 85,954 35,066 189,653 167,308 15,831 6,514 65,980 50,857 3,156 459 8,289,355 311,283 867,083 PERIOD 2b - Site Decontamination Period 2b Direct Decommissioning Activities Disposal of Plant Systems 2b.1.1.1 Chemical & Volume Control 763 1,052 68 49 17 291 734 2,973 2,973 909 2,787 283,146 29,248 2b.1.1.2 Chilled Water RCA 592 46 43 71 191 218 1,161 1,161 3,736 1,808 313,840 9,257 2b.1.1.3 Component Cooling 627 44 47 121 160 226 1,225 1,225 6,342 1,513 393,115 10,143 2b.1.1.4 Electrical 3,669 550 4,220 4,220 66,259 2b.1.1.5 Electrical - Contaminated 1,727 20 34 172 25 471 2,451 2,451 9,033 240 388,394 28,801 2b.1.1.6 Electrical - RCA 2,236 47 78 389 57 648 3,455 3,455 20,387 542 876,577 37,570 2b.1.1.7 Emergency Diesel Generator 83 13 96 96 1,514 2b.1.1.8 Essential Service Water RCA 303 38 45 129 140 141 796 796 6,764 1,325 393,573 5,007 2b.1.1.9 Fire Protection 271 41 311 311 4,983 2b.1.1.10 Fire Protection RCA 476 35 35 76 137 173 933 933 3,961 1,298 277,242 7,443 2b.1.1.11 HVAC-Auxiliary Building 538 12 20 102 15 158 846 846 5,365 141 230,495 9,018 2b.1.1.12 HVAC-Control Room HVAC 7

1 8

8 127 2b.1.1.13 HVAC-Diesel Generator Room 38 6

44 44 686 2b.1.1.14 HVAC-Laboratory 17 3

20 20 315 2b.1.1.15 HVAC-Machine Shop 16 2

18 18 297 2b.1.1.16 HVAC-Primary Containment 598 22 39 194 29 194 1,076 1,076 10,145 270 436,230 9,906 2b.1.1.17 HVAC-Pumphouse 15 2

18 18 275 2b.1.1.18 HVAC-Radwaste 309 7

12 60 9

91 489 489 3,160 84 135,891 5,013 2b.1.1.19 HVAC-Turbine Building 163 24 187 187 3,158 2b.1.1.20 Instrument Air Supply 64 10 73 73 1,197 2b.1.1.21 Instrument Air Supply RCA 220 9

7 8

32 66 342 342 437 306 45,151 3,581 2b.1.1.22 Miscellaneous Drains 73 3

3 7

13 23 123 123 377 121 26,209 1,242 2b.1.1.23 Primary Containment Purge 290 23 26 85 73 110 607 607 4,466 687 242,950 5,082 2b.1.1.24 Primary Water 799 58 54 144 181 281 1,517 1,517 7,569 2,154 460,483 14,115 2b.1.1.25 Radioactive Waste Disposal 2,388 2,674 206 154 106 861 2,137 8,527 8,527 5,558 8,877 955,683 82,599 2b.1.1.26 Reactor Bldg Equipment Drains 102 106 10 8

3 47 92 368 368 170 446 46,524 2,908 2b.1.1.27 Reactor Building Floor Drains 18 40 2

2 1

10 22 95 95 75 92 11,255 942 2b.1.1.28 Reactor Coolant 162 9

6 2

37 52 268 268 104 351 35,666 2,678 2b.1.1.29 Residual Heat Removal 133 185 15 14 16 74 137 574 574 849 696 96,886 3,992 2b.1.1.30 Safety Injection 841 62 58 126 228 301 1,616 1,616 6,576 2,428 460,194 14,716 2b.1.1.31 Station Air RCA 51 3

2 1

12 17 87 87 69 115 13,089 822 2b.1.1.32 Station Heating RCA 223 14 13 26 56 77 410 410 1,372 529 103,157 3,574 2b.1.1.33 Waste Oil Sumps RCA 23 1

1 1

4 7

38 38 78 38 6,630 363 2b.1.1.34 Waste Water Treatment 78 12 90 90 1,464 2b.1.1 Totals 3,403 18,570 754 751 1,861 2,682 7,039 35,060 29,975 5,085 97,501 26,849 6,232,380 368,293 2b.1.2 Scaffolding in support of decommissioning 1,773 12 3

13 4

448 2,252 2,252 591 37 29,920 34,158 Decontamination of Site Buildings 2b.1.3.1 Reactor 1,947 1,478 195 205 134 786 1,610 6,355 6,355 7,022 9,990 1,229,614 57,952 2b.1.3.2 Auxiliary Building 231 150 13 15 17 33 167 626 626 866 613 95,474 6,417 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 17 of 22 Table C-2 Byron Nuclear Power Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:29 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 (continued) 2b.1.3.3 Radwaste/Service Building 152 69 11 12 6

29 104 383 383 322 540 66,201 3,701 2b.1.3.4 Refueling Water Storage Tank 354 422 5

6 22 9

290 1,108 1,108 1,146 142 60,367 13,578 2b.1.3 Totals 2,684 2,119 224 238 179 858 2,171 8,473 8,473 9,356 11,284 1,451,657 81,647 2b.1 Subtotal Period 2b Activity Costs 6,087 22,462 990 991 2,052 3,543 9,658 45,785 40,700 5,085 107,449 38,170 7,713,957 484,098 Period 2b Collateral Costs 2b.3.1 Process liquid waste 287 237 1,110 1,507 711 3,852 3,852 3,817 324,682 744 2b.3.2 Small tool allowance 437 66 503 503 2b.3.3 Spent Fuel Capital and Transfer 23,000 3,450 26,450 26,450 2b.3 Subtotal Period 2b Collateral Costs 287 437 237 1,110 1,507 23,000 4,226 30,805 4,355 26,450 3,817 324,682 744 Period 2b Period-Dependent Costs 2b.4.1 Decon supplies 764 191 955 955 2b.4.2 Insurance 847 85 932 932 2b.4.3 Property taxes 1,264 126 1,390 1,390 2b.4.4 Health physics supplies 2,919 730 3,649 3,649 2b.4.5 Heavy equipment rental 4,377 657 5,034 5,034 2b.4.6 Disposal of DAW generated 19 7

362 93 481 481 6,483 129,660 30 2b.4.7 Plant energy budget 1,746 262 2,008 2,008 2b.4.8 NRC Fees 1,558 156 1,714 1,714 2b.4.9 Emergency Planning Fees 253 25 278 278 2b.4.10 Site O&M Costs 316 47 363 363 2b.4.11 Spent Fuel Pool O&M 1,733 260 1,992 1,992 2b.4.12 Liquid Radwaste Processing Equipment/Services 484 73 557 557 2b.4.13 ISFSI Operating Costs 111 17 128 128 2b.4.14 Security Staff Cost 13,765 2,065 15,830 15,830 333,599 2b.4.15 DOC Staff Cost 31,199 4,680 35,879 35,879 385,023 2b.4.16 Utility Staff Cost 53,549 8,032 61,581 61,581 714,666 2b.4 Subtotal Period 2b Period-Dependent Costs 764 7,296 19 7

362 106,824 17,498 132,770 130,372 2,398 6,483 129,660 30 1,433,287 2b.0 TOTAL PERIOD 2b COST 7,139 30,196 1,246 2,109 2,052 5,412 129,824 31,383 209,360 175,427 28,848 5,085 107,449 48,470 8,168,299 484,872 1,433,287 PERIOD 2c - Decontamination Following Wet Fuel Storage Period 2c Direct Decommissioning Activities 2c.1.1 Remove spent fuel racks 1,093 106 305 93 590 765 2,951 2,951 5,572 499,920 2,174 Disposal of Plant Systems 2c.1.2.1 Fuel Handling Bldg Equip Drains 161 10 8

14 38 54 286 286 738 397 62,254 2,688 2c.1.2.2 Fuel Handling Bldg Equip Drains (Unit 1) 29 1

1 1

5 9

46 46 37 49 5,918 475 2c.1.2.3 Fuel Handling Bldg Floor Drains 165 11 8

10 41 55 290 290 524 409 56,293 2,736 2c.1.2.4 Fuel Handling Bldg Floor Drains (Unit 1) 115 7

5 9

24 37 197 197 465 245 39,201 1,954 2c.1.2.5 Fuel Pool Cooling & Cleanup 219 15 13 16 67 77 407 407 830 635 90,354 3,663 2c.1.2.6 Fuel Pool Cooling & Cleanup (Unit 1) 203 14 12 15 61 71 377 377 805 578 84,182 3,417 2c.1.2.7 HVAC-Miscellaneous 97 14 111 111 1,769 2c.1.2 Totals 988 58 49 65 236 319 1,715 1,604 111 3,400 2,314 338,202 16,702 Decontamination of Site Buildings 2c.1.3.1 Fuel Handling Building 1,012 1,174 20 24 59 43 825 3,157 3,157 3,097 736 198,355 38,107 2c.1.3 Totals 1,012 1,174 20 24 59 43 825 3,157 3,157 3,097 736 198,355 38,107 2c.1.4 Scaffolding in support of decommissioning 355 2

1 3

1 90 450 450 118 7

5,984 6,832 2c.1 Subtotal Period 2c Activity Costs 2,105 2,621 386 166 127 870 1,998 8,273 8,162 111 6,615 8,629 1,042,461 63,814 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 18 of 22 Table C-2 Byron Nuclear Power Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:29 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 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 188 80 366 358 246 1,238 1,238 1,287 77,203 251 2c.3.2 Small tool allowance 75 11 87 87 2c.3.3 Decommissioning Equipment Disposition 119 34 127 40 46 365 365 6,000 373 303,507 88 2c.3 Subtotal Period 2c Collateral Costs 188 75 199 400 127 398 303 1,690 1,690 6,000 1,660 380,710 339 Period 2c Period-Dependent Costs 2c.4.1 Decon supplies 152 38 191 191 2c.4.2 Insurance 206 21 227 227 2c.4.3 Property taxes 308 31 339 339 2c.4.4 Health physics supplies 478 120 598 598 2c.4.5 Heavy equipment rental 1,067 160 1,227 1,227 2c.4.6 Disposal of DAW generated 4

2 82 21 109 109 1,467 29,339 7

2c.4.7 Plant energy budget 227 34 261 261 2c.4.8 NRC Fees 387 39 426 426 2c.4.9 Emergency Planning Fees 62 6

68 68 2c.4.10 Site O&M Costs 77 12 89 89 2c.4.11 Liquid Radwaste Processing Equipment/Services 236 35 272 272 2c.4.12 ISFSI Operating Costs 27 4

31 31 2c.4.13 Security Staff Cost 1,875 281 2,157 2,157 42,750 2c.4.14 DOC Staff Cost 5,254 788 6,043 6,043 64,286 2c.4.15 Utility Staff Cost 9,604 1,441 11,045 11,045 122,786 2c.4 Subtotal Period 2c Period-Dependent Costs 152 1,545 4

2 82 18,264 3,030 23,080 22,981 99 1,467 29,339 7

229,821 2c.0 TOTAL PERIOD 2c COST 2,445 4,242 589 567 253 1,350 19,204 5,614 34,266 34,056 99 111 12,615 11,756 1,452,510 64,160 236,061 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 7,473 2,242 9,716 9,716 128,636 3,120 2e.2 Subtotal Period 2e Additional Costs 7,473 2,242 9,716 9,716 128,636 3,120 Period 2e Collateral Costs 2e.3.1 DOC staff relocation expenses 1,130 169 1,299 1,299 2e.3 Subtotal Period 2e Collateral Costs 1,130 169 1,299 1,299 Period 2e Period-Dependent Costs 2e.4.1 Insurance 228 23 251 251 2e.4.2 Property taxes 376 38 414 414 2e.4.3 Health physics supplies 739 185 924 924 2e.4.4 Disposal of DAW generated 1

0 19 5

25 25 337 6,734 2

2e.4.5 Plant energy budget 139 21 160 160 2e.4.6 NRC Fees 355 35 390 390 2e.4.7 Emergency Planning Fees 75 8

83 83 2e.4.8 Site O&M Costs 94 14 108 108 2e.4.9 ISFSI Operating Costs 33 5

38 38 2e.4.10 Security Staff Cost 1,214 182 1,396 1,396 27,893 2e.4.11 DOC Staff Cost 3,801 570 4,371 4,371 46,750 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 19 of 22 Table C-2 Byron Nuclear Power Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:29 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.4.12 Utility Staff Cost 4,795 719 5,514 5,514 60,107 2e.4 Subtotal Period 2e Period-Dependent Costs 739 1

0 19 11,110 1,804 13,674 13,553 121 337 6,734 2

134,750 2e.0 TOTAL PERIOD 2e COST 739 1

0 19 19,865 4,261 24,886 24,765 121 337 6,734 128,638 137,870 PERIOD 2 TOTALS 11,348 63,235 11,485 7,553 3,516 29,855 254,847 76,324 458,164 401,555 44,899 11,709 186,044 111,419 3,156 459 17,916,900 988,953 2,674,302 PERIOD 3b - Site Restoration Period 3b Direct Decommissioning Activities Demolition of Remaining Site Buildings 3b.1.1.1 Reactor 6,217 933 7,149 7,149 69,541 3b.1.1.2 Aux Feedwater-Steam Tunnel/Penetr. Area 644 97 741 741 5,185 3b.1.1.3 Auxiliary Building 5,417 813 6,230 6,230 62,063 3b.1.1.4 Berms, Settling Ponds, and Drying Beds 130 19 149 149 1,631 3b.1.1.5 Circulating Water Pumphouse 931 140 1,071 1,071 11,861 3b.1.1.6 Essential Service Cooling Tower 427 64 491 491 5,067 3b.1.1.7 Make-up Demineralizer Area 1,558 234 1,792 1,792 20,770 3b.1.1.8 Miscellaneous Site Structures 1,649 247 1,897 1,897 20,544 3b.1.1.9 Radwaste/Service Building 3,579 537 4,116 4,116 45,688 3b.1.1.10 Receiving Building 166 25 190 190 2,293 3b.1.1.11 Refueling Water Storage Tank 936 140 1,077 1,077 11,688 3b.1.1.12 River Screen House 524 79 603 603 5,869 3b.1.1.13 Security Modifications 975 146 1,121 1,121 8,636 3b.1.1.14 Turbine Building 5,246 787 6,033 6,033 70,347 3b.1.1.15 Turbine Pedestal 1,250 187 1,437 1,437 12,628 3b.1.1.16 Yard Inventory 1,876 281 2,158 2,158 20,610 3b.1.1.17 Fuel Handling Building 2,781 417 3,198 3,198 33,246 3b.1.1 Totals 34,307 5,146 39,453 39,453 407,670 Site Closeout Activities 3b.1.2 BackFill Site 3,308 496 3,804 3,804 9,059 3b.1.3 Grade & landscape site 267 40 307 307 869 3b.1.4 Final report to NRC 79 12 91 91 668 3b.1 Subtotal Period 3b Activity Costs 37,882 79 5,694 43,655 91 43,565 417,598 668 Period 3b Additional Costs 3b.2.1 Concrete Crushing 935 5

141 1,081 1,081 4,554 3b.2.2 Hyberbolic Cooling Tower 2,769 415 3,184 3,184 18,598 3b.2.3 Cofferdam Construction and Teardown 409 61 470 470 3,996 3b.2 Subtotal Period 3b Additional Costs 4,112 5

618 4,735 4,735 27,148 Period 3b Collateral Costs 3b.3.1 Small tool allowance 423 63 486 486 3b.3 Subtotal Period 3b Collateral Costs 423 63 486 486 Period 3b Period-Dependent Costs 3b.4.1 Insurance 751 75 826 826 3b.4.2 Property taxes 1,239 124 1,363 1,363 3b.4.3 Heavy equipment rental 6,137 921 7,057 7,057 3b.4.4 Plant energy budget 228 34 262 (0) 52 210 3b.4.5 NRC ISFSI Fees 244 24 268 268 3b.4.6 Emergency Planning Fees 248 25 273 273 3b.4.7 ISFSI Operating Costs 109 16 125 125 3b.4.8 Site O&M Cost 310 46 356 356 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 20 of 22 Table C-2 Byron Nuclear Power Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:29 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 Period-Dependent Costs (continued) 3b.4.9 Security Staff Cost 3,821 573 4,394 0

3,603 791 87,294 3b.4.10 DOC Staff Cost 11,650 1,748 13,398 13,398 137,043 3b.4.11 Utility Staff Cost 7,035 1,055 8,090 (0) 1,537 6,553 87,294 3b.4 Subtotal Period 3b Period-Dependent Costs 6,137 25,634 4,642 36,413 (0) 8,048 28,365 311,630 3b.0 TOTAL PERIOD 3b COST 48,554 25,718 11,017 85,289 91 8,048 77,150 444,746 312,298 PERIOD 3c - Fuel Storage Operations/Shipping Period 3c Direct Decommissioning Activities Period 3c Collateral Costs 3c.3.1 Spent Fuel Capital and Transfer 7,875 1,181 9,056 9,056 3c.3 Subtotal Period 3c Collateral Costs 7,875 1,181 9,056 9,056 Period 3c Period-Dependent Costs 3c.4.1 Insurance 2,063 206 2,269 2,269 3c.4.2 Property taxes 3,403 340 3,744 3,744 3c.4.3 Plant energy budget 3c.4.4 NRC ISFSI Fees 1,269 127 1,396 1,396 3c.4.5 Emergency Planning Fees 681 68 749 749 3c.4.6 Site O&M Costs 851 128 978 978 3c.4.7 ISFSI Operating Costs 299 45 344 344 3c.4.8 Security Staff Cost 8,657 1,299 9,956 9,956 191,777 3c.4.9 Utility Staff Cost 3,679 552 4,231 4,231 48,015 3c.4 Subtotal Period 3c Period-Dependent Costs 20,903 2,765 23,667 23,667 239,792 3c.0 TOTAL PERIOD 3c COST 28,778 3,946 32,724 32,724 239,792 PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d.1.1.1 Vessel & Internals GTCC Disposal 375 11,665 1,787 13,827 13,827 505 104,146 3d.1.1 Totals 375 11,665 1,787 13,827 13,827 505 104,146 3d.1 Subtotal Period 3d Activity Costs 375 11,665 1,787 13,827 13,827 505 104,146 Period 3d Period-Dependent Costs 3d.4.1 Insurance 12 1

13 13 3d.4.2 Property taxes 19 2

21 21 3d.4.3 Plant energy budget 3d.4.4 NRC ISFSI Fees 7

1 8

8 3d.4.5 Emergency Planning Fees 4

0 4

4 3d.4.6 Site O&M Costs 5

1 6

6 3d.4.7 ISFSI Operating Costs 2

0 2

2 3d.4.8 Security Staff Cost 49 7

56 56 1,080 3d.4.9 Utility Staff Cost 21 3

24 24 270 3d.4 Subtotal Period 3d Period-Dependent Costs 118 16 133 133 1,350 3d.0 TOTAL PERIOD 3d COST 375 11,665 118 1,803 13,960 13,827 133 505 104,146 1,350 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 21 of 22 Table C-2 Byron Nuclear Power Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:29 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 - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 3e Additional Costs 3e.2.1 ISFSI License Termination 38 1

23 90 727 143 1,021 1,021 1,705 142,596 2,873 1,280 3e.2 Subtotal Period 3e Additional Costs 38 1

23 90 727 143 1,021 1,021 1,705 142,596 2,873 1,280 Period 3e Collateral Costs 3e.3.1 Small tool allowance 0

0 1

1 3e.3 Subtotal Period 3e Collateral Costs 0

0 1

1 Period 3e Period-Dependent Costs 3e.4.1 Insurance 99 10 109 109 3e.4.2 Property taxes 163 16 179 179 3e.4.3 Heavy equipment rental 219 33 251 251 3e.4.4 Plant energy budget 3e.4.5 Site O&M Costs 41 6

47 47 3e.4.6 Security Staff Cost 110 16 126 126 2,468 3e.4.7 Utility Staff Cost 147 22 169 169 1,870 3e.4 Subtotal Period 3e Period-Dependent Costs 219 559 104 882 882 4,338 3e.0 TOTAL PERIOD 3e COST 257 1

23 90 1,286 247 1,903 1,903 1,705 142,596 2,873 5,618 PERIOD 3f - ISFSI Site Restoration Period 3f Direct Decommissioning Activities Period 3f Additional Costs 3f.2.1 ISFSI Demolition and Site Restoration 1,227 24 188 1,439 1,439 17,085 80 3f.2 Subtotal Period 3f Additional Costs 1,227 24 188 1,439 1,439 17,085 80 Period 3f Collateral Costs 3f.3.1 Small tool allowance 16 2

18 18 3f.3 Subtotal Period 3f Collateral Costs 16 2

18 18 Period 3f Period-Dependent Costs 3f.4.1 Insurance 3f.4.2 Property taxes 86 9

95 95 3f.4.3 Heavy equipment rental 89 13 103 103 3f.4.4 Plant energy budget 3f.4.5 Site O&M Costs 22 3

25 25 3f.4.6 Security Staff Cost 58 9

67 67 1,307 3f.4.7 Utility Staff Cost 64 10 73 73 810 3f.4 Subtotal Period 3f Period-Dependent Costs 89 229 44 362 362 2,117 3f.0 TOTAL PERIOD 3f COST 1,332 253 234 1,820 1,820 17,085 2,197 PERIOD 3 TOTALS 50,143 376 23 11,754 56,153 17,246 135,695 13,917 44,628 77,150 1,705 505 246,742 464,704 561,256 TOTAL COST TO DECOMMISSION 14,193 115,706 11,937 7,923 3,516 44,729 419,263 111,750 729,017 521,395 118,136 89,486 186,044 114,386 3,962 459 505 18,293,140 1,467,999 4,089,289 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix C, Page 22 of 22 Table C-2 Byron Nuclear Power Station, Unit 2 DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:29 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 18.1% CONTINGENCY:

$729,017 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 71.52% OR:

$521,395 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 16.2% OR:

$118,136 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 12.27% OR:

$89,486 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

118,807 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

505 cubic feet TOTAL SCRAP METAL REMOVED:

74,681 tons TOTAL CRAFT LABOR REQUIREMENTS:

1,467,999 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.

Byron Nuclear Power Station Document E16-1555-013, Rev. 0 Decommissioning Cost Analysis Appendix D, Page 1 of 24 TLG Services, Inc.

APPENDIX D DETAILED COST ANALYSIS DELAYED DECON Page Byron Nuclear Power Station, Unit 1...........................................................................D-2 Byron Nuclear Power Station, Unit 2........................................................................D-13

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 2 of 24 Table D-1 Byron Nuclear Power Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:52 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 769 77 846 846 1a.4.2 Property taxes 1a.4.3 Health physics supplies 414 104 518 518 1a.4.4 Heavy equipment rental 414 62 476 476 1a.4.5 Disposal of DAW generated 2

1 34 9

45 45 610 12,190 3

1a.4.6 Plant energy budget 921 138 1,059 1,059 1a.4.7 NRC Fees 706 71 776 776 1a.4.8 Emergency Planning Fees 306 31 337 337 1a.4.9 Site O&M Costs 125 19 144 144 1a.4.10 Spent Fuel Pool O&M 381 57 438 438 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 458 69 527 527 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 828 2

1 34 34,793 5,304 40,961 40,135 826 610 12,190 3

435,664 1a.0 TOTAL PERIOD 1a COST 828 2

1 34 39,426 6,059 46,349 45,523 826 610 12,190 3

471,554 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 3 of 24 Table D-1 Byron Nuclear Power Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:52 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 1,924 962 2,886 2,886 33,093 1b.1.1.2 Auxiliary Building 191 95 286 286 3,289 1b.1.1.3 Refueling Water Storage Tank 314 157 471 471 5,322 1b.1.1 Totals 2,429 1,214 3,643 3,643 41,705 1b.1 Subtotal Period 1b Activity Costs 2,429 1,214 3,643 3,643 41,705 Period 1b Collateral Costs 1b.3.1 Decon equipment 797 120 917 917 1b.3.2 Process liquid waste 184 78 357 349 241 1,210 1,210 1,255 75,307 245 1b.3.3 Small tool allowance 39 6

44 44 1b.3 Subtotal Period 1b Collateral Costs 982 39 78 357 349 366 2,172 2,172 1,255 75,307 245 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 561 140 702 702 1b.4.2 Insurance 192 19 211 211 1b.4.3 Property taxes 2,452 245 2,697 2,697 1b.4.4 Health physics supplies 264 66 331 331 1b.4.5 Heavy equipment rental 103 15 119 119 1b.4.6 Disposal of DAW generated 1

1 29 7

38 38 517 10,338 2

1b.4.7 Plant energy budget 229 34 264 264 1b.4.8 NRC Fees 176 18 194 194 1b.4.9 Emergency Planning Fees 76 8

84 84 1b.4.10 Site O&M Costs 31 5

36 36 1b.4.11 Spent Fuel Pool O&M 95 14 109 109 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 561 368 1

1 29 11,126 1,753 13,839 13,633 206 517 10,338 2

108,618 1b.0 TOTAL PERIOD 1b COST 3,972 406 79 358 378 11,126 3,334 19,654 19,448 206 1,772 85,645 41,952 108,618 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 431 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 1,575 1,575 17,116 583 Period 1c Collateral Costs 1c.3.1 Process liquid waste 150 64 292 285 197 988 988 1,024 61,469 200 1c.3.2 Small tool allowance 4

1 4

4 1c.3 Subtotal Period 1c Collateral Costs 150 4

64 292 285 197 992 992 1,024 61,469 200 Period 1c Period-Dependent Costs 1c.4.1 Insurance 192 19 211 211 1c.4.2 Property taxes 2,452 245 2,697 2,697 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 4 of 24 Table D-1 Byron Nuclear Power Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:52 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 Period-Dependent Costs (continued) 1c.4.3 Health physics supplies 145 36 181 181 1c.4.4 Heavy equipment rental 103 15 119 119 1c.4.5 Disposal of DAW generated 0

0 6

2 8

8 107 2,132 0

1c.4.6 Plant energy budget 229 34 264 264 1c.4.7 NRC Fees 176 18 194 194 1c.4.8 Emergency Planning Fees 76 8

84 84 1c.4.9 Site O&M Costs 31 5

36 36 1c.4.10 Spent Fuel Pool O&M 95 14 109 109 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 248 0

0 6

5,523 737 6,514 6,309 206 107 2,132 0

30,098 1c.0 TOTAL PERIOD 1c COST 150 724 64 292 291 6,325 1,235 9,082 8,876 206 1,131 63,601 17,316 30,681 PERIOD 1 TOTALS 4,122 1,958 145 650 703 56,876 10,628 75,085 73,847 1,238 3,513 161,436 59,271 610,852 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 57 8

65 65 2a.1.5 Maintenance supplies 1,656 414 2,070 2,070 2a.1 Subtotal Period 2a Activity Costs 1,712 422 2,135 2,135 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 10,500 1,575 12,075 12,075 2a.3 Subtotal Period 2a Collateral Costs 10,500 1,575 12,075 12,075 Period 2a Period-Dependent Costs 2a.4.1 Insurance 4,412 441 4,853 4,853 2a.4.2 Property taxes 15,682 1,568 17,251 17,251 2a.4.3 Health physics supplies 1,054 264 1,318 1,318 2a.4.4 Disposal of DAW generated 15 5

282 73 374 374 5,047 100,942 23 2a.4.5 Plant energy budget 2,425 364 2,789 2,789 2a.4.6 NRC Fees 2,654 265 2,920 2,920 2a.4.7 Emergency Planning Fees 1,316 132 1,448 1,448 2a.4.8 Site O&M Costs 1,645 247 1,892 1,892 2a.4.9 Spent Fuel Pool O&M 5,021 753 5,774 5,774 2a.4.10 ISFSI Operating Costs 579 87 666 666 2a.4.11 Security Staff Cost 25,170 3,775 28,945 28,945 619,545 2a.4.12 Utility Staff Cost 32,266 4,840 37,106 37,106 414,037 2a.4 Subtotal Period 2a Period-Dependent Costs 1,054 15 5

282 91,172 12,809 105,337 4,612 100,725 5,047 100,942 23 1,033,583 2a.0 TOTAL PERIOD 2a COST 1,054 15 5

282 103,384 14,806 119,546 6,747 112,800 5,047 100,942 23 1,033,583 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 15 2

17 17 2b.1.5 Maintenance supplies 441 110 551 551 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 5 of 24 Table D-1 Byron Nuclear Power Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:52 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 2b.1 Subtotal Period 2b Activity Costs 456 112 568 568 Period 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 2,125 319 2,444 2,444 2b.3 Subtotal Period 2b Collateral Costs 2,125 319 2,444 2,444 Period 2b Period-Dependent Costs 2b.4.1 Insurance 1,062 106 1,168 1,168 2b.4.2 Property taxes 1,752 175 1,927 1,927 2b.4.3 Health physics supplies 269 67 336 336 2b.4.4 Disposal of DAW generated 4

1 74 19 98 98 1,322 26,445 6

2b.4.5 Plant energy budget 323 48 371 371 2b.4.6 NRC Fees 707 71 777 777 2b.4.7 Emergency Planning Fees 350 35 385 385 2b.4.8 Site O&M Costs 438 66 504 504 2b.4.9 ISFSI Operating Costs 154 23 177 177 2b.4.10 Security Staff Cost 4,350 652 5,002 5,002 98,743 2b.4.11 Utility Staff Cost 5,313 797 6,110 6,110 73,143 2b.4 Subtotal Period 2b Period-Dependent Costs 269 4

1 74 14,450 2,060 16,858 1,212 15,646 1,322 26,445 6

171,886 2b.0 TOTAL PERIOD 2b COST 269 4

1 74 17,031 2,491 19,870 1,780 18,090 1,322 26,445 6

171,886 PERIOD 2 TOTALS 1,323 18 7

355 120,415 17,298 139,416 8,527 130,890 6,369 127,387 29 1,205,468 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 Biological shield 59 9

68 68 500 3a.1.11.6 Steam generators 368 55 423 423 3,120 3a.1.11.7 Reinforced concrete 189 28 217 109 109 1,600 3a.1.11.8 Main Turbine 47 7

54 54 400 3a.1.11.9 Main Condensers 47 7

54 54 400 3a.1.11.10 Plant structures & buildings 368 55 423 212 212 3,120 3a.1.11.11 Waste management 543 81 624 624 4,600 3a.1.11.12 Facility & site closeout 106 16 122 61 61 900 3a.1.11 Total 4,694 704 5,398 4,752 646 39,777 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 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 6 of 24 Table D-1 Byron Nuclear Power Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:52 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 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 13,580 2,037 15,617 14,970 646 72,703 Period 3a Period-Dependent Costs 3a.4.1 Insurance 303 30 333 333 3a.4.2 Property taxes 500 50 550 550 3a.4.3 Health physics supplies 363 91 454 454 3a.4.4 Heavy equipment rental 414 62 476 476 3a.4.5 Disposal of DAW generated 1

1 29 7

38 38 516 10,311 2

3a.4.6 Plant energy budget 921 138 1,059 1,059 3a.4.7 NRC Fees 249 25 274 274 3a.4.8 Site O&M Costs 125 19 144 144 3a.4.9 Security Staff Cost 2,963 444 3,408 3,408 69,350 3a.4.10 Utility Staff Cost 19,481 2,922 22,403 22,403 260,714 3a.4 Subtotal Period 3a Period-Dependent Costs 777 1

1 29 24,541 3,789 29,138 29,138 516 10,311 2

330,064 3a.0 TOTAL PERIOD 3a COST 777 1

1 29 38,121 5,826 44,754 44,108 646 516 10,311 2

402,767 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 295 44 339 339 2,500 3b.1.1.3 Remaining buildings 159 24 183 46 137 1,350 3b.1.1.4 CRD cooling assembly 118 18 136 136 1,000 3b.1.1.5 CRD housings & ICI tubes 118 18 136 136 1,000 3b.1.1.6 Incore instrumentation 118 18 136 136 1,000 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 Missile shields 53 8

61 61 450 3b.1.1.10 Biological shield 142 21 163 163 1,200 3b.1.1.11 Steam generators 543 81 624 624 4,600 3b.1.1.12 Reinforced concrete 118 18 136 68 68 1,000 3b.1.1.13 Main Turbine 184 28 212 212 1,560 3b.1.1.14 Main Condensers 184 28 212 212 1,560 3b.1.1.15 Auxiliary building 322 48 370 333 37 2,730 3b.1.1.16 Reactor building 322 48 370 333 37 2,730 3b.1.1 Total 3,805 571 4,376 3,527 848 32,243 3b.1 Subtotal Period 3b Activity Costs 3,805 571 4,376 3,527 848 32,243 Period 3b Additional Costs 3b.2.1 Site Characterization 6,341 1,902 8,243 8,243 30,500 10,852 3b.2 Subtotal Period 3b Additional Costs 6,341 1,902 8,243 8,243 30,500 10,852 Period 3b Collateral Costs 3b.3.1 Decon equipment 797 120 917 917 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 797 1,100 1,130 454 3,482 3,482 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 7 of 24 Table D-1 Byron Nuclear Power Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:52 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 Period-Dependent Costs 3b.4.1 Decon supplies 24 6

31 31 3b.4.2 Insurance 168 17 185 185 3b.4.3 Property taxes 251 25 276 276 3b.4.4 Health physics supplies 201 50 251 251 3b.4.5 Heavy equipment rental 207 31 238 238 3b.4.6 Disposal of DAW generated 1

0 16 4

22 22 292 5,846 1

3b.4.7 Plant energy budget 462 69 531 531 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 1,486 223 1,708 1,708 34,770 3b.4.11 DOC Staff Cost 4,781 717 5,498 5,498 58,560 3b.4.12 Utility Staff Cost 9,767 1,465 11,232 11,232 130,714 3b.4 Subtotal Period 3b Period-Dependent Costs 24 408 1

0 16 17,102 2,630 20,181 20,181 292 5,846 1

224,044 3b.0 TOTAL PERIOD 3b COST 822 1,508 1

0 16 28,377 5,557 36,281 35,433 848 292 5,846 30,501 267,139 PERIOD 3 TOTALS 822 2,284 2

1 45 66,498 11,382 81,035 79,540 1,495 808 16,157 30,504 669,906 PERIOD 4a - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Reactor Coolant Piping 40 138 31 28 331 144 712 712 1,677 202,809 3,153 4a.1.1.2 Pressurizer Relief Tank 7

26 6

5 60 26 131 131 329 36,553 596 4a.1.1.3 Reactor Coolant Pumps & Motors 25 94 53 168 1,272 384 1,996 1,996 4,796 780,540 2,726 80 4a.1.1.4 Pressurizer 11 59 345 94 412 172 1,093 1,093 3,033 252,826 1,527 750 4a.1.1.5 Steam Generators 85 4,096 2,098 2,506 667 4,349 2,839 16,640 16,640 45,513 17,359 3,811,289 20,508 1,500 4a.1.1.6 Retired Steam Generator Units 1,426 2,644 580 3,416 1,480 9,546 9,546 39,289 14,064 3,041,432 10,800 1,500 4a.1.1.7 CRDMs/ICIs/Service Structure Removal 35 89 194 34 102 90 543 543 3,881 86,025 2,135 4a.1.1.8 Reactor Vessel Internals 69 2,029 3,483 555 4,878 208 5,036 16,258 16,258 1,710 876 459 325,944 23,633 1,077 4a.1.1.9 Vessel & Internals GTCC Disposal 11,665 1,750 13,414 13,414 505 104,146 4a.1.1.10 Reactor Vessel 85 3,998 1,314 675 3,107 208 5,123 14,510 14,510 6,606 2,254 978,589 23,633 1,077 4a.1.1 Totals 357 10,529 8,951 6,708 1,247 29,591 415 17,045 74,844 74,844 84,802 53,456 3,130 459 505 9,620,152 88,712 5,985 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 510 256 32 214 190 1,201 1,201 5,355 455,213 9,016 4a.1.3 Main Condensers 1,042 133 27 150 300 1,653 1,653 7,111 320,000 18,250 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor 1,076 161 1,237 1,237 12,130 4a.1.4.2 Auxiliary Building 594 89 683 683 6,810 4a.1.4.3 Refueling Water Storage Tank 104 16 120 120 1,299 4a.1.4 Totals 1,773 266 2,039 2,039 20,238 Disposal of Plant Systems 4a.1.5.1 Auxiliary Feedwater 69 10 79 79 1,244 4a.1.5.2 Auxiliary Steam 61 9

71 71 1,126 4a.1.5.3 Auxiliary Steam RCA 122 2

3 16 34 176 176 835 33,900 1,935 4a.1.5.4 Boric Acid Processing 444 32 31 86 99 157 850 850 4,531 1,193 268,274 7,890 4a.1.5.5 CO2 & H2 23 3

26 26 419 4a.1.5.6 CO2 & H2 RCA 35 0

1 3

9 48 48 164 6,658 572 4a.1.5.7 Chemical Feed 51 8

58 58 934 4a.1.5.8 Chilled Water 63 9

72 72 1,142 4a.1.5.9 Circulating Water 279 42 321 321 5,150 4a.1.5.10 Condensate 331 50 381 381 6,023 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 8 of 24 Table D-1 Byron Nuclear Power Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:52 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.1.5.11 Condensate Booster 299 45 344 344 5,428 4a.1.5.12 Condensate Cleanup 58 9

67 67 1,060 4a.1.5.13 Containment Spray 233 7

12 69 71 392 392 3,629 147,367 3,729 4a.1.5.14 Diesel Fuel Oil 90 13 103 103 1,615 4a.1.5.15 Essential Service Water 208 31 239 239 3,837 4a.1.5.16 Extraction Steam 167 25 192 192 3,089 4a.1.5.17 Feedwater 278 42 320 320 5,142 4a.1.5.18 Feedwater Drains 668 100 768 768 12,366 4a.1.5.19 Gland Steam 50 8

58 58 932 4a.1.5.20 Gland Water 44 7

51 51 828 4a.1.5.21 Main Steam 284 43 326 326 5,216 4a.1.5.22 Main Steam RCA 46 1

3 15 14 79 79 760 30,853 739 4a.1.5.23 Nitrogen 3

0 0

1 1

5 5

52 2,102 49 4a.1.5.24 Non-Essential Service Water 157 23 180 180 2,916 4a.1.5.25 Non-Essential Service Water RCA 86 3

5 28 27 148 148 1,462 59,354 1,295 4a.1.5.26 Off Gas 512 10 19 106 148 795 795 5,572 226,266 8,494 4a.1.5.27 Process Radiation Monitoring 37 0

0 2

10 49 49 113 4,587 666 4a.1.5.28 Process Sampling 107 1

2 12 29 151 151 616 25,019 1,927 4a.1.5.29 Station Air 27 4

31 31 498 4a.1.5.30 Station Heating 96 14 111 111 1,771 4a.1.5.31 Switchgear Heat Removal 8

1 9

9 139 4a.1.5.32 Turbine Bldg Equip Drains 1

0 1

1 17 4a.1.5.33 Turbine Generator 50 8

58 58 901 4a.1.5.34 Turbine Oil 77 12 88 88 1,399 4a.1.5.35 Waste Oil Sumps 26 4

30 30 483 4a.1.5 Totals 5,090 56 75 338 99 1,019 6,678 2,694 3,984 17,732 1,193 804,381 90,969 4a.1.6 Scaffolding in support of decommissioning 941 6

1 6

2 237 1,194 1,194 306 19 15,459 18,101 4a.1 Subtotal Period 4a Activity Costs 357 19,885 9,401 6,844 1,956 29,693 415 19,058 87,609 83,625 3,984 115,307 54,668 3,130 459 505 11,215,210 245,285 5,985 Period 4a Collateral Costs 4a.3.1 Process liquid waste 76 34 154 150 102 516 516 539 32,357 105 4a.3.2 Small tool allowance 210 32 242 218 24 4a.3 Subtotal Period 4a Collateral Costs 76 210 34 154 150 134 757 733 24 539 32,357 105 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 65 16 81 81 4a.4.2 Insurance 448 45 493 493 4a.4.3 Property taxes 668 67 735 661 73 4a.4.4 Health physics supplies 1,484 371 1,855 1,855 4a.4.5 Heavy equipment rental 2,333 350 2,683 2,683 4a.4.6 Disposal of DAW generated 9

3 177 46 235 235 3,170 63,404 15 4a.4.7 Plant energy budget 1,169 175 1,345 1,345 4a.4.8 NRC Fees 880 88 968 968 4a.4.9 Site O&M Costs 167 25 192 192 4a.4.10 Liquid Radwaste Processing Equipment/Services 512 77 589 589 4a.4.11 Security Staff Cost 2,367 355 2,722 2,722 61,683 4a.4.12 DOC Staff Cost 15,170 2,275 17,445 17,445 190,432 4a.4.13 Utility Staff Cost 24,665 3,700 28,365 28,365 335,716 4a.4 Subtotal Period 4a Period-Dependent Costs 65 3,817 9

3 177 46,047 7,590 57,708 57,635 73 3,170 63,404 15 587,831 4a.0 TOTAL PERIOD 4a COST 498 23,913 9,444 7,001 1,956 30,020 46,462 26,781 146,075 141,993 4,081 115,307 58,377 3,130 459 505 11,310,970 245,405 593,816 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 9 of 24 Table D-1 Byron Nuclear Power Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:52 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 - Site Decontamination Disposal of Plant Systems 4b.1.2.1 Chemical & Volume Control 1,000 62 46 33 255 332 1,728 1,728 1,744 2,431 287,102 16,313 4b.1.2.2 Chilled Water RCA 282 8

16 90 87 484 484 4,716 191,536 4,732 4b.1.2.3 Component Cooling RCA 604 15 29 164 181 994 994 8,589 348,801 9,675 4b.1.2.4 Electrical 2,682 402 3,085 3,085 48,490 4b.1.2.5 Electrical - Contaminated 1,028 12 23 128 281 1,471 1,471 6,722 272,965 17,115 4b.1.2.6 Electrical - RCA 1,706 32 59 335 489 2,621 2,621 17,555 712,922 29,098 4b.1.2.7 Emergency Diesel Generator 113 17 130 130 2,066 4b.1.2.8 Essential Service Water RCA 271 9

17 99 86 482 482 5,177 210,230 4,418 4b.1.2.9 Fire Protection 108 16 124 124 1,984 4b.1.2.10 Fire Protection RCA 168 2

4 20 46 240 240 1,069 43,397 2,628 4b.1.2.11 HVAC-Auxiliary Building 445 9

17 96 129 697 697 5,054 205,243 7,162 4b.1.2.12 HVAC-Diesel Generator Room 38 6

44 44 682 4b.1.2.13 HVAC-Miscellaneous 37 5

42 42 656 4b.1.2.14 HVAC-Primary Containment 539 19 36 204 173 970 970 10,679 433,695 8,624 4b.1.2.15 HVAC-Turbine Building 164 25 188 188 3,177 4b.1.2.16 Instrument Air Supply 41 6

47 47 760 4b.1.2.17 Instrument Air Supply RCA 67 1

1 7

18 94 94 366 14,869 1,073 4b.1.2.18 Miscellaneous Drains 35 1

1 6

10 52 52 312 12,666 584 4b.1.2.19 Primary Containment Purge 247 10 20 112 82 471 471 5,850 237,590 4,312 4b.1.2.20 Primary Water 54 1

1 3

4 15 79 79 143 42 9,560 915 4b.1.2.21 Radioactive Waste Disposal 817 45 39 81 154 265 1,400 1,400 4,235 1,622 302,491 14,169 4b.1.2.22 Reactor Building Equipment Drains 88 7

5 3

29 31 164 164 183 277 32,048 1,435 4b.1.2.23 Reactor Building Floor Drains 41 2

2 2

8 13 68 68 130 74 11,914 678 4b.1.2.24 Reactor Coolant 155 9

6 4

34 50 257 257 208 324 37,451 2,506 4b.1.2.25 Residual Heat Removal 172 11 12 28 44 61 328 328 1,453 418 96,526 2,924 4b.1.2.26 Safety Injection 783 37 47 175 103 259 1,404 1,404 9,181 1,028 460,142 13,528 4b.1.2.27 Station Air RCA 33 0

1 3

9 46 46 175 7,089 521 4b.1.2.28 Station Heating RCA 109 2

4 24 32 171 171 1,256 51,005 1,759 4b.1.2.29 Waste Oil Sumps RCA 7

0 0

1 2

10 10 52 2,098 92 4b.1.2 Totals 11,832 293 386 1,619 632 3,128 17,891 14,231 3,660 84,848 6,216 3,981,341 202,075 4b.1.3 Scaffolding in support of decommissioning 1,411 9

2 10 3

356 1,791 1,791 458 29 23,188 27,151 Decontamination of Site Buildings 4b.1.4.1 Reactor 1,748 1,236 177 192 134 604 1,401 5,491 5,491 7,022 8,897 1,144,531 50,361 4b.1.4.2 Auxiliary Building 175 93 6

7 17 13 118 428 428 866 228 57,032 4,547 4b.1.4.3 Refueling Water Storage Tank 315 366 4

5 22 6

255 973 973 1,146 87 54,853 11,906 4b.1.4 Totals 2,238 1,695 187 204 172 623 1,774 6,893 6,893 9,034 9,212 1,256,416 66,815 4b.1 Subtotal Period 4b Activity Costs 2,238 14,938 490 591 1,802 1,258 5,258 26,575 22,914 3,660 94,341 15,456 5,260,945 296,041 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 33 0

23 89 626 128 899 899 1,689 142,287 1,585 1,280 4b.2.3 Soil Remediation 17 0

52 143 48 260 260 2,730 207,480 99 4b.2 Subtotal Period 4b Additional Costs 50 1

75 232 1,566 458 2,381 1,482 899 4,419 349,767 1,684 7,520 Period 4b Collateral Costs 4b.3.1 Process liquid waste 92 41 186 182 123 623 623 652 39,118 127 4b.3.2 Small tool allowance 268 40 309 309 4b.3.3 Decommissioning Equipment Disposition 119 34 127 40 46 365 365 6,000 373 303,507 88 4b.3 Subtotal Period 4b Collateral Costs 92 268 160 219 127 221 209 1,297 1,297 6,000 1,025 342,625 215 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 10 of 24 Table D-1 Byron Nuclear Power Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:52 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 4b.4.1 Decon supplies 657 164 821 821 4b.4.2 Insurance 743 74 818 818 4b.4.3 Property taxes 1,109 111 1,220 1,220 4b.4.4 Health physics supplies 1,958 490 2,448 2,448 4b.4.5 Heavy equipment rental 3,841 576 4,418 4,418 4b.4.6 Disposal of DAW generated 12 5

241 62 320 320 4,311 86,211 20 4b.4.7 Plant energy budget 1,532 230 1,762 1,762 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 952 143 1,095 1,095 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 657 5,800 12 5

241 51,030 8,781 66,526 66,526 4,311 86,211 20 631,800 4b.0 TOTAL PERIOD 4b COST 2,987 21,056 663 890 1,929 1,952 52,597 14,706 96,779 92,219 899 3,660 100,341 25,211 6,039,548 297,960 639,320 PERIOD 4d - Delay before License Termination Period 4d Period-Dependent Costs 4d.4.1 Insurance 4d.4.2 Property taxes 643 64 708 708 4d.4.3 Health physics supplies 96 24 120 120 4d.4.4 Disposal of DAW generated 0

0 7

2 10 10 128 2,567 1

4d.4.5 Plant energy budget 4d.4.6 NRC Fees 235 23 258 258 4d.4.7 Site O&M Costs 161 24 185 185 4d.4.8 Security Staff Cost 3

0 4

4 4d.4.9 Utility Staff Cost 1,323 198 1,522 1,522 18,800 4d.4 Subtotal Period 4d Period-Dependent Costs 96 0

0 7

2,365 337 2,806 2,806 128 2,567 1

18,800 4d.0 TOTAL PERIOD 4d COST 96 0

0 7

2,365 337 2,806 2,806 128 2,567 1

18,800 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 5,485 1,646 7,131 7,131 91,793 3,120 4e.2 Subtotal Period 4e Additional Costs 5,485 1,646 7,131 7,131 91,793 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 376 38 414 414 4e.4.3 Health physics supplies 597 149 746 746 4e.4.4 Disposal of DAW generated 1

0 19 5

25 25 335 6,698 2

4e.4.5 Plant energy budget 139 21 160 160 4e.4.6 NRC Fees 532 53 585 585 4e.4.7 Site O&M Costs 94 14 108 108 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 11 of 24 Table D-1 Byron Nuclear Power Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:52 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 Period-Dependent Costs (continued) 4e.4.8 Security Staff Cost 532 80 612 612 11,786 4e.4.9 DOC Staff Cost 3,801 570 4,371 4,371 46,750 4e.4.10 Utility Staff Cost 4,551 683 5,234 5,234 56,964 4e.4 Subtotal Period 4e Period-Dependent Costs 597 1

0 19 10,024 1,612 12,253 12,253 335 6,698 2

115,500 4e.0 TOTAL PERIOD 4e COST 597 1

0 19 16,791 3,473 20,880 20,880 335 6,698 91,795 118,620 PERIOD 4 TOTALS 3,485 45,661 10,108 7,891 3,885 31,998 118,215 45,297 266,540 257,899 899 7,742 215,647 84,052 3,130 459 505 17,359,780 635,160 1,370,556 PERIOD 5b - Site Restoration Period 5b Direct Decommissioning Activities Demolition of Remaining Site Buildings 5b.1.1.1 Reactor 6,217 933 7,149 7,149 69,541 5b.1.1.2 Auxiliary Building 5,342 801 6,143 6,143 61,287 5b.1.1.3 Old Steam Generator Storage Facility 417 63 479 479 4,868 5b.1.1.4 Refueling Water Storage Tank 936 140 1,077 1,077 11,688 5b.1.1.5 Turbine Building 5,246 787 6,033 6,033 70,347 5b.1.1.6 Turbine Pedestal 1,250 187 1,437 1,437 12,628 5b.1.1 Totals 19,408 2,911 22,319 22,319 230,359 Site Closeout Activities 5b.1.2 Grade & landscape site 267 40 307 307 869 5b.1.3 Final report to NRC 184 28 212 212 1,560 5b.1 Subtotal Period 5b Activity Costs 19,675 184 2,979 22,838 212 22,626 231,228 1,560 Period 5b Additional Costs 5b.2.1 Hyperbolic Cooling Tower 3,461 519 3,980 3,980 18,598 5b.2.2 Concrete Crushing 574 3

87 664 664 2,798 5b.2.3 ISFSI Demolition and Site Restoration 534 24 84 642 642 6,183 80 5b.2 Subtotal Period 5b Additional Costs 4,569 27 689 5,286 642 4,644 27,579 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 247 37 284 284 5b.3 Subtotal Period 5b Collateral Costs 247 37 284 284 Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property taxes 1,239 124 1,363 1,363 5b.4.3 Heavy equipment rental 6,137 921 7,057 7,057 5b.4.4 Plant energy budget 228 34 262 262 5b.4.5 Site O&M Cost 310 46 356 356 5b.4.6 Security Staff Cost 1,582 237 1,819 1,819 34,287 5b.4.7 DOC Staff Cost 11,650 1,748 13,398 13,398 137,043 5b.4.8 Utility Staff Cost 5,559 834 6,392 6,392 67,229 5b.4 Subtotal Period 5b Period-Dependent Costs 6,137 20,567 3,944 30,648 30,648 238,558 5b.0 TOTAL PERIOD 5b COST 30,628 20,779 7,649 59,055 212 642 58,201 258,806 240,198 PERIOD 5 TOTALS 30,628 20,779 7,649 59,055 212 642 58,201 258,806 240,198 TOTAL COST TO DECOMMISSION 8,429 81,855 10,274 8,549 3,885 33,101 382,783 92,254 621,131 420,024 133,669 67,438 215,647 94,742 3,130 459 505 17,664,760 983,770 4,096,980 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 12 of 24 Table D-1 Byron Nuclear Power Station, Unit 1 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:03:52 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 17.44% CONTINGENCY:

$621,131 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 67.62% OR:

$420,024 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 21.52% OR:

$133,669 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 10.86% OR:

$67,438 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

98,330 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

505 cubic feet TOTAL SCRAP METAL REMOVED:

58,942 tons TOTAL CRAFT LABOR REQUIREMENTS:

983,770 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.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 13 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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 66 10 76 76 556 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 101 15 116 116 856 1a.1.8 Review plant dwgs & specs.

66 10 76 76 556 1a.1.9 Perform detailed rad survey a

1a.1.10 Estimate by-product inventory 51 8

58 58 428 1a.1.11 End product description 51 8

58 58 428 1a.1.12 Detailed by-product inventory 76 11 87 87 642 1a.1.13 Define major work sequence 51 8

58 58 428 1a.1.14 Perform SER and EA 157 23 180 180 1,327 1a.1.15 Perform Site-Specific Cost Study 253 38 290 290 2,140 Activity Specifications 1a.1.16.1 Prepare plant and facilities for SAFSTOR 249 37 286 286 2,106 1a.1.16.2 Plant systems 210 32 242 242 1,783 1a.1.16.3 Plant structures and buildings 158 24 181 181 1,335 1a.1.16.4 Waste management 101 15 116 116 856 1a.1.16.5 Facility and site dormancy 101 15 116 116 856 1a.1.16 Total 819 123 941 941 6,936 Detailed Work Procedures 1a.1.17.1 Plant systems 60 9

69 69 506 1a.1.17.2 Facility closeout & dormancy 61 9

70 70 514 1a.1.17 Total 120 18 138 138 1,020 1a.1.18 Procure vacuum drying system 5

1 6

6 43 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 2,211 391 2,602 2,602 15,361 Period 1a Period-Dependent Costs 1a.4.1 Insurance 769 77 846 846 1a.4.2 Property taxes 1a.4.3 Health physics supplies 414 104 518 518 1a.4.4 Heavy equipment rental 414 62 476 476 1a.4.5 Disposal of DAW generated 2

1 34 9

45 45 610 12,190 3

1a.4.6 Plant energy budget 921 138 1,059 1,059 1a.4.7 NRC Fees 471 47 518 518 1a.4.8 Emergency Planning Fees 306 31 337 337 1a.4.9 Site O&M Costs 125 19 144 144 1a.4.10 Spent Fuel Pool O&M 381 57 438 438 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 6,241 936 7,177 7,177 157,471 1a.4.13 Utility Staff Cost 31,082 4,662 35,745 35,745 423,400 1a.4 Subtotal Period 1a Period-Dependent Costs 828 2

1 34 40,340 6,148 47,353 46,527 826 610 12,190 3

580,871 1a.0 TOTAL PERIOD 1a COST 828 2

1 34 42,551 6,539 49,955 49,129 826 610 12,190 3

596,232 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 14 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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 1,924 962 2,886 2,886 33,093 1b.1.1.2 Auxiliary Building 222 111 333 333 3,830 1b.1.1.3 Radwaste/Service Building 145 72 217 217 2,506 1b.1.1.4 Refueling Water Storage Tank 314 157 471 471 5,322 1b.1.1.5 Fuel Handling Building 899 449 1,348 1,348 15,238 1b.1.1 Totals 3,504 1,752 5,255 5,255 59,990 1b.1 Subtotal Period 1b Activity Costs 3,504 1,752 5,255 5,255 59,990 Period 1b Collateral Costs 1b.3.1 Decon equipment 797 120 917 917 1b.3.2 Process liquid waste 205 87 398 389 268 1,347 1,347 1,398 83,853 272 1b.3.3 Small tool allowance 56 8

65 65 1b.3 Subtotal Period 1b Collateral Costs 1,003 56 87 398 389 396 2,329 2,329 1,398 83,853 272 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 734 184 918 918 1b.4.2 Insurance 192 19 211 211 1b.4.3 Property taxes 2,452 245 2,697 2,697 1b.4.4 Health physics supplies 335 84 418 418 1b.4.5 Heavy equipment rental 103 15 119 119 1b.4.6 Disposal of DAW generated 2

1 33 8

43 43 585 11,700 3

1b.4.7 Plant energy budget 229 34 264 264 1b.4.8 NRC Fees 117 12 129 129 1b.4.9 Emergency Planning Fees 76 8

84 84 1b.4.10 Site O&M Costs 31 5

36 36 1b.4.11 Spent Fuel Pool O&M 95 14 109 109 1b.4.12 ISFSI Operating Costs 11 2

13 13 1b.4.13 Security Staff Cost 1,556 233 1,789 1,789 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 734 438 2

1 33 12,509 2,026 15,742 15,536 206 585 11,700 3

144,820 1b.0 TOTAL PERIOD 1b COST 5,240 494 89 399 422 12,509 4,174 23,326 23,120 206 1,983 95,552 60,265 144,820 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 431 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

34 34 250 1c.1 Subtotal Period 1c Activity Costs 473 762 295 1,530 1,530 17,116 250 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 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 15 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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 251 106 487 476 328 1,649 1,649 1,710 102,618 333 1c.3.2 Small tool allowance 4

1 4

4 1c.3 Subtotal Period 1c Collateral Costs 251 4

106 487 476 329 1,653 1,653 1,710 102,618 333 Period 1c Period-Dependent Costs 1c.4.1 Insurance 192 19 211 211 1c.4.2 Property taxes 2,452 245 2,697 2,697 1c.4.3 Health physics supplies 145 36 182 182 1c.4.4 Heavy equipment rental 103 15 119 119 1c.4.5 Disposal of DAW generated 0

0 6

2 8

8 107 2,132 0

1c.4.6 Plant energy budget 229 34 264 264 1c.4.7 NRC Fees 117 12 129 129 1c.4.8 Emergency Planning Fees 76 8

84 84 1c.4.9 Site O&M Costs 31 5

36 36 1c.4.10 Spent Fuel Pool O&M 95 14 109 109 1c.4.11 ISFSI Operating Costs 11 2

13 13 1c.4.12 Security Staff Cost 1,556 233 1,789 1,789 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 249 0

0 6

6,906 947 8,109 7,903 206 107 2,132 0

66,300 1c.0 TOTAL PERIOD 1c COST 251 725 107 487 482 17,358 3,025 22,435 22,229 206 1,817 104,751 17,450 66,550 PERIOD 1 TOTALS 5,491 2,047 197 886 938 72,418 13,738 95,716 94,478 1,238 4,409 212,493 77,717 807,602 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 192 29 220 220 2a.1.5 Maintenance supplies 1,665 416 2,081 2,081 2a.1 Subtotal Period 2a Activity Costs 1,856 445 2,301 2,301 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 12,500 1,875 14,375 14,375 2a.3 Subtotal Period 2a Collateral Costs 12,500 1,875 14,375 14,375 Period 2a Period-Dependent Costs 2a.4.1 Insurance 4,436 444 4,879 4,273 606 2a.4.2 Property taxes 15,718 1,572 17,290 7,279 10,011 2a.4.3 Health physics supplies 1,061 265 1,327 1,327 2a.4.4 Disposal of DAW generated 15 5

283 73 376 376 5,077 101,533 23 2a.4.5 Plant energy budget 2,438 366 2,804 1,402 1,402 2a.4.6 NRC Fees 2,367 237 2,604 2,604 2a.4.7 Emergency Planning Fees 1,324 132 1,456 1,456 2a.4.8 Site O&M Costs 1,654 248 1,902 1,902 2a.4.9 Spent Fuel Pool O&M 5,844 877 6,721 6,721 2a.4.10 ISFSI Operating Costs 582 87 669 669 2a.4.11 Security Staff Cost 34,590 5,189 39,779 37 39,741 851,336 2a.4.12 Utility Staff Cost 32,968 4,945 37,913 8,300 29,613 420,144 2a.4 Subtotal Period 2a Period-Dependent Costs 1,061 15 5

283 101,921 14,434 117,720 27,500 90,219 5,077 101,533 23 1,271,480 2a.0 TOTAL PERIOD 2a COST 1,061 15 5

283 116,277 16,754 134,396 29,802 104,594 5,077 101,533 23 1,271,480 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 16 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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 21 3

24 24 2b.1.5 Maintenance supplies 178 45 223 223 2b.1 Subtotal Period 2b Activity Costs 199 48 247 247 Period 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 2,125 319 2,444 2,444 2b.3 Subtotal Period 2b Collateral Costs 2,125 319 2,444 2,444 Period 2b Period-Dependent Costs 2b.4.1 Insurance 430 43 473 458 15 2b.4.2 Property taxes 709 71 780 780 2b.4.3 Health physics supplies 109 27 136 136 2b.4.4 Disposal of DAW generated 2

1 30 8

40 40 535 10,702 2

2b.4.5 Plant energy budget 131 20 150 150 2b.4.6 NRC Fees 254 25 279 279 2b.4.7 Emergency Planning Fees 142 14 156 156 2b.4.8 Site O&M Costs 177 27 204 204 2b.4.9 ISFSI Operating Costs 62 9

72 72 2b.4.10 Security Staff Cost 1,760 264 2,024 4

2,020 39,960 2b.4.11 Utility Staff Cost 2,150 323 2,473 889 1,583 29,600 2b.4 Subtotal Period 2b Period-Dependent Costs 109 2

1 30 5,815 830 6,787 2,940 3,846 535 10,702 2

69,560 2b.0 TOTAL PERIOD 2b COST 109 2

1 30 8,139 1,197 9,477 3,187 6,290 535 10,702 2

69,560 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 12 2

14 14 2c.1.5 Maintenance supplies 108 27 136 136 2c.1 Subtotal Period 2c Activity Costs 121 29 150 150 Period 2c Period-Dependent Costs 2c.4.1 Insurance 253 25 278 278 2c.4.2 Property taxes 431 43 474 474 2c.4.3 Health physics supplies 63 16 78 78 2c.4.4 Disposal of DAW generated 1

0 18 5

24 24 319 6,383 1

2c.4.5 Plant energy budget 79 12 91 91 2c.4.6 NRC Fees 147 15 162 162 2c.4.7 Site O&M Costs 108 16 124 124 2c.4.8 Security Staff Cost 2

0 2

2 2c.4.9 Utility Staff Cost 470 71 541 541 7,200 2c.4 Subtotal Period 2c Period-Dependent Costs 63 1

0 18 1,491 202 1,775 1,775 319 6,383 1

7,200 2c.0 TOTAL PERIOD 2c COST 63 1

0 18 1,612 231 1,925 1,925 319 6,383 1

7,200 PERIOD 2 TOTALS 1,233 17 6

331 126,029 18,183 145,798 34,914 110,884 5,931 118,618 27 1,348,240 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 17 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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 - Reactivate Site Following SAFSTOR Dormancy Period 3a Direct Decommissioning Activities 3a.1.1 Prepare preliminary decommissioning cost 66 10 76 76 556 3a.1.2 Review plant dwgs & specs.

232 35 267 267 1,969 3a.1.3 Perform detailed rad survey a

3a.1.4 End product description 51 8

58 58 428 3a.1.5 Detailed by-product inventory 66 10 76 76 556 3a.1.6 Define major work sequence 379 57 436 436 3,210 3a.1.7 Perform SER and EA 157 23 180 180 1,327 3a.1.8 Perform Site-Specific Cost Study 253 38 290 290 2,140 3a.1.9 Prepare/submit License Termination Plan 207 31 238 238 1,753 3a.1.10 Receive NRC approval of termination plan a

Activity Specifications 3a.1.11.1 Re-activate plant & temporary facilities 372 56 428 385 43 3,154 3a.1.11.2 Plant systems 210 32 242 218 24 1,783 3a.1.11.3 Reactor internals 359 54 412 412 3,039 3a.1.11.4 Reactor vessel 328 49 378 378 2,782 3a.1.11.5 Biological shield 25 4

29 29 214 3a.1.11.6 Steam generators 158 24 181 181 1,335 3a.1.11.7 Reinforced concrete 81 12 93 46 46 685 3a.1.11.8 Main Turbine 20 3

23 23 171 3a.1.11.9 Main Condensers 20 3

23 23 171 3a.1.11.10 Plant structures & buildings 158 24 181 91 91 1,335 3a.1.11.11 Waste management 232 35 267 267 1,969 3a.1.11.12 Facility & site closeout 45 7

52 26 26 385 3a.1.11 Total 2,009 301 2,310 2,034 277 17,024 Planning & Site Preparations 3a.1.12 Prepare dismantling sequence 121 18 139 139 1,027 3a.1.13 Plant prep. & temp. svces 2,800 420 3,220 3,220 3a.1.14 Design water clean-up system 71 11 81 81 599 3a.1.15 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,200 330 2,530 2,530 3a.1.16 Procure casks/liners & containers 62 9

71 71 526 3a.1 Subtotal Period 3a Activity Costs 8,672 1,301 9,973 9,696 277 31,117 Period 3a Period-Dependent Costs 3a.4.1 Insurance 303 30 333 333 3a.4.2 Property taxes 500 50 550 550 3a.4.3 Health physics supplies 344 86 430 430 3a.4.4 Heavy equipment rental 414 62 476 476 3a.4.5 Disposal of DAW generated 1

1 27 7

36 36 481 9,613 2

3a.4.6 Plant energy budget 921 138 1,059 1,059 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 235 35 270 270 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 757 1

1 27 16,557 2,588 19,931 19,931 481 9,613 2

206,486 3a.0 TOTAL PERIOD 3a COST 757 1

1 27 25,229 3,888 29,904 29,627 277 481 9,613 2

237,603 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 18 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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 - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 239 36 275 247 27 2,026 3b.1.1.2 Reactor internals 126 19 145 145 1,070 3b.1.1.3 Remaining buildings 68 10 78 20 59 578 3b.1.1.4 CRD cooling assembly 51 8

58 58 428 3b.1.1.5 CRD housings & ICI tubes 51 8

58 58 428 3b.1.1.6 Incore instrumentation 51 8

58 58 428 3b.1.1.7 Reactor vessel 183 28 211 211 1,554 3b.1.1.8 Facility closeout 61 9

70 35 35 514 3b.1.1.9 Missile shields 23 3

26 26 193 3b.1.1.10 Biological shield 61 9

70 70 514 3b.1.1.11 Steam generators 232 35 267 267 1,969 3b.1.1.12 Reinforced concrete 51 8

58 29 29 428 3b.1.1.13 Main Turbine 79 12 91 91 668 3b.1.1.14 Main Condensers 79 12 91 91 668 3b.1.1.15 Auxiliary building 138 21 159 143 16 1,168 3b.1.1.16 Reactor building 138 21 159 143 16 1,168 3b.1.1 Total 1,629 244 1,873 1,510 363 13,800 3b.1 Subtotal Period 3b Activity Costs 1,629 244 1,873 1,510 363 13,800 Period 3b Additional Costs 3b.2.1 Site Characterization 2,711 813 3,525 3,525 13,042 4,640 3b.2 Subtotal Period 3b Additional Costs 2,711 813 3,525 3,525 13,042 4,640 Period 3b Collateral Costs 3b.3.1 Decon equipment 797 120 917 917 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 797 1,100 1,130 454 3,482 3,482 Period 3b Period-Dependent Costs 3b.4.1 Decon supplies 24 6

31 31 3b.4.2 Insurance 168 17 185 185 3b.4.3 Property taxes 251 25 276 276 3b.4.4 Health physics supplies 186 46 232 232 3b.4.5 Heavy equipment rental 207 31 238 238 3b.4.6 Disposal of DAW generated 1

0 15 4

20 20 266 5,315 1

3b.4.7 Plant energy budget 462 69 531 531 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 118 18 136 136 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 24 393 1

0 15 11,613 1,803 13,850 13,850 266 5,315 1

146,400 3b.0 TOTAL PERIOD 3b COST 822 1,493 1

0 15 17,083 3,315 22,729 22,366 363 266 5,315 13,043 164,840 PERIOD 3 TOTALS 822 2,251 2

1 42 42,312 7,203 52,632 51,993 640 746 14,927 13,045 402,442 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 19 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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 - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Reactor Coolant Piping 38 131 30 26 317 138 679 679 1,606 194,222 2,979 4a.1.1.2 Pressurizer Relief Tank 7

26 6

5 60 26 131 131 329 36,553 596 4a.1.1.3 Reactor Coolant Pumps & Motors 25 94 53 168 1,272 384 1,996 1,996 4,796 780,540 2,726 80 4a.1.1.4 Pressurizer 11 59 345 94 412 172 1,093 1,093 3,033 252,826 1,527 750 4a.1.1.5 Steam Generators 85 4,096 1,426 2,363 580 3,416 2,505 14,471 14,471 39,289 14,436 3,096,232 20,508 1,500 4a.1.1.6 CRDMs/ICIs/Service Structure Removal 35 89 194 34 102 90 543 543 3,881 86,025 2,135 4a.1.1.7 Reactor Vessel Internals 69 2,029 3,483 555 4,946 208 5,070 16,360 16,360 1,710 876 459 325,944 23,633 1,077 4a.1.1.8 Vessel & Internals GTCC Disposal 11,665 1,750 13,414 13,414 505 104,146 4a.1.1.9 Reactor Vessel 85 3,998 1,314 675 3,129 208 5,134 14,544 14,544 6,606 2,254 978,589 23,633 1,077 4a.1.1 Totals 355 10,521 6,852 3,921 580 25,318 415 15,268 63,231 63,231 39,289 36,398 3,130 459 505 5,855,076 77,738 4,485 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 510 256 32 214 190 1,201 1,201 5,355 455,213 9,016 4a.1.3 Main Condensers 1,042 133 27 150 300 1,653 1,653 7,111 320,000 18,250 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor 1,076 161 1,237 1,237 12,130 4a.1.4.2 Auxiliary Building 602 90 692 692 6,896 4a.1.4.3 Radwaste/Service Building 391 59 450 450 5,060 4a.1.4.4 Refueling Water Storage Tank 104 16 120 120 1,299 4a.1.4.5 Fuel Handling Building 309 46 355 355 3,690 4a.1.4 Totals 2,481 372 2,853 2,853 29,074 Disposal of Plant Systems 4a.1.5.1 Auxiliary Feedwater 224 3

6 36 63 331 331 1,866 75,766 3,747 4a.1.5.2 Auxiliary Steam 115 17 132 132 2,107 4a.1.5.3 Auxiliary Steam RCA 326 5

10 54 92 486 486 2,822 114,583 5,241 4a.1.5.4 Boric Acid Processing 421 27 23 34 106 143 755 755 1,794 1,076 162,827 6,970 4a.1.5.5 CO2 & H2 16 2

18 18 289 4a.1.5.6 CO2 & H2 RCA 31 1

1 5

9 46 46 287 11,664 478 4a.1.5.7 Chemical Feed 145 22 167 167 2,663 4a.1.5.8 Chilled Water 80 12 92 92 1,454 4a.1.5.9 Circulating Water 525 79 604 604 9,669 4a.1.5.10 Condensate 293 44 337 337 5,317 4a.1.5.11 Condensate Booster 293 44 336 336 5,314 4a.1.5.12 Condensate Cleanup 160 24 184 184 3,000 4a.1.5.13 Containment Spray 229 6

12 69 70 386 386 3,602 146,289 3,673 4a.1.5.14 Diesel Fuel Oil 158 24 182 182 2,848 4a.1.5.15 Essential Service Water 274 41 315 315 5,049 4a.1.5.16 Extraction Steam 196 29 226 226 3,637 4a.1.5.17 Feedwater 267 40 307 307 4,925 4a.1.5.18 Feedwater Drains 633 95 728 728 11,719 4a.1.5.19 Gland Steam 33 5

38 38 616 4a.1.5.20 Gland Water 24 4

28 28 458 4a.1.5.21 Main Steam 271 41 312 312 4,979 4a.1.5.22 Main Steam RCA 76 2

3 19 23 123 123 990 40,190 1,250 4a.1.5.23 Make-up Demineralizer 137 21 158 158 2,595 4a.1.5.24 Nitrogen 1

0 1

1 18 4a.1.5.25 Non-Essential Service Water 318 48 366 366 5,903 4a.1.5.26 Non-Essential Service Water RCA 163 7

13 75 55 313 313 3,909 158,755 2,535 4a.1.5.27 Off Gas 605 13 25 141 177 962 962 7,411 300,945 10,038 4a.1.5.28 Potable Water 4

1 5

5 75 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 20 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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 Process Radiation Monitoring 59 0

0 3

15 77 77 138 5,613 1,086 4a.1.5.30 Process Sampling 129 1

2 12 35 179 179 641 26,045 2,347 4a.1.5.31 Sewage Treatment Plant 85 13 98 98 1,579 4a.1.5.32 Station Air 38 6

44 44 705 4a.1.5.33 Station Heating 130 19 149 149 2,391 4a.1.5.34 Steam Humidification 6

1 7

7 115 4a.1.5.35 Switchgear Heat Removal 29 4

33 33 519 4a.1.5.36 Turbine Bldg Equip Drains 67 10 77 77 1,235 4a.1.5.37 Turbine Bldg Floor Drains 115 17 133 133 2,117 4a.1.5.38 Turbine Oil 73 11 84 84 1,359 4a.1.5.39 Turbine-Generator Auxilaries 49 7

57 57 884 4a.1.5.40 Waste Oil Sumps 28 4

32 32 517 4a.1.5.41 Well Water 69 10 79 79 1,247 4a.1.5 Totals 6,898 66 96 448 106 1,376 8,989 3,659 5,330 23,460 1,076 1,042,678 122,666 4a.1.6 Scaffolding in support of decommissioning 1,358 9

2 10 3

343 1,726 1,726 473 29 23,936 26,134 4a.1 Subtotal Period 4a Activity Costs 355 22,811 7,316 4,077 1,402 25,427 415 17,850 79,653 74,324 5,330 75,688 37,503 3,130 459 505 7,696,903 282,877 4,485 Period 4a Collateral Costs 4a.3.1 Process liquid waste 80 35 160 157 107 539 539 563 33,788 110 4a.3.2 Small tool allowance 254 38 292 263 29 4a.3 Subtotal Period 4a Collateral Costs 80 254 35 160 157 145 831 801 29 563 33,788 110 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 65 16 81 81 4a.4.2 Insurance 448 45 493 493 4a.4.3 Property taxes 668 67 735 661 73 4a.4.4 Health physics supplies 1,633 408 2,041 2,041 4a.4.5 Heavy equipment rental 2,333 350 2,683 2,683 4a.4.6 Disposal of DAW generated 9

4 183 47 243 243 3,279 65,590 15 4a.4.7 Plant energy budget 1,169 175 1,345 1,345 4a.4.8 NRC Fees 603 60 663 663 4a.4.9 Site O&M Costs 167 25 192 192 4a.4.10 Liquid Radwaste Processing Equipment/Services 512 77 589 589 4a.4.11 Security Staff Cost 3,754 563 4,317 4,317 87,143 4a.4.12 DOC Staff Cost 15,423 2,313 17,736 17,736 192,411 4a.4.13 Utility Staff Cost 26,027 3,904 29,931 29,931 348,571 4a.4 Subtotal Period 4a Period-Dependent Costs 65 3,966 9

4 183 48,771 8,051 61,049 60,976 73 3,279 65,590 15 628,126 4a.0 TOTAL PERIOD 4a COST 499 27,031 7,360 4,241 1,402 25,767 49,186 26,046 141,533 136,101 5,432 75,688 41,346 3,130 459 505 7,796,281 283,002 632,610 PERIOD 4b - Site Decontamination Period 4b Direct Decommissioning Activities 4b.1.1 Remove spent fuel racks 990 106 305 93 590 713 2,796 2,796 5,572 499,920 2,174 Disposal of Plant Systems 4b.1.2.1 Chemical & Volume Control 954 59 44 34 243 317 1,652 1,652 1,783 2,322 278,742 15,645 4b.1.2.2 Chilled Water RCA 592 13 25 139 174 943 943 7,293 296,176 9,173 4b.1.2.3 Component Cooling 627 17 31 178 190 1,043 1,043 9,319 378,439 10,075 4b.1.2.4 Electrical 3,669 550 4,220 4,220 66,259 4b.1.2.5 Electrical - Contaminated 1,564 17 32 181 425 2,219 2,219 9,508 386,137 25,754 4b.1.2.6 Electrical - RCA 2,236 39 72 410 635 3,392 3,392 21,460 871,483 37,551 4b.1.2.7 Emergency Diesel Generator 83 13 96 96 1,514 4b.1.2.8 Essential Service Water RCA 303 17 32 179 109 639 639 9,380 380,930 4,955 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 21 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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.1.2.9 Fire Protection 271 41 311 311 4,983 4b.1.2.10 Fire Protection RCA 476 12 22 124 142 776 776 6,516 264,606 7,384 4b.1.2.11 Fuel Handling Bldg Equip Drains 146 7

7 20 23 47 249 249 1,027 221 60,829 2,404 4b.1.2.12 Fuel Handling Bldg Floor Drains 149 7

7 16 25 48 252 252 830 238 54,723 2,441 4b.1.2.13 Fuel Handling Bldg Floor Drains (Unit 1) 103 4

4 13 11 32 168 168 703 109 37,980 1,740 4b.1.2.14 Fuel Hnadling Bldg Equip Drains (Unit 1) 26 1

1 1

4 8

41 41 67 34 5,758 424 4b.1.2.15 Fuel Pool Cooling & Cleanup 199 11 11 24 43 67 355 355 1,275 406 88,160 3,272 4b.1.2.16 Fuel Pool Cooling & Cleanup (Unit 1) 184 10 10 23 38 62 327 327 1,226 361 82,110 3,050 4b.1.2.17 HVAC-Auxiliary Building 485 10 19 108 141 762 762 5,643 229,172 7,876 4b.1.2.18 HVAC-Control Room HVAC 7

1 8

8 127 4b.1.2.19 HVAC-Diesel Generator Room 38 6

44 44 686 4b.1.2.20 HVAC-Laboratory 17 3

20 20 315 4b.1.2.21 HVAC-Machine Shop 16 2

18 18 297 4b.1.2.22 HVAC-Miscellaneous 97 14 111 111 1,769 4b.1.2.23 HVAC-Primary Containment 539 19 36 204 173 970 970 10,679 433,695 8,624 4b.1.2.24 HVAC-Pumphouse 15 2

18 18 275 4b.1.2.25 HVAC-Radwaste 279 6

11 63 82 441 441 3,327 135,102 4,323 4b.1.2.26 HVAC-Turbine Building 163 24 187 187 3,158 4b.1.2.27 Instrument Air Supply 64 10 73 73 1,197 4b.1.2.28 Instrument Air Supply RCA 220 2

3 20 59 304 304 1,035 42,036 3,563 4b.1.2.29 Miscellaneous Drains 66 1

2 12 19 100 100 617 25,043 1,104 4b.1.2.30 Primary Containment Purge 261 10 20 111 86 488 488 5,816 236,197 4,524 4b.1.2.31 Primary Water 722 31 43 187 61 233 1,278 1,278 9,803 667 449,848 12,651 4b.1.2.32 Radioactive Waste Disposal 2,431 164 134 181 652 834 4,396 4,396 9,461 6,530 936,736 39,735 4b.1.2.33 Reactor Bldg Equipment Drains 96 8

7 7

37 36 191 191 356 350 45,614 1,581 4b.1.2.34 Reactor Building Floor Drains 36 2

2 2

7 12 60 60 125 66 11,009 597 4b.1.2.35 Reactor Coolant 147 8

6 4

32 47 243 243 206 299 35,137 2,391 4b.1.2.36 Residual Heat Removal 167 10 12 27 43 59 318 318 1,421 405 94,061 2,834 4b.1.2.37 Safety Injection 760 36 46 172 98 251 1,362 1,362 9,001 979 448,431 13,165 4b.1.2.38 Station Air RCA 51 1

1 6

14 72 72 293 11,919 815 4b.1.2.39 Station Heating RCA 223 4

8 46 64 346 346 2,412 97,961 3,548 4b.1.2.40 Waste Oil Sumps RCA 23 0

1 3

6 33 33 154 6,246 361 4b.1.2.41 Waste Water Treatment 78 12 90 90 1,464 4b.1.2 Totals 18,585 524 648 2,495 1,316 5,047 28,616 23,420 5,196 130,736 12,987 6,424,277 313,605 4b.1.3 Scaffolding in support of decommissioning 2,037 14 3

15 5

515 2,589 2,589 710 44 35,904 39,201 Decontamination of Site Buildings 4b.1.4.1 Reactor 1,748 1,236 177 192 134 604 1,401 5,491 5,491 7,022 8,897 1,144,531 50,361 4b.1.4.2 Auxiliary Building 205 105 8

9 17 18 138 499 499 866 322 66,374 5,241 4b.1.4.3 Radwaste/Service Building 134 42 6

6 6

15 84 293 293 322 278 40,041 2,960 4b.1.4.4 Refueling Water Storage Tank 315 366 4

5 22 6

255 973 973 1,146 87 54,853 11,906 4b.1.4.5 Fuel Handling Building 904 1,006 14 17 59 26 723 2,749 2,749 3,097 411 165,835 33,340 4b.1.4 Totals 3,306 2,755 209 229 238 669 2,600 10,006 10,006 12,453 9,994 1,471,635 103,808 4b.1 Subtotal Period 4b Activity Costs 4,296 23,483 1,052 973 2,748 2,579 8,875 44,007 38,811 5,196 143,899 28,597 8,431,736 458,788 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 33 0

23 89 626 128 899 899 1,689 142,287 1,585 1,280 4b.2 Subtotal Period 4b Additional Costs 33 0

23 89 1,566 410 2,122 1,222 899 1,689 142,287 1,585 7,520 Period 4b Collateral Costs 4b.3.1 Process liquid waste 228 100 460 449 305 1,542 1,542 1,614 96,845 315 4b.3.2 Small tool allowance 431 65 495 495 4b.3.3 Decommissioning Equipment Disposition 119 34 127 40 46 365 365 6,000 373 303,507 88 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 22 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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.3 Subtotal Period 4b Collateral Costs 228 431 220 493 127 489 416 2,403 2,403 6,000 1,988 400,352 403 Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 851 213 1,064 1,064 4b.4.2 Insurance 886 89 975 975 4b.4.3 Property taxes 1,322 132 1,455 1,455 4b.4.4 Health physics supplies 2,835 709 3,543 3,543 4b.4.5 Heavy equipment rental 4,581 687 5,269 5,269 4b.4.6 Disposal of DAW generated 19 7

367 95 488 488 6,584 131,682 30 4b.4.7 Plant energy budget 1,827 274 2,101 2,101 4b.4.8 NRC Fees 1,193 119 1,312 1,312 4b.4.9 Site O&M Costs 331 50 380 380 4b.4.10 Liquid Radwaste Processing Equipment/Services 1,014 152 1,166 1,166 4b.4.11 Security Staff Cost 7,432 1,115 8,546 8,546 172,500 4b.4.12 DOC Staff Cost 29,760 4,464 34,224 34,224 369,840 4b.4.13 Utility Staff Cost 48,980 7,347 56,327 56,327 651,360 4b.4 Subtotal Period 4b Period-Dependent Costs 851 7,416 19 7

367 92,744 15,445 116,850 116,850 6,584 131,682 30 1,193,700 4b.0 TOTAL PERIOD 4b COST 5,375 31,363 1,291 1,496 2,875 3,524 94,311 25,146 165,381 159,286 899 5,196 149,899 38,858 9,106,056 460,806 1,201,220 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 7,473 2,242 9,716 9,716 128,636 3,120 4e.2 Subtotal Period 4e Additional Costs 7,473 2,242 9,716 9,716 128,636 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 376 38 414 414 4e.4.3 Health physics supplies 738 185 923 923 4e.4.4 Disposal of DAW generated 1

0 19 5

25 25 335 6,698 2

4e.4.5 Plant energy budget 139 21 160 160 4e.4.6 NRC Fees 355 35 390 390 4e.4.7 Site O&M Costs 94 14 108 108 4e.4.8 Security Staff Cost 532 80 612 612 11,786 4e.4.9 DOC Staff Cost 3,801 570 4,371 4,371 46,750 4e.4.10 Utility Staff Cost 4,551 683 5,234 5,234 56,964 4e.4 Subtotal Period 4e Period-Dependent Costs 738 1

0 19 9,847 1,630 12,235 12,235 335 6,698 2

115,500 4e.0 TOTAL PERIOD 4e COST 738 1

0 19 18,602 4,087 23,447 23,447 335 6,698 128,638 118,620 PERIOD 4 TOTALS 5,874 59,132 8,652 5,738 4,277 29,310 162,099 55,279 330,361 318,834 899 10,628 225,587 80,539 3,130 459 505 16,909,030 872,445 1,952,450 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 23 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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 6,217 933 7,149 7,149 69,541 5b.1.1.2 Aux Feedwater-Steam Tunnel/Penetr. Area 644 97 741 741 5,185 5b.1.1.3 Auxiliary Building 5,417 813 6,230 6,230 62,063 5b.1.1.4 Berms, Settling Ponds, and Drying Beds 130 19 149 149 1,631 5b.1.1.5 Circulating Water Pumphouse 931 140 1,071 1,071 11,861 5b.1.1.6 Essential Service Cooling Tower 427 64 491 491 5,067 5b.1.1.7 Make-up Demineralizer Area 1,558 234 1,792 1,792 20,770 5b.1.1.8 Miscellaneous Site Structures 1,649 247 1,897 1,897 20,544 5b.1.1.9 Radwaste/Service Building 3,579 537 4,116 4,116 45,688 5b.1.1.10 Receiving Building 166 25 190 190 2,293 5b.1.1.11 Refueling Water Storage Tank 936 140 1,077 1,077 11,688 5b.1.1.12 River Screen House 524 79 603 603 5,869 5b.1.1.13 Security Modifications 975 146 1,121 1,121 8,636 5b.1.1.14 Turbine Building 5,246 787 6,033 6,033 70,347 5b.1.1.15 Turbine Pedestal 1,250 187 1,437 1,437 12,628 5b.1.1.16 Yard Inventory 1,876 281 2,158 2,158 20,610 5b.1.1.17 Fuel Handling Building 2,781 417 3,198 3,198 33,246 5b.1.1 Totals 34,307 5,146 39,453 39,453 407,670 Site Closeout Activities 5b.1.2 BackFill Site 3,308 496 3,804 3,804 9,059 5b.1.3 Grade & landscape site 267 40 307 307 869 5b.1.4 Final report to NRC 79 12 91 91 668 5b.1 Subtotal Period 5b Activity Costs 37,882 79 5,694 43,655 91 43,565 417,598 668 Period 5b Additional Costs 5b.2.1 Hyperbolic Cooling Tower 2,769 415 3,184 3,184 18,598 5b.2.2 ISFSI Demolition and Site Restoration 534 24 84 642 642 6,183 80 5b.2.3 Cofferdam Construction and Teardown 409 61 470 470 3,996 5b.2.4 Concrete Crushing 935 5

141 1,081 1,081 4,554 5b.2 Subtotal Period 5b Additional Costs 4,647 29 701 5,377 642 4,735 33,331 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 429 64 493 493 5b.3 Subtotal Period 5b Collateral Costs 429 64 493 493 Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property taxes 1,239 124 1,363 1,363 5b.4.3 Heavy equipment rental 6,137 921 7,057 7,057 5b.4.4 Plant energy budget 228 34 262 262 5b.4.5 Site O&M Cost 310 46 356 356 5b.4.6 Security Staff Cost 1,582 237 1,819 1,819 34,287 5b.4.7 DOC Staff Cost 11,650 1,748 13,398 13,398 137,043 5b.4.8 Utility Staff Cost 5,559 834 6,392 6,392 67,229 5b.4 Subtotal Period 5b Period-Dependent Costs 6,137 20,567 3,944 30,648 30,648 238,558 5b.0 TOTAL PERIOD 5b COST 49,094 20,675 10,404 80,173 91 642 79,440 450,929 239,306 PERIOD 5 TOTALS 49,094 20,675 10,404 80,173 91 642 79,440 450,929 239,306 TOTAL COST TO DECOMMISSION 12,187 113,757 8,868 6,631 4,277 30,621 423,533 104,806 704,681 500,309 113,664 90,708 225,587 91,625 3,130 459 505 17,255,070 1,414,165 4,750,040 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix D, Page 24 of 24 Table D-2 Byron Nuclear Power Station, Unit 2 Delayed DECON Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:13 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 17.47% CONTINGENCY:

$704,681 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 71% OR:

$500,309 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 16.13% OR:

$113,664 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 12.87% OR:

$90,708 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

95,215 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

505 cubic feet TOTAL SCRAP METAL REMOVED:

74,707 tons TOTAL CRAFT LABOR REQUIREMENTS:

1,414,165 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.

Byron Nuclear Power Station Document E16-1555-013, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 1 of 25 TLG Services, Inc.

APPENDIX E DETAILED COST ANALYSIS SAFSTOR Page Byron Nuclear Power Station, Unit 1...........................................................................E-2 Byron Nuclear Power Station, Unit 2........................................................................E-14

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 2 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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 9,800 1,470 11,270 11,270 1a.2 Subtotal Period 1a Additional Costs 9,800 1,470 11,270 11,270 Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 8,000 1,200 9,200 9,200 1a.3 Subtotal Period 1a Collateral Costs 8,000 1,200 9,200 9,200 Period 1a Period-Dependent Costs 1a.4.1 Insurance 769 77 846 846 1a.4.2 Property taxes 1a.4.3 Health physics supplies 414 104 518 518 1a.4.4 Heavy equipment rental 414 62 476 476 1a.4.5 Disposal of DAW generated 2

1 34 9

45 45 610 12,190 3

1a.4.6 Plant energy budget 921 138 1,059 1,059 1a.4.7 NRC Fees 706 71 776 776 1a.4.8 Emergency Planning Fees 306 31 337 337 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 3 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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 381 57 438 438 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 470 71 541 541 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 828 2

1 34 34,805 5,306 40,975 40,149 826 610 12,190 3

435,664 1a.0 TOTAL PERIOD 1a COST 828 2

1 34 57,238 8,731 66,833 45,537 21,296 610 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 1,924 962 2,886 2,886 33,093 1b.1.1.2 Auxiliary Building 191 95 286 286 3,289 1b.1.1.3 Refueling Water Storage Tank 314 157 471 471 5,322 1b.1.1 Totals 2,429 1,214 3,643 3,643 41,705 1b.1 Subtotal Period 1b Activity Costs 2,429 1,214 3,643 3,643 41,705 Period 1b Collateral Costs 1b.3.1 Decon equipment 797 120 917 917 1b.3.2 Process liquid waste 184 78 357 349 241 1,210 1,210 1,255 75,307 245 1b.3.3 Small tool allowance 39 6

44 44 1b.3.4 Spent Fuel Capital and Transfer 2,000 300 2,300 2,300 1b.3 Subtotal Period 1b Collateral Costs 982 39 78 357 349 2,000 666 4,472 2,172 2,300 1,255 75,307 245 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 561 140 702 702 1b.4.2 Insurance 192 19 211 211 1b.4.3 Property taxes 2,452 245 2,697 2,697 1b.4.4 Health physics supplies 264 66 331 331 1b.4.5 Heavy equipment rental 103 15 119 119 1b.4.6 Disposal of DAW generated 1

1 29 7

38 38 517 10,338 2

1b.4.7 Plant energy budget 229 34 264 264 1b.4.8 NRC Fees 176 18 194 194 1b.4.9 Emergency Planning Fees 76 8

84 84 1b.4.10 Site O&M Costs 31 5

36 36 1b.4.11 Spent Fuel Pool O&M 95 14 109 109 1b.4.12 ISFSI Operating Costs 11 2

13 13 1b.4.13 Security Staff Cost 117 18 135 135 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 561 368 1

1 29 11,129 1,754 13,842 13,637 206 517 10,338 2

108,618 1b.0 TOTAL PERIOD 1b COST 3,972 406 79 358 378 13,129 3,635 21,957 19,451 2,506 1,772 85,645 41,952 108,618 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 431 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 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 4 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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 Subtotal Period 1c Activity Costs 473 802 301 1,575 1,575 17,116 583 Period 1c Collateral Costs 1c.3.1 Process liquid waste 150 64 292 285 197 988 988 1,024 61,469 200 1c.3.2 Small tool allowance 4

1 4

4 1c.3.3 Spent Fuel Capital and Transfer 2,000 300 2,300 2,300 1c.3 Subtotal Period 1c Collateral Costs 150 4

64 292 285 2,000 497 3,292 992 2,300 1,024 61,469 200 Period 1c Period-Dependent Costs 1c.4.1 Insurance 192 19 211 211 1c.4.2 Property taxes 2,452 245 2,697 2,697 1c.4.3 Health physics supplies 145 36 181 181 1c.4.4 Heavy equipment rental 103 15 119 119 1c.4.5 Disposal of DAW generated 0

0 6

2 8

8 107 2,132 0

1c.4.6 Plant energy budget 229 34 264 264 1c.4.7 NRC Fees 176 18 194 194 1c.4.8 Emergency Planning Fees 76 8

84 84 1c.4.9 Site O&M Costs 31 5

36 36 1c.4.10 Spent Fuel Pool O&M 95 14 109 109 1c.4.11 ISFSI Operating Costs 11 2

13 13 1c.4.12 Security Staff Cost 117 18 135 135 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 248 0

0 6

5,526 737 6,518 6,312 206 107 2,132 0

30,098 1c.0 TOTAL PERIOD 1c COST 150 724 64 292 291 8,328 1,536 11,385 8,879 2,506 1,131 63,601 17,316 30,681 PERIOD 1 TOTALS 4,122 1,958 145 650 703 78,694 13,901 100,175 73,868 26,308 3,513 161,436 59,271 610,852 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 17 3

20 20 2a.1.5 Maintenance supplies 503 126 629 629 2a.1 Subtotal Period 2a Activity Costs 520 128 649 649 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 30,000 4,500 34,500 34,500 2a.3 Subtotal Period 2a Collateral Costs 30,000 4,500 34,500 34,500 Period 2a Period-Dependent Costs 2a.4.1 Insurance 1,341 134 1,475 1,291 183 2a.4.2 Property taxes 11,097 1,110 12,207 2,200 10,007 2a.4.3 Health physics supplies 324 81 405 405 2a.4.4 Disposal of DAW generated 4

2 86 22 114 114 1,540 30,799 7

2a.4.5 Plant energy budget 737 111 847 424 424 2a.4.6 NRC Fees 807 81 887 887 2a.4.7 Emergency Planning Fees 400 40 440 440 2a.4.8 Site O&M Costs 500 75 575 575 2a.4.9 Spent Fuel Pool O&M 1,526 229 1,755 1,755 2a.4.10 ISFSI Operating Costs 176 26 202 202 2a.4.11 Security Staff Cost 1,527 229 1,756 1,756 110,285 2a.4.12 Utility Staff Cost 10,654 1,598 12,252 4,321 7,930 136,750 2a.4 Subtotal Period 2a Period-Dependent Costs 324 4

2 86 28,764 3,735 32,915 10,218 22,698 1,540 30,799 7

247,034 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 5 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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 2a.0 TOTAL PERIOD 2a COST 324 4

2 86 59,284 8,364 68,064 10,866 57,198 1,540 30,799 7

247,034 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 54 8

63 63 2b.1.5 Maintenance supplies 1,593 398 1,992 1,992 2b.1 Subtotal Period 2b Activity Costs 1,648 407 2,054 2,054 Period 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 7,875 1,181 9,056 9,056 2b.3 Subtotal Period 2b Collateral Costs 7,875 1,181 9,056 9,056 Period 2b Period-Dependent Costs 2b.4.1 Insurance 3,840 384 4,224 4,090 134 2b.4.2 Property taxes 6,334 633 6,968 6,968 2b.4.3 Health physics supplies 964 241 1,205 1,205 2b.4.4 Disposal of DAW generated 14 5

266 69 353 353 4,765 95,304 22 2b.4.5 Plant energy budget 1,167 175 1,342 1,342 2b.4.6 NRC Fees 2,554 255 2,810 2,810 2b.4.7 Emergency Planning Fees 1,267 127 1,394 1,394 2b.4.8 Site O&M Costs 1,583 238 1,821 1,821 2b.4.9 ISFSI Operating Costs 557 84 641 641 2b.4.10 Security Staff Cost 16,113 2,417 18,530 11,529 7,000 356,940 2b.4.11 Utility Staff Cost 17,249 2,587 19,837 13,686 6,151 239,282 2b.4 Subtotal Period 2b Period-Dependent Costs 964 14 5

266 50,665 7,210 59,123 43,804 15,320 4,765 95,304 22 596,222 2b.0 TOTAL PERIOD 2b COST 964 14 5

266 60,188 8,797 70,234 45,858 24,376 4,765 95,304 22 596,222 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 150 22 172 172 2c.1.5 Maintenance supplies 4,381 1,095 5,476 5,476 2c.1 Subtotal Period 2c Activity Costs 4,530 1,118 5,648 5,648 Period 2c Period-Dependent Costs 2c.4.1 Insurance 10,221 1,022 11,243 11,243 2c.4.2 Property taxes 17,413 1,741 19,154 19,154 2c.4.3 Health physics supplies 2,589 647 3,236 3,236 2c.4.4 Disposal of DAW generated 37 14 725 187 963 963 12,988 259,756 60 2c.4.5 Plant energy budget 3,208 481 3,689 3,689 2c.4.6 NRC Fees 6,359 636 6,995 6,995 2c.4.7 Site O&M Costs 4,353 653 5,006 5,006 2c.4.8 Security Staff Cost 27,561 4,134 31,695 31,695 545,143 2c.4.9 Utility Staff Cost 32,716 4,907 37,623 37,623 463,735 2c.4 Subtotal Period 2c Period-Dependent Costs 2,589 37 14 725 101,831 14,409 119,606 119,606 12,988 259,756 60 1,008,878 2c.0 TOTAL PERIOD 2c COST 2,589 37 14 725 106,361 15,527 125,253 125,253 12,988 259,756 60 1,008,878 PERIOD 2 TOTALS 3,877 55 21 1,077 225,834 32,688 263,552 181,978 81,574 19,293 385,859 89 1,852,134 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 6 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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 - 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 Biological shield 59 9

68 68 500 3a.1.11.6 Steam generators 368 55 423 423 3,120 3a.1.11.7 Reinforced concrete 189 28 217 109 109 1,600 3a.1.11.8 Main Turbine 47 7

54 54 400 3a.1.11.9 Main Condensers 47 7

54 54 400 3a.1.11.10 Plant structures & buildings 368 55 423 212 212 3,120 3a.1.11.11 Waste management 543 81 624 624 4,600 3a.1.11.12 Facility & site closeout 106 16 122 61 61 900 3a.1.11 Total 4,694 704 5,398 4,752 646 39,777 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 13,580 2,037 15,617 14,970 646 72,703 Period 3a Period-Dependent Costs 3a.4.1 Insurance 293 29 323 323 3a.4.2 Property taxes 500 50 550 550 3a.4.3 Health physics supplies 362 91 453 453 3a.4.4 Heavy equipment rental 414 62 476 476 3a.4.5 Disposal of DAW generated 1

1 29 7

38 38 514 10,287 2

3a.4.6 Plant energy budget 921 138 1,059 1,059 3a.4.7 NRC Fees 249 25 274 274 3a.4.8 Site O&M Costs 125 19 144 144 3a.4.9 Security Staff Cost 2,882 432 3,315 3,315 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 776 1

1 29 24,263 3,747 28,816 28,816 514 10,287 2

323,807 3a.0 TOTAL PERIOD 3a COST 776 1

1 29 37,842 5,784 44,433 43,787 646 514 10,287 2

396,510 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 7 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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 - 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 295 44 339 339 2,500 3b.1.1.3 Remaining buildings 159 24 183 46 137 1,350 3b.1.1.4 CRD cooling assembly 118 18 136 136 1,000 3b.1.1.5 CRD housings & ICI tubes 118 18 136 136 1,000 3b.1.1.6 Incore instrumentation 118 18 136 136 1,000 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 Missile shields 53 8

61 61 450 3b.1.1.10 Biological shield 142 21 163 163 1,200 3b.1.1.11 Steam generators 543 81 624 624 4,600 3b.1.1.12 Reinforced concrete 118 18 136 68 68 1,000 3b.1.1.13 Main Turbine 184 28 212 212 1,560 3b.1.1.14 Main Condensers 184 28 212 212 1,560 3b.1.1.15 Auxiliary building 322 48 370 333 37 2,730 3b.1.1.16 Reactor building 322 48 370 333 37 2,730 3b.1.1 Total 3,805 571 4,376 3,527 848 32,243 3b.1 Subtotal Period 3b Activity Costs 3,805 571 4,376 3,527 848 32,243 Period 3b Additional Costs 3b.2.1 Site Characterization 6,341 1,902 8,243 8,243 30,500 10,852 3b.2 Subtotal Period 3b Additional Costs 6,341 1,902 8,243 8,243 30,500 10,852 Period 3b Collateral Costs 3b.3.1 Decon equipment 797 120 917 917 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 797 1,100 1,130 454 3,482 3,482 Period 3b Period-Dependent Costs 3b.4.1 Decon supplies 24 6

31 31 3b.4.2 Insurance 168 17 185 185 3b.4.3 Property taxes 251 25 276 276 3b.4.4 Health physics supplies 200 50 250 250 3b.4.5 Heavy equipment rental 207 31 238 238 3b.4.6 Disposal of DAW generated 1

0 16 4

22 22 292 5,834 1

3b.4.7 Plant energy budget 462 69 531 531 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 1,445 217 1,662 1,662 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 24 408 1

0 16 16,967 2,609 20,025 20,025 292 5,834 1

220,907 3b.0 TOTAL PERIOD 3b COST 822 1,508 1

0 16 28,242 5,536 36,125 35,277 848 292 5,834 30,501 264,002 PERIOD 3 TOTALS 822 2,283 2

1 45 66,084 11,321 80,558 79,063 1,495 806 16,121 30,504 660,512 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 8 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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 - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Reactor Coolant Piping 40 138 31 20 44 165 109 547 547 838 838 194,479 3,153 4a.1.1.2 Pressurizer Relief Tank 7

26 6

4 9

30 20 102 102 165 165 36,553 596 4a.1.1.3 Reactor Coolant Pumps & Motors 25 94 53 168 1,272 384 1,996 1,996 4,796 780,540 2,726 80 4a.1.1.4 Pressurizer 11 59 345 94 412 172 1,093 1,093 3,033 252,826 1,527 750 4a.1.1.5 Steam Generators 85 4,096 2,098 2,506 667 4,349 2,839 16,640 16,640 45,513 17,359 3,811,289 20,508 1,500 4a.1.1.6 Retired Steam Generator Units 1,426 2,644 580 3,416 1,480 9,546 9,546 39,289 14,064 3,041,432 10,800 1,500 4a.1.1.7 CRDMs/ICIs/Service Structure Removal 35 89 191 32 13 63 81 505 505 753 2,947 81,666 2,134 4a.1.1.8 Reactor Vessel Internals 67 2,001 3,441 515 3,709 203 4,409 14,346 14,346 2,211 376 470 325,254 23,067 1,055 4a.1.1.9 Vessel & Internals GTCC Disposal 11,665 1,750 13,414 13,414 505 104,146 4a.1.1.10 Reactor Vessel 81 3,970 1,280 655 2,976 203 5,020 14,184 14,184 6,672 2,254 979,179 23,067 1,055 4a.1.1 Totals 351 10,473 8,871 6,636 1,312 28,058 406 16,264 72,372 72,372 86,558 52,085 2,629 470 505 9,607,363 87,577 5,939 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 510 256 32 214 190 1,201 1,201 5,355 455,213 9,016 4a.1.3 Main Condensers 1,042 133 27 150 300 1,653 1,653 7,111 320,000 18,250 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor 1,076 161 1,237 1,237 12,130 4a.1.4.2 Auxiliary Building 594 89 683 683 6,810 4a.1.4.3 Refueling Water Storage Tank 104 16 120 120 1,299 4a.1.4 Totals 1,773 266 2,039 2,039 20,238 Disposal of Plant Systems 4a.1.5.1 Auxiliary Feedwater 69 10 79 79 1,244 4a.1.5.2 Auxiliary Steam 61 9

71 71 1,126 4a.1.5.3 Auxiliary Steam RCA 122 2

3 16 34 176 176 835 33,900 1,935 4a.1.5.4 Boric Acid Processing 444 32 31 86 99 157 850 850 4,531 1,193 268,274 7,890 4a.1.5.5 CO2 & H2 23 3

26 26 419 4a.1.5.6 CO2 & H2 RCA 35 0

1 3

9 48 48 164 6,658 572 4a.1.5.7 Chemical Feed 51 8

58 58 934 4a.1.5.8 Chilled Water 63 9

72 72 1,142 4a.1.5.9 Circulating Water 279 42 321 321 5,150 4a.1.5.10 Condensate 331 50 381 381 6,023 4a.1.5.11 Condensate Booster 299 45 344 344 5,428 4a.1.5.12 Condensate Cleanup 58 9

67 67 1,060 4a.1.5.13 Containment Spray 233 7

12 69 71 392 392 3,629 147,367 3,729 4a.1.5.14 Diesel Fuel Oil 90 13 103 103 1,615 4a.1.5.15 Essential Service Water 208 31 239 239 3,837 4a.1.5.16 Extraction Steam 167 25 192 192 3,089 4a.1.5.17 Feedwater 278 42 320 320 5,142 4a.1.5.18 Feedwater Drains 668 100 768 768 12,366 4a.1.5.19 Gland Steam 50 8

58 58 932 4a.1.5.20 Gland Water 44 7

51 51 828 4a.1.5.21 Main Steam 284 43 326 326 5,216 4a.1.5.22 Main Steam RCA 46 1

3 15 14 79 79 760 30,853 739 4a.1.5.23 Nitrogen 3

0 0

1 1

5 5

52 2,102 49 4a.1.5.24 Non-Essential Service Water 157 23 180 180 2,916 4a.1.5.25 Non-Essential Service Water RCA 86 3

5 28 27 148 148 1,462 59,354 1,295 4a.1.5.26 Off Gas 512 10 19 106 148 795 795 5,572 226,266 8,494 4a.1.5.27 Process Radiation Monitoring 37 0

0 2

10 49 49 113 4,587 666 4a.1.5.28 Process Sampling 107 1

2 12 29 151 151 616 25,019 1,927 4a.1.5.29 Station Air 27 4

31 31 498 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 9 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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.1.5.30 Station Heating 96 14 111 111 1,771 4a.1.5.31 Switchgear Heat Removal 8

1 9

9 139 4a.1.5.32 Turbine Bldg Equip Drains 1

0 1

1 17 4a.1.5.33 Turbine Generator 50 8

58 58 901 4a.1.5.34 Turbine Oil 77 12 88 88 1,399 4a.1.5.35 Waste Oil Sumps 26 4

30 30 483 4a.1.5 Totals 5,090 56 75 338 99 1,019 6,678 2,694 3,984 17,732 1,193 804,381 90,969 4a.1.6 Scaffolding in support of decommissioning 941 6

1 6

2 237 1,194 1,194 306 19 15,459 18,101 4a.1 Subtotal Period 4a Activity Costs 351 19,829 9,322 6,771 2,022 28,160 406 18,276 85,137 81,153 3,984 117,063 53,297 2,629 470 505 11,202,420 244,150 5,939 Period 4a Collateral Costs 4a.3.1 Process liquid waste 35 17 79 77 50 258 258 276 16,564 54 4a.3.2 Small tool allowance 209 31 241 217 24 4a.3 Subtotal Period 4a Collateral Costs 35 209 17 79 77 82 498 474 24 276 16,564 54 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 63 16 79 79 4a.4.2 Insurance 437 44 480 480 4a.4.3 Property taxes 652 65 717 645 72 4a.4.4 Health physics supplies 1,465 366 1,832 1,832 4a.4.5 Heavy equipment rental 2,276 341 2,617 2,617 4a.4.6 Disposal of DAW generated 9

3 175 45 232 232 3,134 62,685 14 4a.4.7 Plant energy budget 1,140 171 1,311 1,311 4a.4.8 NRC Fees 858 86 944 944 4a.4.9 Site O&M Costs 163 24 187 187 4a.4.10 Liquid Radwaste Processing Equipment/Services 500 75 574 574 4a.4.11 Security Staff Cost 2,217 333 2,550 2,550 57,773 4a.4.12 DOC Staff Cost 14,773 2,216 16,989 16,989 185,558 4a.4.13 Utility Staff Cost 23,931 3,590 27,521 27,521 326,264 4a.4 Subtotal Period 4a Period-Dependent Costs 63 3,741 9

3 175 44,671 7,372 56,035 55,963 72 3,134 62,685 14 569,595 4a.0 TOTAL PERIOD 4a COST 449 23,780 9,348 6,853 2,022 28,411 45,077 25,730 141,670 137,591 4,079 117,063 56,707 2,629 470 505 11,281,670 244,219 575,535 PERIOD 4b - Site Decontamination Disposal of Plant Systems 4b.1.2.1 Chemical & Volume Control 1,000 62 46 33 255 332 1,728 1,728 1,744 2,431 287,102 16,313 4b.1.2.2 Chilled Water RCA 282 8

16 90 87 484 484 4,716 191,536 4,732 4b.1.2.3 Component Cooling RCA 604 15 29 164 181 994 994 8,589 348,801 9,675 4b.1.2.4 Electrical 2,682 402 3,085 3,085 48,490 4b.1.2.5 Electrical - Contaminated 1,028 12 23 128 281 1,471 1,471 6,722 272,965 17,115 4b.1.2.6 Electrical - RCA 1,706 32 59 335 489 2,621 2,621 17,555 712,922 29,098 4b.1.2.7 Emergency Diesel Generator 113 17 130 130 2,066 4b.1.2.8 Essential Service Water RCA 271 9

17 99 86 482 482 5,177 210,230 4,418 4b.1.2.9 Fire Protection 108 16 124 124 1,984 4b.1.2.10 Fire Protection RCA 168 2

4 20 46 240 240 1,069 43,397 2,628 4b.1.2.11 HVAC-Auxiliary Building 445 9

17 96 129 697 697 5,054 205,243 7,162 4b.1.2.12 HVAC-Diesel Generator Room 38 6

44 44 682 4b.1.2.13 HVAC-Miscellaneous 37 5

42 42 656 4b.1.2.14 HVAC-Primary Containment 539 19 36 204 173 970 970 10,679 433,695 8,624 4b.1.2.15 HVAC-Turbine Building 164 25 188 188 3,177 4b.1.2.16 Instrument Air Supply 41 6

47 47 760 4b.1.2.17 Instrument Air Supply RCA 67 1

1 7

18 94 94 366 14,869 1,073 4b.1.2.18 Miscellaneous Drains 35 1

1 6

10 52 52 312 12,666 584 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 10 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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 Primary Containment Purge 247 10 20 112 82 471 471 5,850 237,590 4,312 4b.1.2.20 Primary Water 54 1

1 3

4 15 79 79 143 42 9,560 915 4b.1.2.21 Radioactive Waste Disposal 817 45 39 81 154 265 1,400 1,400 4,235 1,622 302,491 14,169 4b.1.2.22 Reactor Building Equipment Drains 88 7

5 3

29 31 164 164 183 277 32,048 1,435 4b.1.2.23 Reactor Building Floor Drains 41 2

2 2

8 13 68 68 130 74 11,914 678 4b.1.2.24 Reactor Coolant 155 9

6 4

34 50 257 257 208 324 37,451 2,506 4b.1.2.25 Residual Heat Removal 172 11 12 28 44 61 328 328 1,453 418 96,526 2,924 4b.1.2.26 Safety Injection 783 37 47 175 103 259 1,404 1,404 9,181 1,028 460,142 13,528 4b.1.2.27 Station Air RCA 33 0

1 3

9 46 46 175 7,089 521 4b.1.2.28 Station Heating RCA 109 2

4 24 32 171 171 1,256 51,005 1,759 4b.1.2.29 Waste Oil Sumps RCA 7

0 0

1 2

10 10 52 2,098 92 4b.1.2 Totals 11,832 293 386 1,619 632 3,128 17,891 14,231 3,660 84,848 6,216 3,981,341 202,075 4b.1.3 Scaffolding in support of decommissioning 1,411 9

2 10 3

356 1,791 1,791 458 29 23,188 27,151 Decontamination of Site Buildings 4b.1.4.1 Reactor 1,748 1,236 171 191 134 455 1,363 5,297 5,297 7,022 8,433 1,122,399 50,351 4b.1.4.2 Auxiliary Building 175 93 6

7 17 13 118 428 428 866 228 57,032 4,547 4b.1.4.3 Refueling Water Storage Tank 315 366 4

5 22 6

255 973 973 1,146 87 54,853 11,906 4b.1.4 Totals 2,238 1,695 181 203 172 474 1,736 6,698 6,698 9,034 8,748 1,234,285 66,804 4b.1 Subtotal Period 4b Activity Costs 2,238 14,938 483 591 1,802 1,109 5,220 26,381 22,720 3,660 94,341 14,993 5,238,813 296,030 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 38 1

23 90 727 144 1,022 1,022 1,705 142,596 2,873 1,280 4b.2.3 Soil Remediation 17 0

52 143 48 260 260 2,730 207,480 99 4b.2 Subtotal Period 4b Additional Costs 54 1

75 233 1,667 474 2,504 1,482 1,022 4,435 350,076 2,972 7,520 Period 4b Collateral Costs 4b.3.1 Process liquid waste 42 21 96 94 61 313 313 336 20,172 66 4b.3.2 Small tool allowance 268 40 309 309 4b.3.3 Decommissioning Equipment Disposition 119 34 127 40 46 365 365 6,000 373 303,507 88 4b.3 Subtotal Period 4b Collateral Costs 42 268 140 129 127 133 147 987 987 6,000 710 323,679 154 Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 657 164 821 821 4b.4.2 Insurance 743 74 818 818 4b.4.3 Property taxes 1,109 111 1,220 1,220 4b.4.4 Health physics supplies 1,963 491 2,454 2,454 4b.4.5 Heavy equipment rental 3,841 576 4,418 4,418 4b.4.6 Disposal of DAW generated 12 5

241 62 320 320 4,311 86,211 20 4b.4.7 Plant energy budget 1,532 230 1,762 1,762 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 977 147 1,123 1,123 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 657 5,804 12 5

241 51,055 8,786 66,560 66,560 4,311 86,211 20 631,800 4b.0 TOTAL PERIOD 4b COST 2,937 21,065 637 800 1,929 1,716 52,722 14,627 96,432 91,750 1,022 3,660 100,341 24,448 5,998,779 299,176 639,320 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 11 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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 4d - Delay before License Termination Period 4d Period-Dependent Costs 4d.4.1 Insurance 4d.4.2 Property taxes 616 62 678 678 4d.4.3 Health physics supplies 92 23 115 115 4d.4.4 Disposal of DAW generated 0

0 7

2 9

9 123 2,458 1

4d.4.5 Plant energy budget 4d.4.6 NRC Fees 225 22 247 247 4d.4.7 Site O&M Costs 154 23 177 177 4d.4.8 Utility Staff Cost 1,267 190 1,457 1,457 18,000 4d.4 Subtotal Period 4d Period-Dependent Costs 92 0

0 7

2,262 322 2,683 2,683 123 2,458 1

18,000 4d.0 TOTAL PERIOD 4d COST 92 0

0 7

2,262 322 2,683 2,683 123 2,458 1

18,000 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 5,485 1,646 7,131 7,131 91,793 3,120 4e.2 Subtotal Period 4e Additional Costs 5,485 1,646 7,131 7,131 91,793 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 376 38 414 414 4e.4.3 Health physics supplies 597 149 746 746 4e.4.4 Disposal of DAW generated 1

0 19 5

25 25 335 6,698 2

4e.4.5 Plant energy budget 139 21 160 160 4e.4.6 NRC Fees 532 53 585 585 4e.4.7 Site O&M Costs 94 14 108 108 4e.4.8 Security Staff Cost 544 82 625 625 11,786 4e.4.9 DOC Staff Cost 3,801 570 4,371 4,371 46,750 4e.4.10 Utility Staff Cost 4,551 683 5,234 5,234 56,964 4e.4 Subtotal Period 4e Period-Dependent Costs 597 1

0 19 10,036 1,614 12,267 12,267 335 6,698 2

115,500 4e.0 TOTAL PERIOD 4e COST 597 1

0 19 16,803 3,474 20,894 20,894 335 6,698 91,795 118,620 PERIOD 4 TOTALS 3,386 45,533 9,986 7,654 3,950 30,152 116,864 44,153 261,679 252,917 1,022 7,740 217,404 81,613 2,629 470 505 17,289,600 635,189 1,351,475 PERIOD 5b - Site Restoration Period 5b Direct Decommissioning Activities Demolition of Remaining Site Buildings 5b.1.1.1 Reactor 6,217 933 7,149 7,149 69,541 5b.1.1.2 Auxiliary Building 5,342 801 6,143 6,143 61,287 5b.1.1.3 Old Steam Generator Storage Facility 417 63 479 479 4,868 5b.1.1.4 Refueling Water Storage Tank 936 140 1,077 1,077 11,688 5b.1.1.5 Turbine Building 5,246 787 6,033 6,033 70,347 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 12 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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 Demolition of Remaining Site Buildings (continued) 5b.1.1.6 Turbine Pedestal 1,250 187 1,437 1,437 12,628 5b.1.1 Totals 19,408 2,911 22,319 22,319 230,359 Site Closeout Activities 5b.1.2 Grade & landscape site 267 40 307 307 869 5b.1.3 Final report to NRC 184 28 212 212 1,560 5b.1 Subtotal Period 5b Activity Costs 19,675 184 2,979 22,838 212 22,626 231,228 1,560 Period 5b Additional Costs 5b.2.1 Hyperbolic Cooling Tower 3,461 519 3,980 3,980 18,598 5b.2.2 ISFSI Demolition and Site Restoration 1,227 24 188 1,439 1,439 17,085 80 5b.2.3 Concrete Crushing 574 3

87 664 664 2,798 5b.2 Subtotal Period 5b Additional Costs 5,262 27 793 6,083 1,439 4,644 38,481 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 257 39 295 295 5b.3 Subtotal Period 5b Collateral Costs 257 39 295 295 Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property taxes 1,239 124 1,363 1,363 5b.4.3 Heavy equipment rental 6,137 921 7,057 7,057 5b.4.4 Plant energy budget 228 34 262 262 5b.4.5 Site O&M Cost 310 46 356 356 5b.4.6 Security Staff Cost 1,616 242 1,859 1,859 34,287 5b.4.7 DOC Staff Cost 11,650 1,748 13,398 13,398 137,043 5b.4.8 Utility Staff Cost 5,559 834 6,392 6,392 67,229 5b.4 Subtotal Period 5b Period-Dependent Costs 6,137 20,602 3,949 30,687 30,687 238,558 5b.0 TOTAL PERIOD 5b COST 31,330 20,813 7,760 59,903 212 1,439 58,252 269,709 240,198 PERIOD 5 TOTALS 31,330 20,813 7,760 59,903 212 1,439 58,252 269,709 240,198 TOTAL COST TO DECOMMISSION 8,331 84,983 10,189 8,326 3,950 31,977 508,289 109,822 765,867 588,038 110,342 67,487 217,404 105,225 2,629 470 505 17,853,020 994,761 4,715,171 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 13 of 25 Table E-1 Byron Nuclear Power Station, Unit 1 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:37 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 16.74% CONTINGENCY:

$765,867 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 76.78% OR:

$588,038 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 14.41% OR:

$110,342 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 8.81% OR:

$67,487 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

108,323 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

505 cubic feet TOTAL SCRAP METAL REMOVED:

58,942 tons TOTAL CRAFT LABOR REQUIREMENTS:

994,761 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.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 14 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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 66 10 76 76 556 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 101 15 116 116 856 1a.1.8 Review plant dwgs & specs.

66 10 76 76 556 1a.1.9 Perform detailed rad survey a

1a.1.10 Estimate by-product inventory 51 8

58 58 428 1a.1.11 End product description 51 8

58 58 428 1a.1.12 Detailed by-product inventory 76 11 87 87 642 1a.1.13 Define major work sequence 51 8

58 58 428 1a.1.14 Perform SER and EA 157 23 180 180 1,327 1a.1.15 Perform Site-Specific Cost Study 253 38 290 290 2,140 Activity Specifications 1a.1.16.1 Prepare plant and facilities for SAFSTOR 249 37 286 286 2,106 1a.1.16.2 Plant systems 210 32 242 242 1,783 1a.1.16.3 Plant structures and buildings 158 24 181 181 1,335 1a.1.16.4 Waste management 101 15 116 116 856 1a.1.16.5 Facility and site dormancy 101 15 116 116 856 1a.1.16 Total 819 123 941 941 6,936 Detailed Work Procedures 1a.1.17.1 Plant systems 60 9

69 69 506 1a.1.17.2 Facility closeout & dormancy 61 9

70 70 514 1a.1.17 Total 120 18 138 138 1,020 1a.1.18 Procure vacuum drying system 5

1 6

6 43 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 2,211 391 2,602 2,602 15,361 Period 1a Additional Costs 1a.2.1 ISFSI Expansion 9,800 1,470 11,270 11,270 1a.2 Subtotal Period 1a Additional Costs 9,800 1,470 11,270 11,270 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 769 77 846 846 1a.4.2 Property taxes 1a.4.3 Health physics supplies 414 104 518 518 1a.4.4 Heavy equipment rental 414 62 476 476 1a.4.5 Disposal of DAW generated 2

1 34 9

45 45 610 12,190 3

1a.4.6 Plant energy budget 921 138 1,059 1,059 1a.4.7 NRC Fees 471 47 518 518 1a.4.8 Emergency Planning Fees 306 31 337 337 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 15 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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 381 57 438 438 1a.4.11 ISFSI Operating Costs 44 7

51 51 1a.4.12 Security Staff Cost 6,424 964 7,387 7,387 157,471 1a.4.13 Utility Staff Cost 31,082 4,662 35,745 35,745 423,400 1a.4 Subtotal Period 1a Period-Dependent Costs 828 2

1 34 40,523 6,176 47,563 46,738 826 610 12,190 3

580,871 1a.0 TOTAL PERIOD 1a COST 828 2

1 34 61,534 9,387 71,785 49,339 22,446 610 12,190 3

596,232 PERIOD 1b - SAFSTOR Limited DECON Activities Period 1b Direct Decommissioning Activities Decontamination of Site Buildings 1b.1.1.1 Reactor 1,924 962 2,886 2,886 33,093 1b.1.1.2 Auxiliary Building 222 111 333 333 3,830 1b.1.1.3 Radwaste/Service Building 145 72 217 217 2,506 1b.1.1.4 Refueling Water Storage Tank 314 157 471 471 5,322 1b.1.1.5 Fuel Handling Building 899 449 1,348 1,348 15,238 1b.1.1 Totals 3,504 1,752 5,255 5,255 59,990 1b.1 Subtotal Period 1b Activity Costs 3,504 1,752 5,255 5,255 59,990 Period 1b Collateral Costs 1b.3.1 Decon equipment 797 120 917 917 1b.3.2 Process liquid waste 205 87 398 389 268 1,347 1,347 1,398 83,853 272 1b.3.3 Small tool allowance 56 8

65 65 1b.3.4 Spent Fuel Capital and Transfer 2,000 300 2,300 2,300 1b.3 Subtotal Period 1b Collateral Costs 1,003 56 87 398 389 2,000 696 4,629 2,329 2,300 1,398 83,853 272 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 734 184 918 918 1b.4.2 Insurance 192 19 211 211 1b.4.3 Property taxes 2,452 245 2,697 2,697 1b.4.4 Health physics supplies 335 84 418 418 1b.4.5 Heavy equipment rental 103 15 119 119 1b.4.6 Disposal of DAW generated 2

1 33 8

43 43 585 11,700 3

1b.4.7 Plant energy budget 229 34 264 264 1b.4.8 NRC Fees 117 12 129 129 1b.4.9 Emergency Planning Fees 76 8

84 84 1b.4.10 Site O&M Costs 31 5

36 36 1b.4.11 Spent Fuel Pool O&M 95 14 109 109 1b.4.12 ISFSI Operating Costs 11 2

13 13 1b.4.13 Security Staff Cost 1,602 240 1,842 1,842 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 734 438 2

1 33 12,555 2,032 15,794 15,588 206 585 11,700 3

144,820 1b.0 TOTAL PERIOD 1b COST 5,240 494 89 399 422 14,555 4,481 25,678 23,173 2,506 1,983 95,552 60,265 144,820 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 431 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 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 16 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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.1.4 Secure building accesses a

1c.1.5 Prepare & submit interim report 29 4

34 34 250 1c.1 Subtotal Period 1c Activity Costs 473 762 295 1,530 1,530 17,116 250 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 251 106 487 476 328 1,649 1,649 1,710 102,618 333 1c.3.2 Small tool allowance 4

1 4

4 1c.3.3 Spent Fuel Capital and Transfer 2,000 300 2,300 2,300 1c.3 Subtotal Period 1c Collateral Costs 251 4

106 487 476 2,000 629 3,953 1,653 2,300 1,710 102,618 333 Period 1c Period-Dependent Costs 1c.4.1 Insurance 192 19 211 211 1c.4.2 Property taxes 2,452 245 2,697 2,697 1c.4.3 Health physics supplies 145 36 182 182 1c.4.4 Heavy equipment rental 103 15 119 119 1c.4.5 Disposal of DAW generated 0

0 6

2 8

8 107 2,132 0

1c.4.6 Plant energy budget 229 34 264 264 1c.4.7 NRC Fees 117 12 129 129 1c.4.8 Emergency Planning Fees 76 8

84 84 1c.4.9 Site O&M Costs 31 5

36 36 1c.4.10 Spent Fuel Pool O&M 95 14 109 109 1c.4.11 ISFSI Operating Costs 11 2

13 13 1c.4.12 Security Staff Cost 1,602 240 1,842 1,842 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 249 0

0 6

6,952 954 8,161 7,955 206 107 2,132 0

66,300 1c.0 TOTAL PERIOD 1c COST 251 725 107 487 482 19,404 3,332 24,787 22,281 2,506 1,817 104,751 17,450 66,550 PERIOD 1 TOTALS 5,491 2,047 197 886 938 95,492 17,199 122,251 94,793 27,458 4,409 212,493 77,717 807,602 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 58 9

67 67 2a.1.5 Maintenance supplies 503 126 629 629 2a.1 Subtotal Period 2a Activity Costs 561 134 696 696 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 37,000 5,550 42,550 42,550 2a.3 Subtotal Period 2a Collateral Costs 37,000 5,550 42,550 42,550 Period 2a Period-Dependent Costs 2a.4.1 Insurance 1,341 134 1,475 1,291 183 2a.4.2 Property taxes 11,097 1,110 12,207 2,200 10,007 2a.4.3 Health physics supplies 333 83 416 416 2a.4.4 Disposal of DAW generated 4

2 87 22 115 115 1,556 31,128 7

2a.4.5 Plant energy budget 737 111 847 424 424 2a.4.6 NRC Fees 715 72 787 787 2a.4.7 Emergency Planning Fees 400 40 440 440 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 17 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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.4.8 Site O&M Costs 500 75 575 575 2a.4.9 Spent Fuel Pool O&M 2,294 344 2,639 2,639 2a.4.10 ISFSI Operating Costs 176 26 202 202 2a.4.11 Security Staff Cost 11,410 1,712 13,122 3,559 9,563 277,507 2a.4.12 Utility Staff Cost 13,086 1,963 15,049 4,281 10,768 165,218 2a.4 Subtotal Period 2a Period-Dependent Costs 333 4

2 87 41,757 5,692 47,875 13,649 34,226 1,556 31,128 7

442,725 2a.0 TOTAL PERIOD 2a COST 333 4

2 87 79,318 11,376 91,120 14,344 76,776 1,556 31,128 7

442,725 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 154 23 177 177 2b.1.5 Maintenance supplies 1,340 335 1,675 1,675 2b.1 Subtotal Period 2b Activity Costs 1,494 358 1,852 1,852 Period 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 7,875 1,181 9,056 9,056 2b.3 Subtotal Period 2b Collateral Costs 7,875 1,181 9,056 9,056 Period 2b Period-Dependent Costs 2b.4.1 Insurance 3,229 323 3,552 3,439 113 2b.4.2 Property taxes 5,327 533 5,859 5,859 2b.4.3 Health physics supplies 818 204 1,022 1,022 2b.4.4 Disposal of DAW generated 12 4

224 58 298 298 4,019 80,388 18 2b.4.5 Plant energy budget 981 147 1,128 1,128 2b.4.6 NRC Fees 1,905 191 2,096 2,096 2b.4.7 Emergency Planning Fees 1,065 107 1,172 1,172 2b.4.8 Site O&M Costs 1,332 200 1,531 1,531 2b.4.9 ISFSI Operating Costs 469 70 539 539 2b.4.10 Security Staff Cost 13,550 2,032 15,582 9,479 6,103 300,163 2b.4.11 Utility Staff Cost 16,152 2,423 18,574 11,401 7,173 222,343 2b.4 Subtotal Period 2b Period-Dependent Costs 818 12 4

224 44,009 6,287 51,354 36,255 15,099 4,019 80,388 18 522,506 2b.0 TOTAL PERIOD 2b COST 818 12 4

224 53,378 7,827 62,262 38,107 24,155 4,019 80,388 18 522,506 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 516 77 593 593 2c.1.5 Maintenance supplies 4,480 1,120 5,601 5,601 2c.1 Subtotal Period 2c Activity Costs 4,996 1,197 6,194 6,194 Period 2c Period-Dependent Costs 2c.4.1 Insurance 10,454 1,045 11,500 11,500 2c.4.2 Property taxes 17,810 1,781 19,591 19,591 2c.4.3 Health physics supplies 2,647 662 3,308 3,308 2c.4.4 Disposal of DAW generated 38 14 741 191 985 985 13,281 265,627 61 2c.4.5 Plant energy budget 3,281 492 3,773 3,773 2c.4.6 NRC Fees 6,080 608 6,688 6,688 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 18 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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 4,452 668 5,120 5,120 2c.4.8 Security Staff Cost 27,561 4,134 31,695 31,695 544,933 2c.4.9 Utility Staff Cost 33,149 4,972 38,122 38,122 469,847 2c.4 Subtotal Period 2c Period-Dependent Costs 2,647 38 14 741 102,788 14,554 120,783 120,783 13,281 265,627 61 1,014,780 2c.0 TOTAL PERIOD 2c COST 2,647 38 14 741 107,785 15,751 126,976 126,976 13,281 265,627 61 1,014,780 PERIOD 2 TOTALS 3,797 54 20 1,052 240,481 34,954 280,359 179,428 100,931 18,857 377,143 87 1,980,010 PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy Period 3a Direct Decommissioning Activities 3a.1.1 Prepare preliminary decommissioning cost 66 10 76 76 556 3a.1.2 Review plant dwgs & specs.

232 35 267 267 1,969 3a.1.3 Perform detailed rad survey a

3a.1.4 End product description 51 8

58 58 428 3a.1.5 Detailed by-product inventory 66 10 76 76 556 3a.1.6 Define major work sequence 379 57 436 436 3,210 3a.1.7 Perform SER and EA 157 23 180 180 1,327 3a.1.8 Perform Site-Specific Cost Study 253 38 290 290 2,140 3a.1.9 Prepare/submit License Termination Plan 207 31 238 238 1,753 3a.1.10 Receive NRC approval of termination plan a

Activity Specifications 3a.1.11.1 Re-activate plant & temporary facilities 372 56 428 385 43 3,154 3a.1.11.2 Plant systems 210 32 242 218 24 1,783 3a.1.11.3 Reactor internals 359 54 412 412 3,039 3a.1.11.4 Reactor vessel 328 49 378 378 2,782 3a.1.11.5 Biological shield 25 4

29 29 214 3a.1.11.6 Steam generators 158 24 181 181 1,335 3a.1.11.7 Reinforced concrete 81 12 93 46 46 685 3a.1.11.8 Main Turbine 20 3

23 23 171 3a.1.11.9 Main Condensers 20 3

23 23 171 3a.1.11.10 Plant structures & buildings 158 24 181 91 91 1,335 3a.1.11.11 Waste management 232 35 267 267 1,969 3a.1.11.12 Facility & site closeout 45 7

52 26 26 385 3a.1.11 Total 2,009 301 2,310 2,034 277 17,024 Planning & Site Preparations 3a.1.12 Prepare dismantling sequence 121 18 139 139 1,027 3a.1.13 Plant prep. & temp. svces 2,800 420 3,220 3,220 3a.1.14 Design water clean-up system 71 11 81 81 599 3a.1.15 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,200 330 2,530 2,530 3a.1.16 Procure casks/liners & containers 62 9

71 71 526 3a.1 Subtotal Period 3a Activity Costs 8,672 1,301 9,973 9,696 277 31,117 Period 3a Period-Dependent Costs 3a.4.1 Insurance 293 29 323 323 3a.4.2 Property taxes 500 50 550 550 3a.4.3 Health physics supplies 344 86 430 430 3a.4.4 Heavy equipment rental 414 62 476 476 3a.4.5 Disposal of DAW generated 1

1 27 7

36 36 481 9,613 2

3a.4.6 Plant energy budget 921 138 1,059 1,059 3a.4.7 NRC Fees 214 21 236 236 3a.4.8 Site O&M Costs 125 19 144 144 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 19 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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.4.9 Security Staff Cost 240 36 276 276 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 757 1

1 27 16,552 2,587 19,926 19,926 481 9,613 2

206,486 3a.0 TOTAL PERIOD 3a COST 757 1

1 27 25,224 3,888 29,899 29,622 277 481 9,613 2

237,603 PERIOD 3b - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 239 36 275 247 27 2,026 3b.1.1.2 Reactor internals 126 19 145 145 1,070 3b.1.1.3 Remaining buildings 68 10 78 20 59 578 3b.1.1.4 CRD cooling assembly 51 8

58 58 428 3b.1.1.5 CRD housings & ICI tubes 51 8

58 58 428 3b.1.1.6 Incore instrumentation 51 8

58 58 428 3b.1.1.7 Reactor vessel 183 28 211 211 1,554 3b.1.1.8 Facility closeout 61 9

70 35 35 514 3b.1.1.9 Missile shields 23 3

26 26 193 3b.1.1.10 Biological shield 61 9

70 70 514 3b.1.1.11 Steam generators 232 35 267 267 1,969 3b.1.1.12 Reinforced concrete 51 8

58 29 29 428 3b.1.1.13 Main Turbine 79 12 91 91 668 3b.1.1.14 Main Condensers 79 12 91 91 668 3b.1.1.15 Auxiliary building 138 21 159 143 16 1,168 3b.1.1.16 Reactor building 138 21 159 143 16 1,168 3b.1.1 Total 1,629 244 1,873 1,510 363 13,800 3b.1 Subtotal Period 3b Activity Costs 1,629 244 1,873 1,510 363 13,800 Period 3b Additional Costs 3b.2.1 Site Characterization 2,711 813 3,525 3,525 13,042 4,640 3b.2 Subtotal Period 3b Additional Costs 2,711 813 3,525 3,525 13,042 4,640 Period 3b Collateral Costs 3b.3.1 Decon equipment 797 120 917 917 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 797 1,100 1,130 454 3,482 3,482 Period 3b Period-Dependent Costs 3b.4.1 Decon supplies 25 6

31 31 3b.4.2 Insurance 169 17 186 186 3b.4.3 Property taxes 252 25 277 277 3b.4.4 Health physics supplies 187 47 234 234 3b.4.5 Heavy equipment rental 209 31 240 240 3b.4.6 Disposal of DAW generated 1

0 15 4

20 20 267 5,344 1

3b.4.7 Plant energy budget 464 70 534 534 3b.4.8 NRC Fees 108 11 119 119 3b.4.9 Site O&M Costs 63 9

72 72 3b.4.10 Security Staff Cost 121 18 139 139 3,154 3b.4.11 DOC Staff Cost 3,314 497 3,811 3,811 43,109 3b.4.12 Utility Staff Cost 7,188 1,078 8,267 8,267 100,937 3b.4 Subtotal Period 3b Period-Dependent Costs 25 395 1

0 15 11,679 1,813 13,928 13,928 267 5,344 1

147,200 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 20 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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 822 1,495 1

0 15 17,149 3,325 22,807 22,444 363 267 5,344 13,043 165,640 PERIOD 3 TOTALS 822 2,253 2

1 42 42,373 7,213 52,706 52,066 640 748 14,956 13,045 403,242 PERIOD 4a - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Reactor Coolant Piping 38 131 30 19 42 158 103 521 521 803 803 186,244 2,979 4a.1.1.2 Pressurizer Relief Tank 7

26 6

4 9

30 20 102 102 165 165 36,553 596 4a.1.1.3 Reactor Coolant Pumps & Motors 25 94 53 168 1,272 384 1,996 1,996 4,796 780,540 2,726 80 4a.1.1.4 Pressurizer 11 59 345 94 412 172 1,093 1,093 3,033 252,826 1,527 750 4a.1.1.5 Steam Generators 85 4,096 1,426 2,363 580 3,416 2,505 14,471 14,471 39,289 14,436 3,096,232 20,508 1,500 4a.1.1.6 CRDMs/ICIs/Service Structure Removal 35 89 191 32 13 63 81 505 505 753 2,947 81,666 2,134 4a.1.1.7 Reactor Vessel Internals 67 2,001 3,441 515 3,719 203 4,413 14,360 14,360 2,211 376 470 325,254 23,067 1,055 4a.1.1.8 Vessel & Internals GTCC Disposal 11,665 1,750 13,414 13,414 505 104,146 4a.1.1.9 Reactor Vessel 81 3,970 1,280 655 2,978 203 5,021 14,188 14,188 6,672 2,254 979,179 23,067 1,055 4a.1.1 Totals 348 10,465 6,772 3,849 644 23,714 406 14,450 60,649 60,649 41,010 35,062 2,629 470 505 5,842,640 76,603 4,439 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 510 256 32 214 190 1,201 1,201 5,355 455,213 9,016 4a.1.3 Main Condensers 1,042 133 27 150 300 1,653 1,653 7,111 320,000 18,250 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor 1,076 161 1,237 1,237 12,130 4a.1.4.2 Auxiliary Building 602 90 692 692 6,896 4a.1.4.3 Radwaste/Service Building 391 59 450 450 5,060 4a.1.4.4 Refueling Water Storage Tank 104 16 120 120 1,299 4a.1.4.5 Fuel Handling Building 309 46 355 355 3,690 4a.1.4 Totals 2,481 372 2,853 2,853 29,074 Disposal of Plant Systems 4a.1.5.1 Auxiliary Feedwater 224 3

6 36 63 331 331 1,866 75,766 3,747 4a.1.5.2 Auxiliary Steam 115 17 132 132 2,107 4a.1.5.3 Auxiliary Steam RCA 326 5

10 54 92 486 486 2,822 114,583 5,241 4a.1.5.4 Boric Acid Processing 421 27 23 34 106 143 755 755 1,794 1,076 162,827 6,970 4a.1.5.5 CO2 & H2 16 2

18 18 289 4a.1.5.6 CO2 & H2 RCA 31 1

1 5

9 46 46 287 11,664 478 4a.1.5.7 Chemical Feed 145 22 167 167 2,663 4a.1.5.8 Chilled Water 80 12 92 92 1,454 4a.1.5.9 Circulating Water 525 79 604 604 9,669 4a.1.5.10 Condensate 293 44 337 337 5,317 4a.1.5.11 Condensate Booster 293 44 336 336 5,314 4a.1.5.12 Condensate Cleanup 160 24 184 184 3,000 4a.1.5.13 Containment Spray 229 6

12 69 70 386 386 3,602 146,289 3,673 4a.1.5.14 Diesel Fuel Oil 158 24 182 182 2,848 4a.1.5.15 Essential Service Water 274 41 315 315 5,049 4a.1.5.16 Extraction Steam 196 29 226 226 3,637 4a.1.5.17 Feedwater 267 40 307 307 4,925 4a.1.5.18 Feedwater Drains 633 95 728 728 11,719 4a.1.5.19 Gland Steam 33 5

38 38 616 4a.1.5.20 Gland Water 24 4

28 28 458 4a.1.5.21 Main Steam 271 41 312 312 4,979 4a.1.5.22 Main Steam RCA 76 2

3 19 23 123 123 990 40,190 1,250 4a.1.5.23 Make-up Demineralizer 137 21 158 158 2,595 4a.1.5.24 Nitrogen 1

0 1

1 18 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 21 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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.1.5.25 Non-Essential Service Water 318 48 366 366 5,903 4a.1.5.26 Non-Essential Service Water RCA 163 7

13 75 55 313 313 3,909 158,755 2,535 4a.1.5.27 Off Gas 605 13 25 141 177 962 962 7,411 300,945 10,038 4a.1.5.28 Potable Water 4

1 5

5 75 4a.1.5.29 Process Radiation Monitoring 59 0

0 3

15 77 77 138 5,613 1,086 4a.1.5.30 Process Sampling 129 1

2 12 35 179 179 641 26,045 2,347 4a.1.5.31 Sewage Treatment Plant 85 13 98 98 1,579 4a.1.5.32 Station Air 38 6

44 44 705 4a.1.5.33 Station Heating 130 19 149 149 2,391 4a.1.5.34 Steam Humidification 6

1 7

7 115 4a.1.5.35 Switchgear Heat Removal 29 4

33 33 519 4a.1.5.36 Turbine Bldg Equip Drains 67 10 77 77 1,235 4a.1.5.37 Turbine Bldg Floor Drains 115 17 133 133 2,117 4a.1.5.38 Turbine Oil 73 11 84 84 1,359 4a.1.5.39 Turbine-Generator Auxilaries 49 7

57 57 884 4a.1.5.40 Waste Oil Sumps 28 4

32 32 517 4a.1.5.41 Well Water 69 10 79 79 1,247 4a.1.5 Totals 6,898 66 96 448 106 1,376 8,989 3,659 5,330 23,460 1,076 1,042,678 122,666 4a.1.6 Scaffolding in support of decommissioning 1,358 9

2 10 3

343 1,726 1,726 473 29 23,936 26,134 4a.1 Subtotal Period 4a Activity Costs 348 22,755 7,236 4,006 1,466 23,823 406 17,031 77,071 71,741 5,330 77,409 36,168 2,629 470 505 7,684,466 281,743 4,439 Period 4a Collateral Costs 4a.3.1 Process liquid waste 37 18 82 80 52 269 269 288 17,264 56 4a.3.2 Small tool allowance 253 38 291 262 29 4a.3 Subtotal Period 4a Collateral Costs 37 253 18 82 80 90 560 530 29 288 17,264 56 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 64 16 80 80 4a.4.2 Insurance 440 44 484 484 4a.4.3 Property taxes 657 66 723 651 72 4a.4.4 Health physics supplies 1,619 405 2,024 2,024 4a.4.5 Heavy equipment rental 2,295 344 2,639 2,639 4a.4.6 Disposal of DAW generated 9

3 181 47 241 241 3,251 65,015 15 4a.4.7 Plant energy budget 1,150 173 1,323 1,323 4a.4.8 NRC Fees 593 59 652 652 4a.4.9 Site O&M Costs 164 25 189 189 4a.4.10 Liquid Radwaste Processing Equipment/Services 504 76 579 579 4a.4.11 Security Staff Cost 2,245 337 2,581 2,581 58,505 4a.4.12 DOC Staff Cost 15,170 2,275 17,445 17,445 189,257 4a.4.13 Utility Staff Cost 25,600 3,840 29,440 29,440 342,857 4a.4 Subtotal Period 4a Period-Dependent Costs 64 3,914 9

3 181 46,523 7,706 58,401 58,329 72 3,251 65,015 15 590,619 4a.0 TOTAL PERIOD 4a COST 449 26,922 7,263 4,091 1,466 24,085 46,929 24,827 136,032 130,601 5,431 77,409 39,707 2,629 470 505 7,766,745 281,814 595,059 PERIOD 4b - Site Decontamination Period 4b Direct Decommissioning Activities 4b.1.1 Remove spent fuel racks 990 106 305 93 590 713 2,796 2,796 5,572 499,920 2,174 Disposal of Plant Systems 4b.1.2.1 Chemical & Volume Control 954 59 44 34 243 317 1,652 1,652 1,783 2,322 278,742 15,645 4b.1.2.2 Chilled Water RCA 592 13 25 139 174 943 943 7,293 296,176 9,173 4b.1.2.3 Component Cooling 627 17 31 178 190 1,043 1,043 9,319 378,439 10,075 4b.1.2.4 Electrical 3,669 550 4,220 4,220 66,259 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 22 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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.1.2.5 Electrical - Contaminated 1,564 17 32 181 425 2,219 2,219 9,508 386,137 25,754 4b.1.2.6 Electrical - RCA 2,236 39 72 410 635 3,392 3,392 21,460 871,483 37,551 4b.1.2.7 Emergency Diesel Generator 83 13 96 96 1,514 4b.1.2.8 Essential Service Water RCA 303 17 32 179 109 639 639 9,380 380,930 4,955 4b.1.2.9 Fire Protection 271 41 311 311 4,983 4b.1.2.10 Fire Protection RCA 476 12 22 124 142 776 776 6,516 264,606 7,384 4b.1.2.11 Fuel Handling Bldg Equip Drains 146 7

7 20 23 47 249 249 1,027 221 60,829 2,404 4b.1.2.12 Fuel Handling Bldg Equip Drains (Unit 1) 26 1

1 1

4 8

41 41 67 34 5,758 424 4b.1.2.13 Fuel Handling Bldg Floor Drains 149 7

7 16 25 48 252 252 830 238 54,723 2,441 4b.1.2.14 Fuel Handling Bldg Floor Drains (Unit 1) 103 4

4 13 11 32 168 168 703 109 37,980 1,740 4b.1.2.15 Fuel Pool Cooling & Cleanup 199 11 11 24 43 67 355 355 1,275 406 88,160 3,272 4b.1.2.16 Fuel Pool Cooling & Cleanup (Unit 1) 184 10 10 23 38 62 327 327 1,226 361 82,110 3,050 4b.1.2.17 HVAC-Auxiliary Building 485 10 19 108 141 762 762 5,643 229,172 7,876 4b.1.2.18 HVAC-Control Room HVAC 7

1 8

8 127 4b.1.2.19 HVAC-Diesel Generator Room 38 6

44 44 686 4b.1.2.20 HVAC-Laboratory 17 3

20 20 315 4b.1.2.21 HVAC-Machine Shop 16 2

18 18 297 4b.1.2.22 HVAC-Miscellaneous 97 14 111 111 1,769 4b.1.2.23 HVAC-Primary Containment 539 19 36 204 173 970 970 10,679 433,695 8,624 4b.1.2.24 HVAC-Pumphouse 15 2

18 18 275 4b.1.2.25 HVAC-Radwaste 279 6

11 63 82 441 441 3,327 135,102 4,323 4b.1.2.26 HVAC-Turbine Building 163 24 187 187 3,158 4b.1.2.27 Instrument Air Supply 64 10 73 73 1,197 4b.1.2.28 Instrument Air Supply RCA 220 2

3 20 59 304 304 1,035 42,036 3,563 4b.1.2.29 Miscellaneous Drains 66 1

2 12 19 100 100 617 25,043 1,104 4b.1.2.30 Primary Containment Purge 261 10 20 111 86 488 488 5,816 236,197 4,524 4b.1.2.31 Primary Water 722 31 43 187 61 233 1,278 1,278 9,803 667 449,848 12,651 4b.1.2.32 Radioactive Waste Disposal 2,431 164 134 181 652 834 4,396 4,396 9,461 6,530 936,736 39,735 4b.1.2.33 Reactor Bldg Equipment Drains 96 8

7 7

37 36 191 191 356 350 45,614 1,581 4b.1.2.34 Reactor Building Floor Drains 36 2

2 2

7 12 60 60 125 66 11,009 597 4b.1.2.35 Reactor Coolant 147 8

6 4

32 47 243 243 206 299 35,137 2,391 4b.1.2.36 Residual Heat Removal 167 10 12 27 43 59 318 318 1,421 405 94,061 2,834 4b.1.2.37 Safety Injection 760 36 46 172 98 251 1,362 1,362 9,001 979 448,431 13,165 4b.1.2.38 Station Air RCA 51 1

1 6

14 72 72 293 11,919 815 4b.1.2.39 Station Heating RCA 223 4

8 46 64 346 346 2,412 97,961 3,548 4b.1.2.40 Waste Oil Sumps RCA 23 0

1 3

6 33 33 154 6,246 361 4b.1.2.41 Waste Water Treatment 78 12 90 90 1,464 4b.1.2 Totals 18,585 524 648 2,495 1,316 5,047 28,616 23,420 5,196 130,736 12,987 6,424,277 313,605 4b.1.3 Scaffolding in support of decommissioning 2,037 14 3

15 5

515 2,589 2,589 710 44 35,904 39,201 Decontamination of Site Buildings 4b.1.4.1 Reactor 1,748 1,236 171 191 134 455 1,363 5,297 5,297 7,022 8,433 1,122,399 50,351 4b.1.4.2 Auxiliary Building 205 105 8

9 17 18 138 499 499 866 322 66,374 5,241 4b.1.4.3 Radwaste/Service Building 134 42 6

6 6

15 84 293 293 322 278 40,041 2,960 4b.1.4.4 Refueling Water Storage Tank 315 366 4

5 22 6

255 973 973 1,146 87 54,853 11,906 4b.1.4.5 Fuel Handling Building 904 1,006 14 17 59 26 723 2,749 2,749 3,097 411 165,835 33,340 4b.1.4 Totals 3,306 2,755 203 228 238 520 2,562 9,812 9,812 12,453 9,531 1,449,503 103,797 4b.1 Subtotal Period 4b Activity Costs 4,296 23,483 1,046 972 2,748 2,430 8,837 43,813 38,617 5,196 143,899 28,134 8,409,604 458,777 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 38 1

23 90 727 144 1,022 1,022 1,705 142,596 2,873 1,280 4b.2 Subtotal Period 4b Additional Costs 38 1

23 90 1,667 426 2,244 1,222 1,022 1,705 142,596 2,873 7,520 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 23 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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 104 52 237 232 151 775 775 832 49,896 162 4b.3.2 Small tool allowance 431 65 495 495 4b.3.3 Decommissioning Equipment Disposition 119 34 127 40 46 365 365 6,000 373 303,507 88 4b.3 Subtotal Period 4b Collateral Costs 104 431 171 270 127 271 261 1,636 1,636 6,000 1,205 353,402 250 Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 851 213 1,064 1,064 4b.4.2 Insurance 886 89 975 975 4b.4.3 Property taxes 1,322 132 1,455 1,455 4b.4.4 Health physics supplies 2,839 710 3,549 3,549 4b.4.5 Heavy equipment rental 4,581 687 5,269 5,269 4b.4.6 Disposal of DAW generated 19 7

367 95 488 488 6,584 131,682 30 4b.4.7 Plant energy budget 1,827 274 2,101 2,101 4b.4.8 NRC Fees 1,193 119 1,312 1,312 4b.4.9 Site O&M Costs 331 50 380 380 4b.4.10 Liquid Radwaste Processing Equipment/Services 1,014 152 1,166 1,166 4b.4.11 Security Staff Cost 7,628 1,144 8,772 8,772 172,500 4b.4.12 DOC Staff Cost 29,760 4,464 34,224 34,224 369,840 4b.4.13 Utility Staff Cost 48,980 7,347 56,327 56,327 651,360 4b.4 Subtotal Period 4b Period-Dependent Costs 851 7,420 19 7

367 92,941 15,476 117,081 117,081 6,584 131,682 30 1,193,700 4b.0 TOTAL PERIOD 4b COST 5,251 31,372 1,237 1,273 2,875 3,158 94,608 25,000 164,774 158,556 1,022 5,196 149,899 37,628 9,037,285 461,930 1,201,220 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 7,473 2,242 9,716 9,716 128,636 3,120 4e.2 Subtotal Period 4e Additional Costs 7,473 2,242 9,716 9,716 128,636 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 376 38 414 414 4e.4.3 Health physics supplies 738 185 923 923 4e.4.4 Disposal of DAW generated 1

0 19 5

25 25 335 6,698 2

4e.4.5 Plant energy budget 139 21 160 160 4e.4.6 NRC Fees 355 35 390 390 4e.4.7 Site O&M Costs 94 14 108 108 4e.4.8 Security Staff Cost 544 82 625 625 11,786 4e.4.9 DOC Staff Cost 3,801 570 4,371 4,371 46,750 4e.4.10 Utility Staff Cost 4,551 683 5,234 5,234 56,964 4e.4 Subtotal Period 4e Period-Dependent Costs 738 1

0 19 9,859 1,632 12,249 12,249 335 6,698 2

115,500 4e.0 TOTAL PERIOD 4e COST 738 1

0 19 18,614 4,089 23,461 23,461 335 6,698 128,638 118,620 PERIOD 4 TOTALS 5,700 59,032 8,501 5,364 4,341 27,262 160,152 53,916 324,267 312,618 1,022 10,627 227,308 77,669 2,629 470 505 16,810,730 872,381 1,914,899 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 24 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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 6,217 933 7,149 7,149 69,541 5b.1.1.2 Aux Feedwater-Steam Tunnel/Penetr. Area 644 97 741 741 5,185 5b.1.1.3 Auxiliary Building 5,417 813 6,230 6,230 62,063 5b.1.1.4 Berms, Settling Ponds, and Drying Beds 130 19 149 149 1,631 5b.1.1.5 Circulating Water Pumphouse 931 140 1,071 1,071 11,861 5b.1.1.6 Essential Service Cooling Tower 427 64 491 491 5,067 5b.1.1.7 Make-up Demineralizer Area 1,558 234 1,792 1,792 20,770 5b.1.1.8 Miscellaneous Site Structures 1,649 247 1,897 1,897 20,544 5b.1.1.9 Radwaste/Service Building 3,579 537 4,116 4,116 45,688 5b.1.1.10 Receiving Building 166 25 190 190 2,293 5b.1.1.11 Refueling Water Storage Tank 936 140 1,077 1,077 11,688 5b.1.1.12 River Screen House 524 79 603 603 5,869 5b.1.1.13 Security Modifications 975 146 1,121 1,121 8,636 5b.1.1.14 Turbine Building 5,246 787 6,033 6,033 70,347 5b.1.1.15 Turbine Pedestal 1,250 187 1,437 1,437 12,628 5b.1.1.16 Yard Inventory 1,876 281 2,158 2,158 20,610 5b.1.1.17 Fuel Handling Building 2,781 417 3,198 3,198 33,246 5b.1.1 Totals 34,307 5,146 39,453 39,453 407,670 Site Closeout Activities 5b.1.2 BackFill Site 3,308 496 3,804 3,804 9,059 5b.1.3 Grade & landscape site 267 40 307 307 869 5b.1.4 Final report to NRC 79 12 91 91 668 5b.1 Subtotal Period 5b Activity Costs 37,882 79 5,694 43,655 91 43,565 417,598 668 Period 5b Additional Costs 5b.2.1 Hyperbolic Cooling Tower 2,769 415 3,184 3,184 18,598 5b.2.2 ISFSI Demolition and Site Restoration 1,227 24 188 1,439 1,439 17,085 80 5b.2.3 Cofferdam Construction and Teardown 409 61 470 470 3,996 5b.2.4 Concrete Crushing 935 5

141 1,081 1,081 4,554 5b.2 Subtotal Period 5b Additional Costs 5,339 29 805 6,174 1,439 4,735 44,233 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 439 66 505 505 5b.3 Subtotal Period 5b Collateral Costs 439 66 505 505 Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property taxes 1,239 124 1,363 1,363 5b.4.3 Heavy equipment rental 6,137 921 7,057 7,057 5b.4.4 Plant energy budget 228 34 262 262 5b.4.5 Site O&M Cost 310 46 356 356 5b.4.6 Security Staff Cost 1,616 242 1,859 1,859 34,287 5b.4.7 DOC Staff Cost 11,650 1,748 13,398 13,398 137,043 5b.4.8 Utility Staff Cost 5,559 834 6,392 6,392 67,229 5b.4 Subtotal Period 5b Period-Dependent Costs 6,137 20,602 3,949 30,687 30,687 238,558 5b.0 TOTAL PERIOD 5b COST 49,797 20,710 10,514 81,021 91 1,439 79,491 461,831 239,306 PERIOD 5 TOTALS 49,797 20,710 10,514 81,021 91 1,439 79,491 461,831 239,306 TOTAL COST TO DECOMMISSION 12,014 116,926 8,754 6,272 4,341 29,293 559,208 123,797 860,604 638,996 130,850 90,758 227,308 101,683 2,629 470 505 17,415,320 1,425,062 5,345,059 TLG Services, Inc.

Byron Nuclear Power Station Decommissioning Cost Analysis Document E16-1555-013, Rev. 0 Appendix E, Page 25 of 25 Table E-2 Byron Nuclear Power Station, Unit 2 SAFSTOR Decommissioning Cost Estimate (thousands of 2009 dollars)

Costs run: Thu, Aug 27, 2009 at 16:04:55 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 16.8% CONTINGENCY:

$860,604 thousands of 2009 dollars TOTAL NRC LICENSE TERMINATION COST IS 74.25% OR:

$638,996 thousands of 2009 dollars SPENT FUEL MANAGEMENT COST IS 15.2% OR:

$130,850 thousands of 2009 dollars NON-NUCLEAR DEMOLITION COST IS 10.55% OR:

$90,758 thousands of 2009 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

104,782 cubic feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

505 cubic feet TOTAL SCRAP METAL REMOVED:

74,707 tons TOTAL CRAFT LABOR REQUIREMENTS:

1,425,062 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 Byron Station, Units 1 and 2 Radiological Decommissioning Projected SAFSTOR Cash Flow (dollars, thousands)

Byron Unit 1 Radiological Decommissioning Cost Byron Unit 2 Radiological Decommissioning Cost Year (October 31, 2009 dollars)

(October 31, 2009 dollars) 2024

$7,735

$0 2025

$51,055

$0 2026

$16,900

$7,570 2027

$2,715

$56,030 2028

$2,722

$33,550 2029

$2,715

$3,584 2030

$3,321

$3,584 2031

$3,618

$3,584 2032

$3,627

$3,588 2033

$3,618

$3,575 2034

$3,618

$3,575 2035

$3,618

$3,575 2036

$3,627

$3,584 2037

$3,618

$3,575 2038

$3,618

$3,575 2039

$3,618

$3,575 2040

$3,627

$3,584 2041

$3,618

$3,575 2042

$3,617

$3,575 2043

$3,594

$3,562 2044

$3,604

$3,572 2045

$3,594

$3,562 2046

$3,594

$3,562 2047

$3,594

$3,562 2048

$3,604

$3,572 2049

$3,594

$3,562 2050

$3,594

$3,562 2051

$3,594

$3,562 2052

$3,604

$3,572 2053

$3,594

$3,562 2054

$3,594

$3,562 2055

$3,594

$3,562 2056

$3,604

$3,572 2057

$3,594

$3,562 2058

$3,594

$3,562 2059

$3,594

$3,562 2060

$3,604

$3,572 2061

$3,594

$3,562 2062

$3,594

$3,562

ATTACHMENT 2 Byron Station Units 1 and 2 Radiological Decommissioning Projected SAFSTOR Cash Flow (continued)

(dollars, thousands)

Byron Unit 1 Radiological Decommissioning Cost Byron Unit 2 Radiological Decommissioning Cost Year (October 31, 2009 dollars)

(October 31, 2009 dollars) 2063

$3,594

$3,562 2064

$3,604

$3,572 2065

$3,594

$3,562 2066

$3,594

$3,562 2067

$3,594

$3,562 2068

$3,604

$3,572 2069

$3,594

$3,562 2070

$3,594

$3,562 2071

$3,594

$3,562 2072

$3,604

$3,572 2073

$3,594

$3,562 2074

$3,594

$3,562 2075

$3,594

$3,562 2076

$3,604

$3,572 2077

$10,752

$3,562 2078

$48,519

$13,558 2079

$94,144

$35,337 2080

$81,599

$92,706 2081

$41,344

$77,074 2082

$35,335

$59,910 2083

$2,176

$59,910 2084

$21,081

$28,391 2085

$85

$37 2086

$85

$37 2087

$26

$11 Total

$588,038

$638,996