ML24318C273

Request for Exemptions from 10 CFR 50.82(a)(8)(i) and (II) for Use of Nuclear Decommissioning Trust Funds for Disposal of Major Radioactive Components During Operations

ML24318C273
Person / Time
Site:	Arkansas Nuclear
Issue date:	11/13/2024
From:	Couture P Entergy Operations
To:	Office of Nuclear Reactor Regulation, Document Control Desk
References
CNRO2024-00026
Download: ML24318C273 (1)

Text

Phil Couture Senior Manager Fleet Regulatory Assurance - Licensing 601-368-5102 Entergy Operations, Inc. 1340 Echelon Parkway, Jackson, MS 39213 CNRO2024-00026 10 CFR 50.12 10 CFR 50.82(a)(8)(i) and (ii)

November 13, 2024 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001

Subject:

Request for Exemptions from 10 CFR 50.82(a)(8)(i) and (ii) for use of Nuclear Decommissioning Trust Funds for Disposal of Major Radioactive Components During Operations Arkansas Nuclear One, Units 1 & 2 NRC Docket Nos. 50-313 and 50-368 Renewed Facility Operating License Nos. DPR-51 & NPF-6

Dear Sir or Madam:

Pursuant to 10 CFR 50.12, Entergy Operations, Inc. (EOI) requests exemptions from 10 CFR 50.82(a)(8)(i) and (ii) for Arkansas Nuclear One (ANO) Units 1 and 2 to allow the immediate withdrawal of a small portion of the funds from the ANO Unit 1 and Unit 2 nuclear decommissioning trust funds (DTF) to facilitate the prompt disposal of certain retired Major Radioactive Components (MRCs).

Specifically, EOI seeks approval to use the DTFs, not to exceed $20 million per Unit, to promptly dispose of the following MRCs:

Unit 1 - Two steam generators and one reactor vessel closure head that were removed from service in 2005.

Unit 2 - Two steam generators that were removed from service in 2000.

Currently, these MRCs are stored in long-term onsite storage facilities at ANO, which have reached their capacity. During the Unit 2 refueling outage that is currently planned for Spring 2026, EOI plans to replace the existing reactor vessel closure head ("RVCH"), which will require EOI to remove the component from service and store it onsite. Unless capacity can be recovered from the current onsite storage facilities, EOI will have to build a new facility to store the Unit 2 RVCH. However, if EOI were to dispose of the older MRCs that were removed from service in 2000 and 2005 to make room for the Unit 2 RVCH, then it could avoid the costs to construct the new facility, as well as the ongoing maintenance costs and the eventual costs to decommission the new storage facility.

If approved, the exemptions will facilitate the prompt removal of radiologically contaminated material from ANO, reduce overall decommissioning costs, and reduce an unnecessary

CNRO2024-00026 Page 2 of 3 regulatory burden on EOI and costs associated with continuing to maintain and store the MRCs on site.

The Enclosure to this letter sets forth the basis for EOIs exemption request and includes supporting information outlined in "Interim Staff Guidance on the Use of the Decommissioning Trust Fund During Operations for Major Radioactive Component Disposal (REFS-ISG-2024-01)," to assist the Staffs review of this request. Consistent with 10 CFR 50.12(a), and as demonstrated in the Enclosure, the requested exemptions: (1) are authorized by law; (2) will not present an undue risk to the public health and safety; (3) are consistent with the common defense and security; and (4) are supported by special circumstances.

Further, approving the requested exemptions would be consistent with the NRCs decommissioning regulations (see, e.g., 10 CFR 50.82(a)(6)) as they would not:

(1) foreclose release of the site for possible unrestricted use; (2) result in significant environmental impacts not previously reviewed; or (3) result in there no longer being reasonable assurance that adequate funds will be available for decommissioning.

EOI is submitting these exemption requests now because timely resolution of this issue is needed to support planning activities for the removal and disposal of the MRCs. If space in the current storage facilities cannot be recovered and additional onsite storage capacity is required, EOI plans to begin construction activities for the new facility by September 2025. Accordingly, EOI respectfully requests a response from the NRC by August 1, 2025, to avoid the resource allocation and other related expenses, which would be avoided if funds in the DTFs can be used for the prompt disposal of the MRCs.

This letter contains no new regulatory commitments.

If you have any questions or require additional information, please contact me at 601-368-5102.

Respectfully, Phil Couture PC/chm Digitally signed by Philip Couture DN: cn=Philip Couture, c=US, o=Entergy, ou=Regulatory Assurance, email=pcoutur@entergy.com Date: 2024.11.13 07:34:53 -06'00' Philip Couture

CNRO2024-00026 Page 3 of 3

Enclosure:

Arkansas Nuclear One, Units 1 and 2 Request for Exemptions from 10 CFR 50.82(a)(8)(i) and (ii)

Attachments to

Enclosure:

1. Decommissioning Cost Analysis for Arkansas Nuclear One

2. Arkansas Nuclear One Unit 1 - DECON Methodology, Annual Cash Flow Analysis - Total License Termination Costs

3. Arkansas Nuclear One Unit 2 - DECON Methodology, Annual Cash Flow Analysis - Total License Termination Costs cc:

NRC Region IV Regional Administrator NRC Senior Resident Inspector - ANO NRC Project Manager - ANO

Enclosure CNRO2024-00026 Arkansas Nuclear One, Units 1 and 2 Request for Exemptions from 10 CFR 50.82(a)(8)(i) and (ii)

CNRO2024-00026 Enclosure Page 1 of 12 Table of Contents I.

Exemptions Requested and Purpose................................................................................ 2 II.

Applicable Regulations....................................................................................................... 3 III. Justification for Exemption and Special Circumstances................................................. 4 IV. Environmental Assessment................................................................................................ 6 V.

Extraordinary Circumstances Justify Granting the Requested Exemptions................. 8 VI. Conclusion......................................................................................................................... 12 VII. Attachments....................................................................................................................... 12

CNRO2024-00026 Enclosure Page 2 of 12 Arkansas Nuclear One, Units 1 and 2 Request for Exemptions from 10 CFR 50.82(a)(8)(i) and (ii)

I.

EXEMPTIONS REQUESTED AND PURPOSE Pursuant to 10 CFR 50.12, Entergy Operations, Inc. (EOI) requests that the Nuclear Regulatory Commission (NRC) grant exemptions from the requirements of 10 CFR 50.82(a)(8)(i) and (ii) to allow the immediate withdrawal of a small portion of the funds from the Arkansas Nuclear One (ANO) Unit 1 and Unit 2 nuclear decommissioning trust funds (DTF) to cover the cost of disposal of certain retired major radioactive components (MRCs).

EOI seeks approval to use funds in the DTFs, up to $20 million per Unit, to promptly dispose of the following retired MRCs at ANO:

Unit 1 - Two steam generators and one reactor vessel closure head (RVCH) that were removed from service in 2005.

Unit 2 - Two steam generators that were removed from service in 2000.

EOI currently stores these MRCs onsite at ANO in two mausoleums, which have reached their capacity. During the Unit 2 refueling outage that is currently planned for Spring 2026, EOI plans to replace the existing RVCH, which will require EOI to store the RVCH onsite after it is removed from service. Given the anticipated level of radioactivity of the Unit 2 RVCH, prompt disposal of the component is not a feasible option. However, there is insufficient space in either of the existing mausoleums to store the additional RVCH. Accordingly, because it does not have the ability to store the Unit 2 RVCH in the existing mausoleums, EOI must construct a new storage facility if storage space cannot be recovered in the existing mausoleums. Alternatively, however, if EOI were to dispose of the MRCs that were retired in 2000 and 2005, it could gain sufficient storage space for the Unit 2 RVCH, while avoiding the costs to construct a new facility, as well as the ongoing maintenance costs and the eventual costs to decommission the new storage facility.

As noted in the NRCs Interim Staff Guidance on the Use of the Decommissioning Trust Fund During Operations for Major Radioactive Component Disposal (ISG), the NRC recognizes that once a reactor has permanently ceased operations, the disposal of MRCs is a legitimate decommissioning activity for which DTF funds may be used.1 Furthermore, the Arkansas Public Service Commission (APSC) has authorized the collection of funds from ratepayers to ensure the DTFs are properly funded to pay for decommission costs, which include disposing the MRCs at issue. Thus, there is no controversy over whether the ANO DTFs can be used to dispose of the retired MRCs. Rather, it is merely a matter of timing of when those funds may be used. This exemption request seeks a modest acceleration of the withdrawal of the DTF funds for the disposal activities by approximately 10 years for Unit 1 and approximately 15 years for Unit 2.2 1

"InterimStaffGuidanceontheUseoftheDecommissioningTrustFundDuringOperationsforMajor RadioactiveComponentDisposal(REFSISG202401),"at3(August5,2024)(hereinafterISG).

2 Thesetimeperiodsassumenosubsequentlicenserenewalforeitherunit,althoughadecisiontopursue subsequentlicenserenewalhasnotyetbeenmade.Asindicatedinthesitespecificdecommissioningcost estimate(DCE)providedinAttachment1tothisEnclosure,disposaloftheretiredMRCsatissueisscheduled tooccurduring"Period2a,"whichunderaDECONscenario,beginsinlate2035forUnit1andinearly2040for Unit2.SeeAttachment1,Section4at6.AsnotedinSectionV.Bbelow,thisexemptionrequestandits supportingcashflowanalysesconservativelyassumethatEOIwilldecommissionUnits1and2underaDECON

CNRO2024-00026 Enclosure Page 3 of 12 II.

APPLICABLE REGULATIONS The NRC regulations in 10 CFR 50.82(a)(8)(i) provide that decommissioning trust funds may be used by licensees if:

(A)

The withdrawals are for expenses for legitimate decommissioning activities consistent with the definition of decommissioning in § 50.2; (B)

The expenditure would not reduce the value of the decommissioning trust below an amount necessary to place and maintain the reactor in a safe storage condition if unforeseen conditions or expenses arise and; (C)

The withdrawals would not inhibit the ability of the licensee to complete funding of any shortfalls in the decommissioning trust needed to ensure the availability of funds to ultimately release the site and terminate the license.

Section 50.2 defines the term "decommission" as:

to remove a facility or site safely from service and reduce residual radioactivity to a level that permits-(1) release of the property for unrestricted use and termination of the license; or (2) release of the property under restricted conditions and termination of the license.

NRC has further conditioned the withdrawal of decommissioning trust funds by limiting the timing of withdrawals from the trust. For example, 10 CFR 50.82(a)(8)(ii) provides:

Initially, 3 percent of the generic amount specified in § 50.75 may be used for decommissioning planning. For licensees that have submitted the certifications required under § 50.82(a)(1) and commencing 90 days after the NRC has received the [post-shutdown decommissioning activities report], an additional 20 percent may be used. A site-specific decommissioning cost estimate must be submitted to the NRC prior to the licensee using any funding in excess of these amounts.

In the absence of an exemption from these regulations by the NRC, they would restrict EOIs ability to use the ANO Unit 1 and Unit 2 DTFs for the disposal of MRCs prior to permanent cessation of operations at each of ANOs units.

Pursuant to 10 CFR 50.12, the NRC may grant exemptions from the agencys regulatory requirements if they are:

(1) Authorized by law, will not present an undue risk to the public health and safety, and are consistent with the common defense and security.

(2) The Commission will not consider granting an exemption unless special circumstances are present.

scenario,althoughEOIhasnotyetmadeanydecisionsonwhetheritwouldadoptaDECONorSAFSTOR approachforANO.

CNRO2024-00026 Enclosure Page 4 of 12 III.

JUSTIFICATION FOR EXEMPTION AND SPECIAL CIRCUMSTANCES For the reasons discussed below, EOIs exemption request satisfies the requirements for specific exemptions, as set forth in 10 CFR 50.12.

A. The Requested Exemptions Are Authorized by Law The requested exemptions from 10 CFR 50.82(a)(8)(i) and (ii) would allow EOI to immediately withdraw a small portion of the funds from the ANO Unit 1 and Unit 2 DTFs to facilitate the prompt disposal of certain retired MRCs. As stated above, 10 CFR 50.12 allows the NRC to grant exemptions from the requirements of 10 CFR Part 50. The proposed exemptions would not result in a violation of the Atomic Energy Act of 1954, as amended, or the Commission's regulations. Therefore, the exemptions are authorized by law.

B. The Requested Exemptions Do Not Present an Undue Risk to the Public Health and Safety The underlying purpose of 10 CFR 50.82(a)(8)(i) and (ii) is to provide reasonable assurance that adequate funds will be available for decommissioning within 60 years of permanent cessation of operations.3 As demonstrated in the site-specific DCE and the cash flow analyses provided in Attachments 1, 2 and 3, using a small portion of the Unit 1 and Unit 2 DTFs for the prompt disposal of certain retired MRCs will not adversely impact EOIs ability to terminate the Unit 1 or Unit 2 licenses within the required decommissioning timeframe.

Based on the above, no new accident precursors would be created by using the DTFs in the proposed manner. Thus, the probability of postulated accidents is not increased. Nor would the consequences of any postulated accidents be increased. No changes are being made in the types or amounts of effluents that may be released offsite. There is no significant increase in occupational or public radiation exposure. To the contrary, the prompt removal and disposal of significant source terms from the site would enhance public health and safety. Therefore, the requested exemptions will not present an undue risk to the public health and safety.

C. The Requested Exemptions Will Not Endanger the Common Defense and Security Allowing the use of funds in the DTFs for the immediate disposal of MRCs would not alter the scope of, or the availability of sufficient funding for the ANO security program and would not adversely affect EOIs ability to physically secure the site and to protect special nuclear material.

Therefore, the requested exemptions will not endanger the common defense and security.

3 See,e.g.,RegulatoryGuide1.159,Rev.2,atSectionB("theruleondecommissioningrequiresthatapplicants andlicenseesprovideadequateassurancethatadequatefundsfordecommissioningwillbeavailableatthe endofoperation");seealso10CFR50.82(a)(3)(60yearrequirement).

CNRO2024-00026 Enclosure Page 5 of 12 D. Special Circumstances Support Granting the Requested Exemptions Pursuant to 10 CFR 50.12(a)(2), special circumstances must be present for the NRC to grant an exemption to its regulations. Here, special circumstances do exist and support granting the requested exemptions, and the applicable Section 50.12(a)(2) criteria are addressed below.

1. Application of the regulations in the particular circumstances would not serve the underlying purpose of the rule or is not necessary to achieve the underlying purpose of the rule

(§ 50.12(a)(2)(ii)).

As discussed above, the underlying purpose of 10 CFR 50.82(a)(8)(i) and (ii) is to provide reasonable assurance that adequate funds will be available for decommissioning within 60 years of permanent cessation of operations. The application of the regulations prohibits the expenditure of funds in the DTFs for the prompt disposal of the retired MRCs in this circumstance, which is not necessary to achieve the underlying purpose of the rules. As demonstrated in the cash flow analyses provided in Attachments 2 and 3, the Unit 1 and Unit 2 DTFs will have more than sufficient funding to complete decommissioning of the respective Units, even if certain funds are withdrawn in the near-term for early disposal of the MRCs.

2. Compliance would result in undue hardship or other costs that are significantly in excess of those contemplated when the regulation was adopted, or that are significantly in excess of those incurred by others similarly situated (§ 50.12(a)(2)(iii)).

Compliance with the restrictions on the use of the decommissioning funds would result in an undue hardship on EOI because of EOIs continued need to store the Unit 2 RVCH onsite at ANO. In particular, if EOI is unable to remove the retired MRCs from the two existing mausoleums and dispose of them promptly, EOI must construct an additional storage facility to house the Unit 2 RVCH that will be removed from service in 2026. Compliance with 10 CFR 50.82(a)(8)(i) and (ii) would create an unnecessary regulatory burden in that it would cause EOI to use operating revenues to build and maintain a third storage facility, monitor any releases, and eventually decommission the facility, rather than allowing EOI to use decommissioning funds that were collected to cover the costs of disposing of these MRCs. The construction costs alone are estimated to be $2.2 million, plus additional maintenance costs over the lifetime of the facility and eventual decommissioning costs.

Alternatively, requiring EOI to use operating revenues to fund the prompt disposal of the retired MRCs would also result in a similar undue hardship to EOI, in that the Unit 1 and Unit 2 DTFs already include funds that were collected to cover the disposal costs for the very same MRCs at issue.

3. The exemptions would result in a benefit to the public health and safety that compensates for any decrease in safety that may result from the grant of the exemptions

(§ 50.12(a)(2)(iv)).

Granting the requested exemptions would not result in any decrease in safety. It would, however, result in a benefit to the public health and safety in at least two respects. First, the near-term disposal of the retired MRCs ensures that the components will be removed from the site and disposed of, in that it secures disposal space at facilities with limited capacity at current prices. In addition, prompt removal of the source term from the site created by the retired MRCs furthers the objective of maintaining radiation exposures as low as reasonably achievable pursuant to 10 CFR 20.1101(b) by minimizing the potential for long-term exposure.

CNRO2024-00026 Enclosure Page 6 of 12

4. There is present any other material circumstance not considered when the regulation was adopted for which it would be in the public interest to grant an exemption (§ 50.12(a)(2)(vi)).

There are several material circumstances that were not considered when 10 CFR 50.82(a)(8)(i) and (ii) were adopted that would weigh in favor of granting the requested exemptions from those regulations. At the time the NRC promulgated the rule, NRC regulations did not require, and have never since required, the development of site-specific DCEs prior to the last five years of the operating life of the plant, but instead, it assumed that such estimates would be developed at around the time a plant ceases operation. See 10 CFR § 50.75(f)(2). Although there may be an understandable preference for preserving funds in the DTFs in the absence of site-specific decommissioning activity and cost information, a detailed site-specific DCE provides the NRC with the ability to determine whether there is reasonable assurance that sufficient funds will be available at the time of decommissioning. Here, the information provided in the site-specific DCE and cash flow analyses included as Attachments 1, 2 and 3 support a reasonable assurance determination and the granting of the requested exemptions.

IV.

ENVIRONMENTAL ASSESSMENT The proposed exemptions meet the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(25), because the proposed exemptions involve: (1) no significant hazards consideration; (2) no significant change in the types or significant increase in the amounts of any effluents that may be released offsite; (3) no significant increase in individual or cumulative public or occupational radiation exposure; (4) no significant construction impact; (5) no significant increase in the potential for or consequences from radiological accidents; and (6) the requirements involve surety, insurance or indemnity requirements or other requirements of an administrative nature. Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed exemptions.

A. No Significant Hazards Consideration Determination For the reasons discussed below, Entergy Operations, Inc. (EOI) concludes that the requested exemptions do not present any significant hazards, and therefore, consistent with 10 CFR 50.92, a finding of "no significant hazards consideration" is warranted.

1. The requested exemptions do not involve a significant increase in the probability or consequences of an accident previously evaluated.

The proposed exemptions would allow EOI to withdraw funds from the Arkansas Nuclear One (ANO) Unit 1 and Unit 2 nuclear decommissioning trust funds (DTF) to dispose of retired Major Radioactive Components (MRCs). The requested exemptions have no effect on plant structures, systems, and components (SSCs) and no effect on the capability of any plant SSC to perform its design function. The proposed exemptions would not increase the likelihood of the malfunction of any plant SSC. The proposed exemptions would have no effect on any of the previously evaluated accidents in the Unit 1 or Unit 2 Updated Safety Analysis Reports. Use of DTFs as contemplated under the exemptions will not affect the probability of occurrence of any previously analyzed accident. Therefore, the requested exemptions do not involve a significant increase in the probability or consequences of an accident previously evaluated.

CNRO2024-00026 Enclosure Page 7 of 12

2. The requested exemptions do not create the possibility of a new or different kind of accident from any accident previously evaluated.

The proposed exemptions do not involve a physical alteration of the plant. No new or different type of equipment will be installed, and there are no physical modifications to existing equipment associated with the proposed exemptions. Similarly, the proposed exemptions will not physically change any SSCs involved in the mitigation of any accidents.

Thus, no new initiators or precursors of a new or different kind of accident are created.

Furthermore, the proposed exemptions do not create the possibility of a new accident as a result of new failure modes associated with any equipment or personnel failures. No changes are being made to parameters within which the Units are normally operated, or in the setpoints which initiate protective or mitigative actions, and no new failure modes are being introduced. Therefore, the proposed exemptions do not create the possibility of a new or different kind of accident from any accident previously evaluated.

3. The requested exemptions do not involve a significant reduction in a margin of safety.

The requested exemptions do not alter the design basis or any safety limits for the plant.

The proposed exemptions do not impact station operation or any plant SSC that is relied upon for accident mitigation. Therefore, they do not involve a significant reduction in a margin of safety.

For the reasons discussed above, EOI concludes that the proposed exemptions present no significant hazards consideration, and, accordingly, a finding of "no significant hazards consideration" is justified.

B. There is no significant change in the types or significant increase in the amounts of any effluents that may be released offsite.

There are no changes in the types, characteristics, or quantities of effluents discharged to the environment associated with the requested exemptions. There are no materials or chemicals introduced into the Units that could affect the characteristics or types of effluents released offsite. In addition, the method of operation of waste processing systems will not be affected by the exemptions. The proposed exemptions will not result in changes to the design basis requirements of SSCs that function to limit or monitor the release of effluents. All the SSCs associated with limiting the release of effluents will continue to be able to perform their functions. Therefore, the proposed exemptions will not result in any significant change to the types or significant increase in the amounts of any effluents that may be released offsite.

C. There is no significant increase in individual or cumulative public or occupational radiation exposure.

The proposed exemptions do not involve any physical alterations to the plant configuration of either Unit or any changes to the operation of the Units that could lead to a significant increase in individual or cumulative occupational radiation exposure.

D. There is no significant construction impact.

No construction activities are associated with the proposed exemptions.

E. There is no significant increase in the potential for or consequences from radiological accidents.

See the no significant hazards considerations discussion in Section IV.A above.

CNRO2024-00026 Enclosure Page 8 of 12 F. The requirements from which the exemptions are sought involve surety, insurance or indemnity requirements or other requirements of an administrative nature.

The underlying purpose of the requirements from which the exemptions are sought is to provide reasonable assurance that adequate funds will be available for decommissioning, which is administrative in nature.

Accordingly, the requested exemptions meet the eligibility criterion for categorical exclusion, and therefore, the preparation of an environmental impact statement or environmental assessment is not required in this case.

V.

EXTRAORDINARY CIRCUMSTANCES JUSTIFY GRANTING THE REQUESTED EXEMPTIONS Consistent with the ISG, EOI is providing the following additional information to demonstrate the existence of extraordinary circumstances that support granting the requested exemptions.4 A. The exemption request meets the requirements for specific exemptions.

As discussed in Section III above, EOIs exemption request satisfies the requirements for specific exemptions, as set forth in 10 CFR 50.12(a)(1).

B. There will be large projected surpluses in the Unit 1 and Unit 2 DTFs for license termination costs compared with the site-specific DCEs.

As of June 30, 2024, the Unit 1 DTF had a market value of approximately $833.9 million, and the Unit 2 DTF had a market value of approximately $688.6 million. Annual cash flow analyses for Unit 1 and Unit 2 are provided at Attachments 2 and 3, respectively, and are based on the site-specific DCE provided at Attachment 1. The cash flow analyses assume that EOI withdraws up to $20 million from each of the Unit 1 and Unit 2 DTFs to fund the MRC disposal.

They further assume that major decommissioning activities begin at Unit 1 in 2034 and at Unit 2 in 2038, based on a DECON scenario and an assumption that both Units permanently cease operations at the end of their current period of extended operation. Please note that EOI used these assumptions for conservatism in the cash flow analyses; they do not reflect actual business or operational decisions regarding the decommissioning approach or whether EOI will seek to further extend the Unit 1 and Unit 2 operating licenses, as those decisions have not yet been made. The cash flow analyses also assume that DTF withdrawals are limited to license termination costs. Although it is possible that EOI may request additional exemptions in the future that would allow the use of the DTFs for spent fuel management and/or site restoration activities, EOI has not made any decisions on whether to seek such exemptions at this time.

For each Unit, a large surplus is projected to exist when decommissioning is completed, and adequate decommissioning funding assurance is maintained throughout decommissioning.

Specifically, the Unit 1 DTF is projected to have a surplus of approximately $612 million, and the Unit 2 DTF is projected to have a surplus of approximately $294 million in 2084, when decommissioning is completed (considering only license termination expenditures).

4 SeeISGat4.

CNRO2024-00026 Enclosure Page 9 of 12 C. The site-specific DCE includes the cost of disposing the MRCs described in this exemption request.

As noted in Section I above, the requested exemptions would permit EOI to use the ANO DTFs for the prompt disposal of the following retired MRCs:

Unit 1 - Two steam generators and one RVCH that were removed from service in 2005.

Unit 2 - Two steam generators that were removed from service in 2000.

The site-specific DCE (Attachment 1) includes the following line items related to these MRCs:

DCE Table Activity Index Activity Description Total License Termination Cost Table C-1 2a.1.1.6 Retired Steam Generator Units

$9.582 million Table C-1 2a.2.2 Retired Reactor Closure Head

$3.964 million Table C-2 2a.1.1.6 Retired Steam Generator Units

$14.443 million D. Funds in the Unit 1 and Unit 2 DTFs were collected for the disposal of retired MRCs.

The funds in the Unit 1 and Unit 2 DTFs were collected to cover all of the license termination decommissioning activities that are described in the site-specific DCE, including the disposal of the retired MRCs described in this exemption request. In APSC Docket No. 87-166-TF, the APSC issues periodic orders authorizing Entergy Arkansas, LLC, the licensed owner of ANO Units 1 and 2, to collect ratepayer funds to ensure the DTFs are properly funded to pay for decommissioning costs, which include disposal of the retired MRCs at issue. Funds for both Units 1 and 2 were collected from ratepayers through 2001. Additional collections for the Unit 2 DTF were initiated in 2016, with periodic additional collections through year-end 2024.

E. The time period between plant shutdown and the commencement of major radiological decommissioning activities is sufficient to allow accumulation of decommissioning trust funds.

The cash flow analyses provided in Attachments 2 and 3 conservatively assume for purposes of this exemption request that plant shutdown and the commencement of major decommissioning activities will both occur in 2034 for Unit 1 and in 2038 for Unit 2. Although the funding analyses assume that there effectively will be no time for the accumulation of funds in the DTFs between permanent cessation of operations and the commencement of decommissioning, as discussed in Section V.B above, the Unit 1 and Unit 2 DTFs are nonetheless projected to have surpluses at license termination - approximately $612 million in the Unit 1 DTF and approximately $294 million in the Unit 2 DTF - after the MRC disposal costs are withdrawn from the DTFs in 2025.

If EOI were to apply for, and the NRC were to approve, subsequent license renewal of the Unit 1 and Unit 2 operating licenses, those margins would increase substantially.

F. The current and projected DTF amounts required for decommissioning provide adequate assurance that funds will be available throughout the decommissioning period.

As discussed in Sections V.B and E above, and as demonstrated in the cash flow analyses provided in Attachments 2 and 3, the current and projected DTF amounts for both Unit 1 and Unit 2 provide adequate assurance that sufficient funds will be available throughout the decommissioning period and that surpluses are projected to remain in both DTFs after license termination activities have been completed.

CNRO2024-00026 Enclosure Page 10 of 12 G. Funds for different decommissioning activities are commingled within the ANO DTFs.

For both the Unit 1 and Unit 2 DTFs, the APSC authorized the collection of funds to cover expected radiological decommissioning and spent fuel management costs during plant operations, as well as site restoration costs. The funds collected for those activities are not segregated into separate subaccounts within the respective DTFs; rather, they are commingled in one account within the respective DTFs. Because the funds collected for different decommissioning activities are commingled and not reported separately to the NRC, they are considered funds to be used only for radiological decommissioning for NRC purposes.

H. The ANO DTFs have historically demonstrated excess funding compared to the NRC minimum formula amount.

As shown in the table below, the Unit 1 DTF amount has consistently have exceeded the minimum formula amounts from 10 CFR 50.75(b) and (c), without taking any credit for future earnings. The Unit 1 DTF balance of approximately $834 million (as of June 30, 2024) exceeds the most recently calculated minimum formula amount (as of December 31, 2022) by $304 million. Moreover, the Unit 1 DTF has continued to exceed the NRC minimum formula amount despite the fact that the formula amount increased dramatically from 2021 to 2023, due to an increase in the pressurized water reactor ("PWR") escalation factor from 4.9 to 5.43. This is due to the increased Labor and Energy factors from the Bureau of Labor Statistics and the increased Waste Burial factor from NUREG-1307.

The Unit 2 DTF amount has at times fluctuated above and below the minimum formula amounts when no credit is taken for future earnings, and any apparent deficiencies were corrected by the resumption of ratepayer collections in 2016 for decommissioning. This track record demonstrates EOIs ability and commitment to ensure that the DTF is sufficiently funded.5 The Unit 2 DTF amount compares favorably to the minimum formula amount despite the dramatic increase in the PWR escalation factor from 2021 to 2023, as described above. The Unit 2 DTF balance of approximately $689 million (as of June 30, 2024) is well above the minimum formula of $552M reported in EOIs most recent 10 CFR 50.75(f) filing.

Date (ML Number of Associated DTF Status Report)

Unit 1 Unit 2 Fund Value

($M)

Minimum Formula Amount ($M)

Fund Value

($M)

Minimum Formula Amount ($M) 12/31/2022 (ML23080A288)

$659

$530

$541

$552 12/31/2020 (ML21084A809)

$702

$478

$572

$498 12/31/2018 (ML19087A327)

$506

$472

$405

$492 12/31/2016 (ML17093A933)

$466

$450

$368

$469 5 Given that EOI has prepared a comprehensive site-specific DCE for ANO (Attachment 1), and the annual cash flow analyses (at Attachments 2 and 3) demonstrate that each Units DTF will have a surplus at the completion of license termination activities, arguably, the cash flow analyses present the more relevant comparison for purposes of this exemption request.

CNRO2024-00026 Enclosure Page 11 of 12 I.

The benefits of using the DTFs for near-term MRC disposal outweigh any potential costs.

As discussed above, because there is insufficient space in either of the existing mausoleums to store the soon-to-be-retired Unit 2 RVCH, EOI must either (1) construct a new storage facility; or (2) dispose of the MRCs that were retired in 2000 and 2005 to create sufficient storage space, at a cost approaching $20 million per Unit. Under the first scenario, EOI must expend $2.2 million to construct a new storage facility, plus additional funds to maintain the facility, and then to ultimately decommission the facility once the MRCs have been sent offsite for disposal. The benefit of using the DTFs for the near-term disposal of the MRCs is the avoidance of these incremental costs.

Under the second scenario, in the absence of the requested exemption, EOI would be required to use operating revenues for the near-term disposal of the MRCs, rather than using the funds that were collected from ratepayers to pay for decommissioning, which includes the disposal of the retired MRCs, as authorized by the APSC. The benefit of using the DTFs for near-term disposal of the MRCs is the realization of the intended purpose of the decommissioning funds that were collected from the ratepayers.

In addition to these benefits, prompt disposal of the MRCs will also result in reduced inventory of radioactive waste and associated source term at the ANO site and elimination of any uncertainty regarding future disposal cost and capacity for these MRCs. In that regard, EOI has obtained a third-party proposal and cost estimate to remove, transport, and dispose of the MRCs beginning in 2025. Therefore, EOI has relative cost certainty for this near-term effort.

EOI would not have comparable cost certainty for the same services a decade or more from now, when decommissioning is anticipated to begin.

J. The financial health of EOIs parent company is robust.

Entergy Corporation (Entergy) is the ultimate parent company of EOI. Entergy is a Fortune 500 company with approximately 3 million customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy is headquartered in New Orleans, Louisiana, and has approximately 12,000 employees. For the fiscal year ending December 31, 2023, Entergy reported $12.1 billion in revenues, $2.4 billion in net income, and $59.7 billion in assets.6 Entergy had a market value of approximately $31 billion as of November 1, 2024.

K. In the event of a funding shortfall, rate collection mechanisms are available to obtain additional funds for decommissioning.

As discussed in Section V.D above, the APSC authorizes Entergy Arkansas to collect ratepayer funds to ensure that the DTFs are properly funded for the purpose of decommissioning both Units. Funds for both Units 1 and 2 were collected from ratepayers through 2001, and additional collections for the Unit 2 DTF were initiated in 2016, with periodic additional collections through year-end 2024. EOI and Entergy Arkansas periodically review and update the ANO site-specific DCE to reflect inflation and changes in regulatory requirements and technology, and filings are made annually with the APSC to consider the need for adjusted decommissioning funding. If a funding shortfall were projected, Entergy Arkansas would take 6

"EntergyCorporationAnnualReportPursuanttoSection13or15(d)oftheSecuritiesExchangeActof1934for theFiscalYearEndedDecember31,2023,"Form10K,availableat:ETR-12.31.2023-10K

CNRO2024-00026 Enclosure Page 12 of 12 the necessary steps to seek APSC approval to collect additional funds to cover the anticipated decommissioning costs.

VI.

CONCLUSION For the reasons discussed above, EOI respectfully requests that the NRC approve the requested exemptions and allow EOI to use a small portion of the ANO Unit 1 and Unit 2 DTFs for the near-term disposal of certain retired MRCs. The requested exemptions are authorized by law, will not present an undue risk to the public health and safety, are consistent with the common defense and security, and special circumstances are present as set forth in 10 CFR 50.12(a)(2)(ii) and (iii). Moreover, extraordinary circumstances exist that justify granting the requested exemptions.

VII.

ATTACHMENTS

1. Decommissioning Cost Analysis for Arkansas Nuclear One

2. Arkansas Nuclear One Unit 1 - DECON Methodology, Annual Cash Flow Analysis - Total License Termination Costs

3. Arkansas Nuclear One Unit 2 - DECON Methodology, Annual Cash Flow Analysis - Total License Termination Costs

Enclosure, Attachment 1 CNRO2024-00026 Decommissioning Cost Analysis for Arkansas Nuclear One (177 Pages)

Document E11-1828-001, Rev. 0 DECOMMISSIONING COST ANALYSIS for the ARKANSAS NUCLEAR ONE, UNITS 1 and 2 prepared for Entergy Arkansas, LLC prepared by TLG Services, LLC Bridgewater, Connecticut March 2024

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page ii of xx TLG Services, LLC APPROVALS Project Manager Adam M. Kaczmarek Date Project Engineer Amara M.A. Falotico Date Technical Manager Lori A. Glander Date Adam M. Kaczmarek 03/21/2024 03/21/2024 03/21/2024

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page iii of xx TLG Services, LLC TABLE OF CONTENTS SECTION PAGE EXECUTIVE

SUMMARY

.................................................................................... vii-xx

1.

INTRODUCTION..................................................................................................... 1-1 1.1 Objectives of Study........................................................................................... 1-1 1.2 Site Description................................................................................................. 1-2 1.3 Regulatory Guidance........................................................................................ 1-3 1.3.1 High-Level Radioactive Waste Management...................................... 1-5 1.3.2 Low-Level Radioactive Waste Management....................................... 1-9 1.3.3 Radiological Criteria for License Termination................................. 1-10

2.

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

3.

COST ESTIMATES.................................................................................................. 3-1 3.1 Basis of Estimates............................................................................................ 3-1 3.2 Methodology...................................................................................................... 3-1 3.3 Impact of Decommissioning Multiple Reactor Units..................................... 3-3 3.4 Financial Components of the Cost Model....................................................... 3-4 3.4.1 Contingency........................................................................................... 3-4 3.4.2 Financial Risk........................................................................................ 3-6 3.5 Site-Specific Considerations............................................................................ 3-7 3.5.1 Spent Fuel Management...................................................................... 3-7 3.5.2 Reactor Vessel and Internal Components......................................... 3-11 3.5.3 Primary System Components............................................................. 3-12 3.5.4 Retired Components............................................................................ 3-13 3.5.5 Main Turbine and Condenser............................................................ 3-13

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page iv of xx TLG Services, LLC TABLE OF CONTENTS (continued)

SECTION PAGE 3.5.6 Transportation Methods..................................................................... 3-13 3.5.7 Low-Level Radioactive Waste Disposal............................................. 3-14 3.5.8 Site Conditions Following Decommissioning.................................... 3-15 3.6 Assumptions.................................................................................................... 3-16 3.6.1 Estimating Basis................................................................................. 3-16 3.6.2 Labor Costs.......................................................................................... 3-17 3.6.3 Design Conditions............................................................................... 3-18 3.6.4 General................................................................................................. 3-18 3.7 Cost Estimate Summary............................................................................... 3-21

4.

SCHEDULE ESTIMATE........................................................................................ 4-1 4.1 Schedule Estimate Assumptions..................................................................... 4-1 4.2 Project Schedule................................................................................................ 4-2

5. RADIOACTIVE WASTES........................................................................................ 5-1

6.

RESULTS.............................................................................................................. 6-1

7.

REFERENCES.......................................................................................................... 7-1 TABLES DECON Cost Summary, Decommissioning Cost Elements........................... xix SAFSTOR Cost Summary, Decommissioning Cost Elements........................ xx 3.1 ANO-1, DECON Alternative, Total Annual Expenditures.......................... 3-23 3.1a ANO-1, DECON Alternative, License Termination Expenditures.............. 3-25 3.1b ANO-1, DECON Alternative, Spent Fuel Management Expenditures....... 3-26 3.1c ANO-1, DECON Alternative, Site Restoration Expenditures..................... 3-28 3.2 ANO-2, DECON Alternative, Total Annual Expenditures.......................... 3-29 3.2a ANO-2, DECON Alternative, License Termination Expenditures.............. 3-31 3.2b ANO-2, DECON Alternative, Spent Fuel Management Expenditures....... 3-32 3.2c ANO-2, DECON Alternative, Site Restoration Expenditures..................... 3-34 3.3 ANO-1, SAFSTOR Alternative, Total Annual Expenditures....................... 3-35 3.3a ANO-1, SAFSTOR Alternative, License Termination Expenditures.......... 3-38 3.3b ANO-1, SAFSTOR Alternative, Spent Fuel Management Expenditures.... 3-41 3.3c ANO-1, SAFSTOR Alternative, Site Restoration Expenditures.................. 3-43

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page v of xx TLG Services, LLC TABLE OF CONTENTS (continued)

SECTION PAGE TABLES (continued) 3.4 ANO-2, SAFSTOR Alternative, Total Annual Expenditures....................... 3-44 3.4a ANO-2, SAFSTOR Alternative, License Termination Expenditures.......... 3-46 3.4b ANO-2, SAFSTOR Alternative, Spent Fuel Management Expenditures.... 3-48 3.4c ANO-2, SAFSTOR Alternative, Site Restoration Expenditures.................. 3-50 5.1 DECON Alternative, Decommissioning Waste Summary............................. 5-5 5.2 SAFSTOR Alternative, Decommissioning Waste Summary.......................... 5-6 6.1 DECON Alternative, Decommissioning Cost Elements................................. 6-4 6.2 SAFSTOR Alternative, Decommissioning Cost Elements............................. 6-5 FIGURES 3.1 Decommissioning Personnel Levels, DECON............................................... 3-51 3.2 Decommissioning Personnel Levels, SAFSTOR........................................... 3-52 4.1 Activity Schedule.............................................................................................. 4-3 4.2 Decommissioning Timeline, DECON.............................................................. 4-6 4.3 Decommissioning Timeline, SAFSTOR.......................................................... 4-7 5.1 Radioactive Waste Disposition........................................................................ 5-3 5.2 Decommissioning Waste Destinations, Radiological...................................... 5-4 APPENDICES A.

Unit Cost Factor Development............................................................................. A-1 B.

Unit Cost Factor Listing...................................................................................... B-1 C.

Detailed Cost Analysis, DECON.......................................................................... C-1 D.

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

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page vi of xx TLG Services, LLC REVISION LOG No.

Date Item Revised Reason for Revision 0

03-21-2024 Original Issue

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page vii of xx TLG Services, LLC EXECUTIVE

SUMMARY

This report presents estimates of the cost to decommission Arkansas Nuclear One (ANO) for the selected decommissioning alternatives following the scheduled and permanent cessation of plant operations. The estimates are designed to provide the owner, Entergy Arkansas, LLC (EAL), with the information to assess its current decommissioning liability, as it relates to ANO.

The analysis relies upon site-specific, technical information from an evaluation prepared in 2019,[1] updated to reflect current plant inventory, current assumptions pertaining to the operating life of the reactor, disposition of the nuclear plant and relevant industry experience in undertaking such projects. The costs are based on several key assumptions in areas of regulation, component characterization, high-level radioactive waste management, low-level radioactive waste disposal, performance uncertainties (contingency) and site restoration requirements.

The analysis is not a detailed engineering evaluation, but estimates prepared in advance of the detailed engineering required to carry out the decommissioning of the nuclear units. It may also not reflect the actual plan to decommission ANO; the plan may differ from the assumptions made in this analysis based on facts that exist at the time of decommissioning.

The 2019 plant inventory, the basis for the decontamination and dismantling requirements and cost, and the decommissioning waste streams, were reviewed for this analysis. There were no substantive changes made to the plant inventory (that would impact decommissioning), except for removal of the retired Engineering building.

The costs to decommission ANO for the alternatives evaluated are tabulated at the end of this section. Costs are reported in 2024 dollars and include monies anticipated to be spent for radiological remediation and operating license termination, spent fuel management, and site restoration activities.

A complete discussion of the assumptions relied upon in this analysis is provided in Section 3, along with schedules of annual expenditures for each scenario. A sequence of significant project activities is provided in Section 4 with a timeline for each scenario.

Detailed cost reports used to generate the summary tables contained within this document are provided in Appendices C and D.

1 Decommissioning Cost Analysis for the Arkansas Nuclear One, Units 1 and 2, Document E11-1763-001, Rev. 0, TLG Services, Inc., March 2019

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page viii of xx TLG Services, LLC Consistent with the 2019 analysis, the current cost estimates assume that the shutdown of the nuclear units is a scheduled and pre-planned event (e.g., there is no delay in transitioning the plant and workforce from operations or in obtaining regulatory relief from operating requirements). The estimates include the continued operation of the auxiliary buildings as interim wet fuel storage facilities for approximately five and one-half years after operations cease. During this time period, it is assumed that the spent fuel residing in the pools that cannot be transferred to the Department of Energy (DOE) will be transferred to an independent spent fuel storage installation (ISFSI) located on the site.

The ISFSI will remain operational until the DOE is able to complete the transfer of the fuel to a federal facility (e.g., a monitored retrievable storage facility).[2] DOE has breached its obligations to remove fuel from reactor sites, and has also failed to provide the plant owners with information about how it will ultimately perform. DOE officials have stated that DOE does not have an obligation to accept already-canistered fuel without an amendment to DOEs contracts with plant licensees to remove the fuel (the Standard Contract), but DOE has not explained what any such amendment would involve. Consequently, the plant owner has no information or expectations on how DOE will remove fuel from the site in the future. In the absence of information about how DOE will perform, and for purposes of this analysis only, it is assumed that DOE will accept already-canistered fuel (it is recognized that the canisters may not be licensed or licensable for transportation when DOE performs).

If this assumption is incorrect, it is assumed that DOE will have liability for costs incurred to transfer the fuel to DOE-supplied containers.

Alternatives and Regulations The Nuclear Regulatory Commission (NRC) provided general decommissioning requirements in a rule adopted on June 27, 1988.[3] In this rule, the NRC set forth technical and financial criteria for decommissioning licensed nuclear facilities. The regulations addressed planning needs, timing, funding methods, and environmental review requirements for decommissioning. The rule also defined three decommissioning alternatives as being acceptable to the NRC: DECON, SAFSTOR, and ENTOMB.

DECON is defined as "the alternative in which the equipment, structures, and portions of a facility and site containing radioactive contaminants are 2

Projected expenditures for spent fuel management identified in the cost analyses do not consider the outcome of the litigation with the DOE with regard to the delays incurred by Entergy in the timely removal of spent fuel from the site.

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page ix of xx TLG Services, LLC removed or decontaminated to a level that permits the property to be released for unrestricted use shortly after cessation of operations."[4]

SAFSTOR is defined as "the alternative in which the nuclear facility is placed and maintained in a condition that allows the nuclear facility to be safely stored and subsequently decontaminated (deferred decontamination) to levels that permit release for unrestricted use."[5]

Decommissioning is required to be completed within 60 years, although longer time periods will be considered when necessary to protect public health and safety.

ENTOMB is defined as "the alternative in which radioactive contaminants are encased in a structurally long-lived material, such as concrete; the entombed structure is appropriately maintained and continued surveillance is carried out until the radioactive material decays to a level permitting unrestricted release of the property."[6] As with the SAFSTOR alternative, decommissioning is currently required to be completed within 60 years, although longer time periods will also be considered when necessary to protect public health and safety.

The 60-year restriction has limited the practicality for the ENTOMB alternative at commercial reactors that generate significant amounts of long-lived radioactive material. In 2017, the NRCs staff issued the regulatory basis for proposed new regulations on the decommissioning of commercial nuclear power reactors. In the regulatory basis, the NRC staff proposed removing any discussion of the ENTOMB option from existing guidance documents since the method is not deemed practically feasible for current U.S. power reactors, and the timeframe for decommissioning completion using the ENTOMB method is generally inconsistent with current regulations.[7] Additionally, the Arkansas Public Service Commission Settlement agreement associated with the 2019 DCE filing[8]

no longer requires the ENTOMB alternative to be considered for ANO 4

Ibid. Page FR24022, Column 3 5

Ibid.

6 Ibid. Page FR24023, Column 2 7 Regulatory Improvement for Power Reactors Transitioning to Decommissioning, NRC Regulatory Basis Document, Docket ID NRC-2015-0070, RIN Number 3150-AJ59, November 20, 2017 8 Arkansas Public Service Commission Settlement Agreement, filed 10/9/2019, Docket No. 87-166-TF, Order No. 69

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page x of xx TLG Services, LLC decommissioning cost estimates. Therefore, the analysis contained within this report will no longer address the ENTOMB option.

In 1996, the NRC published revisions to its general requirements for decommissioning nuclear power plants to clarify ambiguities and codify procedures and terminology as a means of enhancing efficiency and uniformity in the decommissioning process.[9] 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, (as revised in October 2013), further described the methods and procedures that are acceptable to the NRC staff for implementing the requirements of the 1996 revised rule that relate to the initial activities and the major phases of the decommissioning process. The costs and schedules presented in this analysis follow the general guidance and sequence in the amended regulations. The format and content of the estimates is also consistent with the recommendations of Regulatory Guide 1.202, issued in February 2005.[10]

In 2011, the NRC issued regulations to improve decommissioning planning and thereby reduce the likelihood that any current operating facility will become a legacy site.[11]

The regulations require licensees to report additional details in their decommissioning cost estimate, including a decommissioning estimate for the ISFSI. This estimate is provided in Appendix E.

Decommissioning Scenarios Two decommissioning scenarios were evaluated for the two ANO nuclear units. The scenarios selected are representative of alternatives currently available to the owner and are defined as follows:

1.

The first scenario assumes that the two units would be promptly decommissioned (DECON alternative) upon the expiration of the current operating licenses, i.e., 2034 and 2038 for Units 1 and 2, respectively.

2.

In the second scenario, the nuclear units are placed into safe-storage (SAFSTOR alternative) at the end of their current operating licenses.

Decommissioning is deferred to the maximum extent such that the licenses are 9

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 10 Standard Format and Content of Decommissioning Cost Estimates for Nuclear Power Reactors, Regulatory Guide 1.202, Nuclear Regulatory Commission, February 2005 11 U.S. Code of Federal Regulations, Title 10, Parts 20, 30, 40, 50, 70, and 72, "Decommissioning Planning," Nuclear Regulatory Commission, Federal Register Volume 76, (p 35512 et seq.), June 17, 2011

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page xi of xx TLG Services, LLC terminated within the required 60-year period.

Methodology The methodology used to develop the estimates follows the basic approach originally presented in the cost estimating guidelines[12] developed by the Atomic Industrial Forum (now Nuclear Energy Institute). This reference describes a unit cost factor method for estimating decommissioning activity costs. The unit cost factors used in this analysis incorporate site-specific costs and the latest available information about worker productivity in decommissioning.

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

The estimates also reflect lessons learned from 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 Rancho Seco, Trojan, Yankee Rowe, Big Rock Point, Maine Yankee, Humboldt Bay-3, Oyster Creek, Connecticut Yankee, Crystal River, Vermont Yankee, Fort Calhoun, Pilgrim, and Indian Point nuclear units have provided additional insight into the process, the regulatory aspects, and the technical challenges of decommissioning commercial nuclear units.

Contingency Consistent with cost estimating practice, contingencies are applied to the decontamination and dismantling costs developed as "specific provision for unforeseeable elements of cost within the defined project scope, particularly important where previous experience relating estimates and actual costs has shown that unforeseeable events which will increase costs are likely to occur.[13] The cost elements in the estimates are based on ideal conditions; therefore, the types of unforeseeable events that are almost certain to occur in decommissioning, based on industry experience, are addressed through a percentage contingency applied on a line-item basis. This contingency factor is a nearly universal element in all large-scale construction and demolition projects. It should be noted that contingency, as used in 12 T.S. LaGuardia et al., "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates," AIF/NESP-036, May 1986 13 Project and Cost Engineers Handbook, Second Edition, American Association of Cost Engineers, Marcel Dekker, Inc., New York, New York, p. 239.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page xii of xx TLG Services, LLC this analysis, does not account for price escalation and inflation in the cost of decommissioning over the remaining operating life of the station.

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

Low-Level Radioactive Waste Management The contaminated and activated material generated in the decontamination and dismantling of a commercial nuclear reactor is generally classified as low-level radioactive waste, although not all of the material is suitable for shallow-land disposal.

With the passage of the Low-Level Radioactive Waste Disposal Act in 1980 and its Amendments of 1985,[14] the states became ultimately responsible for the disposition of low-level radioactive waste generated within their own borders.

With the exception of Texas, no new compact facilities have been successfully sited, licensed, and constructed. The Texas Compact disposal facility is now operational and waste is being accepted from generators within the Compact by the operator, Waste Control Specialists (WCS). The facility is also able to accept limited volumes of non-Compact waste.

The various waste streams produced by the decommissioning process considered all options and services currently available to Entergy. The majority of the low-level radioactive waste designated for direct disposal (Class A[15]) can be sent to EnergySolutions facility in Clive, Utah. Therefore, disposal costs for Class A waste were based upon Entergys Life of Plant Agreement and other service agreements with EnergySolutions. This facility is not licensed to receive the higher activity portion (Classes B and C) of the decommissioning waste stream.

The WCS facility is able to receive the Class B and C waste. As such, for this analysis, Class B and C waste was assumed to be shipped to the WCS facility and disposal costs for the waste were based upon Entergys most current agreement with WCS.

The dismantling of the components residing closest to the reactor core generates radioactive waste that may be considered unsuitable for shallow-land disposal (i.e.,

low-level radioactive waste with concentrations of radionuclides that exceed the limits established by the NRC for Class C radioactive waste (GTCC)). The Low-Level Radioactive Waste Policy Amendments Act of 1985 assigned the federal government 14 Low-Level Radioactive Waste Policy Amendments Act of 1985, Public Law 99-240, January 15, 1986 15 Waste is classified in accordance with U.S. Code of Federal Regulations, Title 10, Part 61.55

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page xiii of xx TLG Services, LLC the responsibility for the disposal of this material. The Act also stated that the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste. However, to date, the federal government has not identified a cost, if any, for GTCC disposal or a schedule for acceptance.

For purposes of this analysis only, the GTCC radioactive waste is assumed to be packaged and disposed of in a manner similar to high-level waste and at a cost equivalent to that envisioned for the spent fuel. The GTCC is packaged in the same canisters used for spent fuel and either stored on site or shipped directly to a federal facility as it is generated (depending upon the timing of the decommissioning and whether the spent fuel has already been removed from the site prior to the start of decommissioning).

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

High-Level Radioactive Waste Management Congress passed the Nuclear Waste Policy Act (NWPA) in 1982, assigning the federal governments long-standing responsibility for disposal of the spent nuclear fuel created by the commercial nuclear generating plants to the DOE. The DOE was to begin accepting spent fuel by January 31, 1998; however, to date no progress in the removal of spent fuel from commercial generating sites has been made.

Completion of the decommissioning process is dependent upon the DOEs ability to remove spent fuel from the site in a timely manner. DOEs repository program assumes that spent fuel allocations will be accepted for disposal from the nations commercial nuclear plants, with limited exceptions, in the order (the queue) in which it was discharged from the reactor.[16] Entergys current spent fuel 16 In 2008, the DOE issued a report to Congress in which it concluded that it did not have authority, under present law, to accept spent nuclear fuel for interim storage from decommissioned commercial nuclear power reactor sites. However, the Blue Ribbon Commission, in its final report, noted that:

[A]ccepting spent fuel according to the OFF [Oldest Fuel First] priority ranking instead of giving priority to shutdown reactor sites could greatly reduce the cost savings that could be achieved through consolidated storage if priority could be given to accepting spent fuel from

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page xiv of xx TLG Services, LLC management plan for the ANO spent fuel is based in general upon: 1) a 2035 start date for DOE initiating transfer of commercial spent fuel from the industry to a federal facility (not necessarily a final repository), and 2) an assumed schedule for spent fuel receipt by the DOE for the ANO fuel. The DOEs generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. Assuming a maximum rate of transfer of 3,000 metric tons of uranium (MTU)/year,[17] the removal of spent fuel from the site could be completed in 2083. Different DOE acceptance schedules may result in different completion dates.

Today, the country is at an impasse on high-level waste disposal, despite DOEs submittal of its License Application for a geologic repository to the NRC in 2008. The Obama administration eliminated the budget for the repository program while promising to conduct a comprehensive review of policies for managing the back end of the nuclear fuel cycle and make recommendations for a new plan.[18] Towards this goal, the Obama administration appointed a Blue Ribbon Commission on Americas Nuclear Future (Blue Ribbon Commission) to make recommendations for a new plan for nuclear waste disposal. The Blue Ribbon Commissions charter included a requirement that it consider [o]ptions for safe storage of used nuclear fuel while final disposition pathways are selected and deployed.[19]

On January 26, 2012, the Blue Ribbon Commission issued its Report to the Secretary of Energy containing a number of recommendations on nuclear waste disposal. Two of the recommendations that may impact decommissioning planning are:

• [T]he United States [should] establish a program that leads to the timely development of one or more consolidated storage facilities[20]

• [T]he United States should undertake an integrated nuclear waste management program that leads to the timely development of one or more shutdown reactor sites before accepting fuel from still-operating plants.. The magnitude of the cost savings that could be achieved by giving priority to shutdown sites appears to be large enough (i.e., in the billions of dollars) to warrant DOE exercising its right under the Standard Contract to move this fuel first. For planning purposes only, this estimate does not assume that ANO, as permanently shutdown units, will receive priority; the fuel removal schedule assumed in this estimate is based upon DOE acceptance of fuel according to the Oldest Fuel First priority ranking. The plant owner will seek the most expeditious means of removing fuel from the site when DOE commences performance.

17 Acceptance Priority Ranking & Annual Capacity Report, DOE/RW-0567, July 2004 18 Advisory Committee Charter, Blue Ribbon Commission on Americas Nuclear Future, Appendix A, January 2012 19 Ibid.

20 Blue Ribbon Commission on Americas Nuclear Future, Report to the Secretary of Energy, p.

32, January 2012

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page xv of xx TLG Services, LLC permanent deep geological facilities for the safe disposal of spent fuel and high-level nuclear waste.[21]

In January 2013, the DOE issued the Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste, in response to the recommendations made by the Blue Ribbon Commission and as a framework for moving toward a sustainable program to deploy an integrated system capable of transporting, storing, and disposing of used nuclear fuel...[22]

With the appropriate authorizations from Congress, the Administration currently plans to implement a program over the next 10 years that:

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

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

• Makes demonstrable progress on the siting and characterization of repository sites to facilitate the availability of a geologic repository by 2048.[23]

The NRCs review of DOEs license application to construct a geologic repository at Yucca Mountain was suspended in 2011 when the Obama administration significantly reduced the budget for completing that work. However, the US Court of Appeals for the District of Columbia Circuit issued a writ of mandamus (in August 2013)[24] ordering NRC to comply with federal law and resume its review of DOE's Yucca Mountain repository license application to the extent allowed by previously appropriated funding for the review. That review is now complete with the publication of the five-volume safety evaluation report. A supplement to DOEs environmental impact statement and adjudicatory hearing on the contentions filed by interested parties must be completed before a licensing decision can be made.

Although the DOE proposed it would start fuel acceptance in 2025, no progress has been made in the repository program since DOEs 2013 strategy was issued except for the 21 Ibid., p.27 22 Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste, U.S. DOE, January 11, 2013 23 Ibid., p.2 24 U.S. Court of Appeals for the District Of Columbia Circuit, In Re: Aiken County, et al, Aug. 2013

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page xvi of xx TLG Services, LLC completion of the Yucca Mountain safety evaluation report. Because of this continued delay, this estimate revises the assumed start date for DOE fuel acceptance from 2030, used in the 2019 evaluation, to 2035.

Holtec International submitted a license application to the NRC on March 30, 2017 for a consolidated interim spent fuel storage facility in southeast New Mexico called HI-STORE CIS (Consolidated Interim Storage) under the provisions of 10 CFR Part

72. The application was approved by the NRC on May 9, 2023.

Waste Control Specialists (WCS) submitted an application to the NRC on April 28, 2016, to construct and operate a Consolidated Interim Storage Facility (CISF) at its West Texas facility. On April 18, 2017, WCS requested that the NRC temporarily suspend all safety and environmental review activities, as well as public participation activities associated with WCSs license application. In March 2018, WCS and Orano USA, announced their intent to form a joint venture to license the facility. On September 17, 2021, the NRC approved the joint ventures original CISF license application. At this time, neither storage facility is in service and therefore has not been considered in this estimate.

On May 10, 2018, the U.S. House of Representatives passed H.R. 3053, the Nuclear Waste Policy Amendments Act of 2018. Proposed to amend the Nuclear Waste Policy Act of 1982, the legislation, if approved by the Senate and signed by the President, would provide the DOE the authority to site, construct, and operate one or more Monitored Retrieval Storage (MRS) facilities while a permanent repository is licensed and constructed and/or to enter into an MRS agreement with a non-Federal entity for temporary storage. At the time of this estimate no further action has been taken on this legislation.

The NRC requires that licensees establish a program to manage and provide funding for the caretaking of all irradiated fuel at the reactor site until title of the fuel is transferred to the DOE. [25] Interim storage of the fuel, until the DOE has completed the transfer, will be in the auxiliary buildings storage pools as well as at an on-site ISFSI.

An ISFSI, operated under a Part 50 General License (in accordance with 10 CFR 72, Subpart K[26]), has been constructed to support continued plant operations. The facility is assumed to be available to support future decommissioning operations. As such, the fuel that cannot be transferred directly to the DOE from the wet pools is packaged for interim storage at the ISFSI. Once the auxiliary buildings storage pools are emptied, 25 U.S. Code of Federal Regulations, Title 10, Part 50 - Domestic Licensing of Production and Utilization Facilities, Subpart 54 (bb), Conditions of Licenses 26 U.S. Code of Federal Regulations, Title 10, Part 72, Subpart K, General License for Storage of Spent Fuel at Power Reactor Sites.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page xvii of xx TLG Services, LLC the buildings can be either decontaminated and dismantled or prepared for long term storage.

Entergys position is that the DOE has a contractual obligation to accept the spent fuel earlier than the projections set out above consistent with its contract commitments. No assumption made in this study should be interpreted to be inconsistent with this claim.

However, at this time, including the cost of storing spent fuel in this study is the most reasonable approach because it ensures the availability of sufficient decommissioning funds at the end of the stations life if, contrary to its contractual obligation, the DOE has not performed earlier.

Site Restoration The efficient removal of the contaminated materials at the site may result in damage to many of the site structures. Blasting, coring, drilling, and the other decontamination activities can substantially damage power block structures, potentially weakening the footings and structural supports. It is unreasonable to anticipate that these structures would be repaired and preserved after the radiological contamination is removed. The cost to dismantle site structures with a work force already mobilized is more efficient and less costly than if the process is deferred.

Consequently, this study assumes that non-essential site structures addressed by this analysis are removed, once remediation is complete, to a nominal depth of three feet below the local grade level wherever possible. The site is then graded and stabilized.

Summary The estimates to decommission ANO assume the removal of all contaminated and activated plant components and structural materials such that the owner may then have unrestricted use of the site with no further requirements for an operating license. Low-level radioactive waste, other than GTCC waste, is sent to a commercial processor for treatment/conditioning or to a controlled disposal facility.

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

The alternatives evaluated in this analysis are described in Section 2. The assumptions are presented in Section 3, along with schedules of annual expenditures. The major cost contributors are identified in Section 6, with detailed activity costs, waste volumes, and associated manpower requirements delineated in Appendices C and D. The major cost components are also identified in the cost summary provided at the end of this section.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page xviii of xx TLG Services, LLC The cost elements in the estimates for the DECON and SAFSTOR alternatives are assigned to one of three subcategories: NRC License Termination (radiological remediation), Spent Fuel Management, and Site Restoration. The subcategory NRC License Termination is used to accumulate costs that are consistent with decommissioning as defined by the NRC in its financial assurance regulations (i.e.,

10 CFR §50.75). The cost reported for this subcategory is generally sufficient to terminate the units operating license, recognizing that there may be some additional cost impact from spent fuel management. The License Termination cost subcategory also includes costs to decommission the ISFSI (as required by 10 CFR §72.30). Section 3.5.1 provides the basis for the ISFSI decommissioning cost delineated in Appendix E.

The Spent Fuel Management subcategory contains costs associated with the containerization and transfer of spent fuel from the wet storage pools to the DOE or to the ISFSI for interim storage, as well as the transfer of the spent fuel in storage at the ISFSI to the DOE. Costs are included for the operation of the storage pools for approximately five and one-half years following shutdown and the management of the ISFSI until such time that the transfer is complete. It does not include any spent fuel management expenses incurred prior to the cessation of plant operations, nor does it include any costs related to the final disposal of the spent fuel.

Site Restoration is used to capture costs associated with the dismantling and demolition of buildings and facilities demonstrated to be free from contamination.

This includes structures never exposed to radioactive materials, as well as those facilities that have been decontaminated to appropriate levels. Structures are removed to a depth of three feet and backfilled to conform to local grade.

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

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

As noted within this document, the estimates were developed and costs are presented in 2024 dollars. As such, the estimates do not reflect the escalation of costs (due to inflationary and market forces) over the remaining operating life of the plant or during the decommissioning period.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page xix of xx TLG Services, LLC DECON COST

SUMMARY

DECOMMISSIONING COST ELEMENTS (thousands of 2024 dollars)

Cost Element ANO-1 ANO-2 Total Decontamination 15,431 16,761 32,192 Removal 133,367 186,741 320,108 Packaging 35,497 39,340 74,837 Transportation 26,300 25,862 52,162 Waste Disposal 88,677 68,312 156,989 Off-site Waste Processing 27,510 56,150 83,659 Program Management[1]

345,058 351,111 696,169 Security 154,408 130,951 285,359 Spent Fuel Pool Isolation 17,313 11,542 28,855 Spent Fuel Management[2]

166,655 143,880 310,535 Insurance and Regulatory Fees 28,220 21,886 50,106 Energy 12,012 11,704 23,716 Characterization and Licensing Surveys 24,197 21,503 45,700 Property Taxes 151 96 247 Miscellaneous Equipment 9,081 9,380 18,461 Corporate A&G 66,325 61,538 127,863 Indirect Overhead 12,389 12,198 24,587 Miscellaneous Site Services 10,439 10,513 20,952 Total [3]

1,173,026 1,179,470 2,352,495 Cost Category ANO-1 ANO-2 Total License Termination 828,744 828,202 1,656,946 Spent Fuel Management 289,423 252,937 542,360 Site Restoration 54,858 98,331 153,189 Total [3]

1,173,026 1,179,470 2,352,495

[1]

Includes engineering costs

[2] Includes costs for operating the spent fuel pools and ISFSI, emergency planning and the cost to transfer the fuel to the DOE and/or ISFSI

[3] Columns may not add due to rounding

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Page xx of xx TLG Services, LLC SAFSTOR COST

SUMMARY

DECOMMISSIONING COST ELEMENTS (thousands of 2024 dollars)

Cost Element ANO-1 ANO-2 Total Decontamination 16,012 18,242 34,254 Removal 139,096 194,390 333,486 Packaging 25,873 30,879 56,753 Transportation 22,433 23,615 46,048 Waste Disposal 62,203 56,167 118,370 Off-site Waste Processing 36,355 57,446 93,802 Program Management[1]

389,401 394,668 784,069 Security 183,491 174,648 358,139 Spent Fuel Pool Isolation 17,313 11,542 28,855 Spent Fuel Management[2]

156,691 133,916 290,607 Insurance and Regulatory Fees 63,608 56,849 120,458 Energy 21,613 22,966 44,579 Characterization and Licensing Surveys 24,372 21,711 46,083 Property Taxes 175 120 295 Miscellaneous Equipment 21,352 21,926 43,278 Corporate A&G 75,562 72,398 147,960 Indirect Overhead 18,137 18,115 36,253 Miscellaneous Site Services 11,866 15,388 27,254 Total [3]

1,285,554 1,324,988 2,610,541 Cost Category ANO-1 ANO-2 Total License Termination 957,075 984,185 1,941,260 Spent Fuel Management 275,649 244,728 520,377 Site Restoration 52,830 96,074 148,904 Total [3]

1,285,554 1,324,988 2,610,541

[1]

Includes engineering costs

[2] Includes costs for operating the spent fuel pools and ISFSI, emergency planning and the cost to transfer the fuel to the DOE and/or ISFSI

[3] Columns may not add due to rounding

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 1 of 11 TLG Services, LLC

1. INTRODUCTION This report presents estimates of the cost to decommission Arkansas Nuclear One (ANO) for the selected decommissioning alternatives following the scheduled and permanent cessation of plant operations. The estimates are designed to provide the owner, Entergy Arkansas LLC (EAL), with the information to assess its current decommissioning liability, as it relates to ANO.

The analysis relies upon site-specific, technical information from an earlier evaluation prepared in 2019,[1]* updated to reflect current plant inventory, current assumptions pertaining to the disposition of the nuclear plant and relevant industry experience in undertaking such projects. The costs are based on several key assumptions in areas of regulation, component characterization, high-level radioactive waste management, low-level radioactive waste disposal, performance uncertainties (contingency) and site restoration requirements.

The analysis is not a detailed engineering evaluation, but rather estimates prepared in advance of the detailed engineering required to carry out the decommissioning of the nuclear units. It may also not reflect the actual plan to decommission ANO; the plan may differ from the assumptions made in this analysis based on facts that exist at the time of decommissioning.

The 2019 plant inventory, the basis for the decontamination and dismantling requirements and cost, and the decommissioning waste streams, were reviewed for this analysis. There were no substantive changes made to the plant inventory (that would impact decommissioning), except for removal of the retired Engineering building.

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

The original operating license for ANO-1 was issued on May 21, 1974, and under the terms of its extended operating license the unit could operate through May 20, 2034. The original operating license for ANO-2 was issued on September 1, 1978 and under the terms of its extended operating license the unit could operate through July 17, 2038.

• References provided in Section 7 of the document

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 2 of 11 TLG Services, LLC 1.2 SITE DESCRIPTION ANO is located in Pope County, approximately six miles west-northwest of Russellville and 57 miles from Little Rock, Arkansas. The plant site is located on a peninsula formed by the Dardanelle Reservoir on the Arkansas River. The two nuclear units located at the site are both pressurized water reactors.

ANO-1 The Nuclear Steam Supply System (NSSS) was supplied by the Babcock &

Wilcox Company and licensed to operate at core power levels up to 2,568 megawatts-thermal (MWt). The steam generators were subsequently replaced in the fall of 2005 with Framatome units. The unit has a maximum dependable capacity of 836 MWe. The original steam generators and reactor closure head remain in storage at the site.

The Reactor Coolant System (RCS) consists of the reactor vessel, two vertical once-through steam generators, four shaft-sealed reactor coolant pumps, one electrically heated pressurizer, and interconnecting piping. The system is arranged in two heat transport loops, each with two pumps and one steam generator. The reactor coolant is transported through piping connecting the reactor vessel to the steam generators and flows downward through the steam generator tubes transferring heat to the steam and water on the shell side of the steam generator.

The RCS, along with portions of the auxiliary systems and engineered safeguard systems, is housed within the reactor building or "containment structure." The reactor building is a fully continuous reinforced concrete structure in the shape of a cylinder on a flat foundation slab with a shallow domed roof. The cylindrical portion is pre-stressed by a post-tensioning system consisting of horizontal and vertical tendons. The foundation slab is conventionally reinforced with high-strength reinforcing steel. A welded steel liner is attached to the inside face of the concrete shell to ensure a high degree of leak tightness. The base liner has been installed on top of the structural slab and is covered with concrete. The structure provides shielding for both normal and accident conditions.

Heat produced in the reactor is converted to electrical energy by the steam and power conversion system. A turbine-generator system converts the thermal energy of steam produced in the steam generators into mechanical shaft power and then into electrical energy via the turbine generator. The turbine is a tandem compound, 3-cylinder, 4-flow, impulse reaction, condensing, 1,800 rpm unit. It has external moisture separation and two stage steam reheaters between the one high-pressure and the two low-pressure cylinders.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 3 of 11 TLG Services, LLC Heat rejected in the main condensers is removed by the circulating water system. Cooling water is drawn from and returned to the Dardanelle Reservoir.

ANO-2 Combustion Engineering originally supplied the Nuclear Steam Supply System (NSSS) for ANO-2. The steam generators were subsequently replaced in the fall of 2000 with Westinghouse units. The system was licensed for an initial core thermal output of 2815 MWt and an uprate output of 3026 MWt. The unit has a maximum dependable capacity of 998 MWe. The original steam generators remain in storage at the site.

The RCS is arranged as two closed loops connected in parallel to the reactor vessel. Each loop consists of one steam generator and two pumps. An electrically heated pressurizer is connected to one of the loops and a safety injection line is connected to each of the four inlet legs. The two steam generators are vertical shell and U-tube units. The RCS is housed within a containment structure similar in design to that of ANO-1.

The main turbine at ANO-2 is an 1,800 rpm, tandem compound, 4-flow, impulse reaction, condensing unit, having one high pressure and two identical low-pressure casings. Combination moisture separator reheaters are employed to dry and superheat the steam between the high and low-pressure turbines. The auxiliaries include deaerating surface condensers, condenser vacuum pumps, cooling tower, turbine driven main feedwater pumps, motor driven condensate pumps, and seven stages of feedwater heaters. The steam is subsequently condensed and returned to the steam generators as heated feedwater.

The heat rejected to the main condenser is removed by the closed loop circulating water system utilizing a natural-draft cooling tower. The counterflow type, hyperbolic, natural draft cooling tower cools the heated water before returning it to the main condenser.

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.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 4 of 11 TLG Services, LLC Subsequent to the rule, the NRC issued Regulatory Guide 1.159, Assuring the Availability of Funds for Decommissioning Nuclear Reactors,[3] which provided additional guidance to the licensees of nuclear facilities on the financial methods acceptable to the NRC staff for complying with the requirements of the rule. The regulatory guide addressed the funding requirements and provided guidance on the content and form of the financial assurance mechanisms indicated in the rule.

The rule defined three decommissioning alternatives as being acceptable to the NRC: DECON, SAFSTOR, and ENTOMB. The DECON alternative assumes that any contaminated or activated portion of the plants systems, structures and facilities are removed or decontaminated to levels that permit the site to be released for unrestricted use shortly after the cessation of plant operations, while the SAFSTOR and ENTOMB alternatives defer the process.

The rule also placed limits on the time allowed to complete the decommissioning process. For all alternatives, the process is restricted in overall duration to 60 years, unless it can be shown that a longer duration is necessary to protect public health and safety. At the conclusion of a 60-year dormancy period (or longer if the NRC approves such a case), the site would still require significant remediation to meet the unrestricted release limits for license termination.

The 60-year restriction has limited the practicality for the ENTOMB alternative at commercial reactors that generate significant amounts of long-lived radioactive material. In 2017, the NRCs staff issued the regulatory basis for proposed new regulations on the decommissioning of commercial nuclear power reactors. In the regulatory basis, the NRC staff proposed removing any discussion of the ENTOMB option from existing guidance documents since the method is not deemed practically feasible for current U.S. power reactors, and the timeframe for decommissioning completion using the ENTOMB method is generally inconsistent with current regulations.[4] Additionally, the Arkansas Public Service Commission Settlement agreement associated with the 2019 DCE filing no longer requires the ENTOMB alternative to be considered in ANO decommissioning cost estimates and therefore is not included in this analysis.

In 1996, the NRC published revisions to the general requirements for decommissioning nuclear power plants.[5] When the decommissioning regulations were adopted in 1988, it was assumed that the majority of licensees would decommission at the end of the facilitys operating licensed life. Since that time, several licensees permanently and prematurely ceased operations.

Exemptions from certain operating requirements were required once the reactor was defueled to facilitate the decommissioning. Each case was handled individually, without clearly defined generic requirements. The NRC amended

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 5 of 11 TLG Services, LLC the decommissioning regulations in 1996 to clarify ambiguities and codify procedures and terminology as a means of enhancing efficiency and uniformity in the decommissioning process. The amendments allow for greater public participation and better define the transition process from operations to decommissioning.

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

Submittal of these notices, along with related changes to Technical Specifications, entitle the licensee to a fee reduction and eliminate the obligation to follow certain requirements needed only during operation of the reactor.

Within two years of submitting notice of permanent cessation of operations, the licensee is required to submit a Post-Shutdown Decommissioning Activities Report (PSDAR) to the NRC.

The PSDAR describes the planned decommissioning activities, the associated sequence and schedule, and an estimate of expected costs. Prior to completing decommissioning, the licensee is required to submit an application to the NRC to terminate the license, which includes a license termination plan (LTP).

In 2011, the NRC issued regulations to improve decommissioning planning and thereby reduce the likelihood that any current operating facility will become a legacy site.[6] The regulations require licensees to report additional details in their decommissioning cost estimate including a decommissioning estimate for the ISFSI. This estimate is provided in Appendix E.

1.3.1 High-Level Radioactive Waste Management Congress passed the Nuclear Waste Policy Act[7] (NWPA) in 1982, assigning the federal governments long-standing responsibility for disposal of the spent nuclear fuel created by the commercial nuclear generating plants to the DOE. It was to begin accepting spent fuel by January 31, 1998; however, to date no progress in the removal of spent fuel from commercial generating sites has been made.

Completion of the decommissioning process is dependent upon the DOEs ability to remove spent fuel from the site in a timely manner. DOEs repository program assumes that spent fuel allocations will be accepted for disposal from the nations commercial nuclear plants, with limited exceptions, in the order (the queue) in which it was discharged from the reactor. Entergys current spent fuel management plan for the ANO spent fuel is based in general upon: 1) a 2035 start date for DOE initiating transfer of commercial spent fuel from the industry to a federal facility

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 6 of 11 TLG Services, LLC (not necessarily a final repository), and 2) an assumed schedule for spent fuel receipt by the DOE for the ANO fuel. The DOEs generator allocation/receipt schedules are based upon the oldest fuel receiving the highest priority. Assuming a maximum rate of transfer of 3,000 metric tons of uranium (MTU)/year, as reflected in DOEs latest Acceptance Priority Ranking and Annual Capacity Report dated June 2004 (DOE/RW-0567),[8] the removal of spent fuel from the site is completed in 2083. Different DOE acceptance schedules may result in different completion dates.

Today, the country is at an impasse on high-level waste disposal, even with the License Application for a geologic repository submitted by the DOE to the NRC in 2008. The Obama administration cut the budget for the repository program while promising to conduct a comprehensive review of policies for managing the back end of the nuclear fuel cycle and make recommendations for a new plan. Towards this goal, the Obama administration appointed a Blue Ribbon Commission on Americas Nuclear Future (Blue Ribbon Commission) to make recommendations for a new plan for nuclear waste disposal. The Blue Ribbon Commissions charter includes a requirement that it consider

[o]ptions for safe storage of used nuclear fuel while final disposition pathways are selected and deployed.[9]

On January 26, 2012, the Blue Ribbon Commission issued its Report to the Secretary of Energy containing a number of recommendations on nuclear waste disposal. Two of the recommendations that may impact decommissioning planning are:

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

• [T]he United States should undertake an integrated nuclear waste management program that leads to the timely development of one or more permanent deep geological facilities for the safe disposal of spent fuel and high-level nuclear waste.[10]

In January 2013, the DOE issued the Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste, in response to the recommendations made by the Blue Ribbon Commission and as a framework for moving toward a sustainable program to deploy an integrated system capable of transporting, storing, and disposing of used nuclear fuel...[11]

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 7 of 11 TLG Services, LLC With the appropriate authorizations from Congress, the Administration currently plans to implement a program over the next 10 years that:

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

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

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

The NRCs review of DOEs license application to construct a geologic repository at Yucca Mountain was suspended in 2011 when the Obama administration significantly reduced the budget for completing that work.

However, the US Court of Appeals for the District of Columbia Circuit issued a writ of mandamus (in August 2013)[12] ordering NRC to comply with federal law and resume its review of DOE's Yucca Mountain repository license application to the extent allowed by previously appropriated funding for the review. That review is now complete with the publication of the five-volume safety evaluation report. A supplement to DOEs environmental impact statement and adjudicatory hearing on the contentions filed by interested parties must be completed before a licensing decision can be made. Although the DOE proposed it would start fuel acceptance in 2025, no progress has been made in the repository program since DOEs 2013 strategy was issued except for the completion of the Yucca Mountain safety evaluation report. Because of this continued delay, this estimate revises the assumed start date for DOE fuel acceptance from 2030, as used in the 2019 evaluation, to 2035.

Holtec International submitted a license application to the NRC on March 30, 2017 for a consolidated interim spent fuel storage facility in southeast New Mexico called HI-STORE CIS (Consolidated Interim Storage) under the provisions of 10 CFR Part 72. The application was approved by the NRC on May 9, 2023.

Waste Control Specialists (WCS) submitted an application to the NRC on April 28, 2016, to construct and operate a Consolidated Interim Storage Facility (CISF) at its West Texas facility. On April 18, 2017, WCS

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 8 of 11 TLG Services, LLC requested that the NRC temporarily suspend all safety and environmental review activities, as well as public participation activities associated with WCSs license application. In March 2018, WCS and Orano USA, announced their intent to form a joint venture to license the facility. On September 17, 2021, the NRC approved the joint ventures original CISF license application. At this time, neither storage facility is in service and therefore has not been considered in this estimate.

On May 10, 2018, the U.S. House of Representatives passed H.R. 3053, the Nuclear Waste Policy Amendments Act of 2018. Proposed to amend the Nuclear Waste Policy Act of 1982, the legislation, if approved by the Senate and signed by the President, would provide the DOE the authority to site, construct, and operate one or more Monitored Retrieval Storage (MRS) facilities while a permanent repository is licensed and constructed and/or to enter into an MRS agreement with a non-Federal entity for temporary storage. At the time of this estimate, no further action has been taken on this legislation.

The NRC requires that licensees establish a program to manage and provide funding for the caretaking of all irradiated fuel at the reactor site until title of the fuel is transferred to the DOE.[13] Interim storage of the fuel, until the DOE has completed the transfer, will be in the auxiliary buildings spent fuel storage pools as well as at an on-site ISFSI. DOE has breached its obligations to remove fuel from reactor sites, and has also failed to provide the plant owner with information about how it will ultimately perform. DOE officials have stated that DOE does not have an obligation to accept already-canistered fuel without an amendment to DOEs contracts with plant licensees to remove the fuel (the Standard Contract), but DOE has not explained what any such amendment would involve. Consequently, the plant owner has no information or expectations on how DOE will remove fuel from the site in the future. In the absence of information about how DOE will perform, and for purposes of this analysis only, it is assumed that DOE will accept already-canistered fuel (it is recognized that the canisters may not be licensed or licensable for transportation when DOE performs). If this assumption is incorrect, it is assumed that DOE will have liability for costs incurred to transfer the fuel to DOE-supplied containers.

An ISFSI, operated under a Part 50 General License (in accordance with 10 CFR 72, Subpart K[14]), has been constructed to support continued plant operations. The facility is assumed to be available to support future decommissioning operations. As such, the fuel that cannot be transferred directly to the DOE from the wet pools is packaged for interim storage at

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 9 of 11 TLG Services, LLC the ISFSI. Once the auxiliary buildings spent fuel storage pools are emptied, the buildings can be either decontaminated and dismantled or prepared for long-term storage.

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

1.3.2 Low-Level Radioactive Waste Management The contaminated and activated material generated in the decontamination and dismantling of a commercial nuclear reactor is classified as low-level (radioactive) waste, although not all of the material is suitable for shallow-land disposal. With the passage of the Low-Level Radioactive Waste Policy Act in 1980,[15] and its Amendments of 1985,[16]

the states became ultimately responsible for the disposition of low-level radioactive waste generated within their own borders.

With the exception of Texas, no new compact facilities have been successfully sited, licensed, and constructed. The Texas Compact disposal facility is now operational and waste is being accepted from generators within the Compact by the operator, Waste Control Specialists (WCS). The facility is also able to accept limited volumes of non-Compact waste.

Disposition of the various waste streams produced by the decommissioning process considered all options and services currently available to Entergy. The majority of the low-level radioactive waste designated for direct disposal (Class A[17]) can be sent to EnergySolutions facility in Clive, Utah. Therefore, disposal costs for Class A waste were based upon Entergys Life of Plant Agreement and other service agreements with EnergySolutions. This facility is not licensed to receive the higher activity portion (Classes B and C) of the decommissioning waste stream.

The WCS facility is able to receive the Class B and C waste. As such, for this analysis, Class B and C waste was assumed to be shipped to the WCS facility and disposal costs for the waste were based upon Entergys current agreement with WCS.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 10 of 11 TLG Services, LLC The dismantling of the components residing closest to the reactor core generates radioactive waste that may be considered unsuitable for shallow-land disposal (i.e.,

low-level radioactive waste with concentrations of radionuclides that exceed the limits established by the NRC for Class C radioactive waste (GTCC)). The Low-Level Radioactive Waste Policy Amendments Act of 1985 assigned the federal government the responsibility for the disposal of this material. The Act also stated that the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste.

However, to date, the federal government has not identified a cost, if any, for GTCC disposal or a schedule for acceptance.

For purposes of this analysis only, the GTCC radioactive waste is assumed to be packaged and disposed of in a manner similar to high-level waste and at a cost equivalent to that envisioned for the spent fuel. The GTCC is packaged in the same canisters used for spent fuel and either stored on site or shipped directly to a federal facility as it is generated (depending upon the timing of the decommissioning and whether the spent fuel has already been removed from the site prior to the start of decommissioning).

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

1.3.3 Radiological Criteria for License Termination In 1997, the NRC published Subpart E, Radiological Criteria for License Termination,[18] amending 10 CFR Part 20. This subpart provides radiological criteria for releasing a facility for unrestricted use. The regulation states that the site can be released for unrestricted use if radioactivity levels are such that the average member of a critical group would not receive a Total Effective Dose Equivalent (TEDE) in excess of 25 millirem per year, and provided that residual radioactivity has been reduced to levels that are As Low As Reasonably Achievable (ALARA).

The decommissioning estimates assume that the ANO site will be

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 1, Page 11 of 11 TLG Services, LLC 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).[19] An additional and separate limit of 4 millirem per year, as defined in 40 CFR

§141.66, is applied to drinking water.[20]

On October 9, 2002, the NRC signed an agreement with the EPA on the radiological decommissioning and decontamination of NRC-licensed sites.

The Memorandum of Understanding (MOU)[21] provides that EPA will defer exercise of authority under CERCLA for the majority of facilities decommissioned under NRC authority. The MOU also includes provisions for NRC and EPA consultation for certain sites when, at the time of license termination, (1) groundwater contamination exceeds EPA-permitted levels; (2) NRC contemplates restricted release of the site; and/or (3) residual radioactive soil concentrations exceed levels defined in the MOU.

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

As such, the possibility of dual regulation remains for certain licensees.

The present study does not include any costs for this occurrence.

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2. DECOMMISSIONING ALTERNATIVES Detailed cost estimates were developed to decommission ANO based upon two of the NRCs three decommissioning alternatives.

Two decommissioning scenarios were evaluated for the two ANO nuclear units. The scenarios selected are representative of alternatives available to the owner and are defined as follows:

1.

The first scenario assumes that the two units would be promptly decommissioned (DECON alternative) upon the expiration of the current operating licenses, i.e., 2034 and 2038 for Units 1 and 2, respectively.

2.

In the second scenario, the nuclear units are placed into safe-storage (SAFSTOR alternative) at the end of their current operating licenses.

Decommissioning is deferred to the maximum extent such that the licenses are terminated within the required 60-year period.

The following sections describe the basic activities associated with each alternative.

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

The conceptual approach that the NRC has described in its regulations divides decommissioning into three phases. The initial phase commences with the effective date of permanent cessation of operations and involves the transition of both plant and licensee from reactor operations (i.e., power production) to facility de-activation and closure. During the first phase, notification is to be provided to the NRC certifying the permanent cessation of operations and the removal of fuel from the reactor vessel. The licensee is then prohibited from reactor operation. The second phase encompasses activities during the storage period or during major decommissioning activities, or a combination of the two. The third phase pertains to the activities involved in license termination. The decommissioning estimates developed for ANO 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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 2 of 12 TLG Services, LLC contaminants are removed or decontaminated to a level that permits the property to be released for unrestricted use shortly after cessation of operations."

This study does not address the cost to dispose of the spent fuel residing at the site; such costs are funded through a surcharge on electrical generation.

However, the study does estimate the costs incurred with the interim on-site storage of the fuel pending shipment by the DOE to an off-site disposal facility.

2.1.1 Period 1 - Preparations In anticipation of the cessation of plant operations, detailed preparations are undertaken to provide a smooth transition from plant operations to site decommissioning. Through implementation of a staffing transition plan, the organization required to manage the intended decommissioning activities is assembled from available plant staff and outside resources.

Preparations include the planning for permanent defueling of the reactor, revision of technical specifications applicable to the operating conditions and requirements, a characterization of the facility and major components, and the development of the PSDAR.

Engineering and Planning The PSDAR, required prior to or within two years of permanent cessation of operations, provides a description of the licensees planned decommissioning activities, a timetable, a site-specific decommissioning cost estimate, and the associated financial requirements of the intended decommissioning program. Upon receipt of the PSDAR, the NRC will make the document available to the public for comment in a local hearing to be held in the vicinity of the reactor site. Ninety days following submittal and NRC receipt of the PSDAR, the licensee may begin to perform major decommissioning activities under a modified 10 CFR

§50.59 procedure (10 CFR §50.59 establishes the conditions under which licensees may make changes to the facility or procedures and conduct test or experiments without prior 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 §61.55. 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,

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• 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 defined in 10 CFR Part 20) for protection of personnel from exposure to radiation hazards. It will also address the continued protection of the health and safety of the public and the environment during the dismantling activity.

Consequently, with the development of the

PSDAR, activity specifications, cost-benefit and safety analyses, work packages, and procedures would be assembled to support the proposed decontamination and dismantling activities.

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

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

• Isolation of the spent fuel storage pools and fuel handling systems, such that decommissioning operations can commence on the balance of the plant. The pools will remain operational for approximately five and one-half years following the cessation of operations. During this time period, it is assumed that the spent fuel residing in the pools that cannot be directly transferred to the DOE will be moved to an ISFSI for interim storage

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

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

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

• Construction of temporary facilities and/or modification of existing facilities to support dismantling activities. For example, this will include a centralized processing area to facilitate equipment removal and component preparations for off-site disposal.

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

• Transfer of the spent fuel from the storage pools to the ISFSI pad.

• 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.

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• 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 baffle, former and thermal shield (ANO-1), and core barrel, shroud and core support structure (ANO-2). Some material is expected to exceed Class C disposal requirements. As such, the segments will be packaged in modified fuel storage canisters for disposal at a federal facility.

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

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

• Removal of the steam generators and pressurizer for material recovery and controlled disposal. The ANO-1 steam generators will be moved to an on-site processing center and prepared for direct disposal. The generators will be shipped intact (no segmentation). With a larger diameter, it is assumed that the steam domes on the ANO-2 steam generators will need to be removed to facilitate transportation. Once removed, the internal components are segregated for recycling. The lower shell and tube bundle will be packaged for direct disposal. These components can serve as their own burial containers provided that all penetrations are properly sealed and the internal contaminants are stabilized, e.g., with grout. Steel shielding will be added, as necessary, to those external areas of the package to meet transportation limits and regulations. A similar process will be used to prepare the retired units for disposal. The pressurizer is disposed of intact.

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 6 of 12 TLG Services, LLC Report (FSAR) or its equivalent, the plan must include: a site characterization, a description of the remaining dismantling activities, plans for site remediation, procedures for the final radiation survey, designation of the end use of the site, an updated cost estimate to complete the decommissioning, and any associated environmental concerns. The NRC will notice the receipt of the plan, make the plan available for public comment, and schedule a local hearing. LTP approval will be subject to any conditions and limitations as deemed appropriate by the Commission.

The licensee may then commence with the final remediation of site facilities and services, including:

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

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

• Surveys of the decontaminated areas of the containment structure.

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

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 7 of 12 TLG Services, LLC the Multi-Agency Radiation Survey and Site Investigation Manual (MARSSIM).[22] This document incorporates the statistical approaches to survey design and data interpretation used by the EPA. It also identifies commercially available instrumentation and procedures for conducting radiological surveys. Use of this guidance ensures that the surveys are conducted in a manner that provides a high degree of confidence that applicable NRC criteria are satisfied. Once the survey is complete, the results are provided to the NRC in a format that can be verified. The NRC then reviews and evaluates the information, performs an independent confirmation of radiological site conditions, and makes a determination on the requested change to the operating license (that would release the property, exclusive of the ISFSI, for unrestricted use).

The NRC will amend the operating licenses if it determines that site remediation has been performed in accordance with the LTP, and that the terminal radiation survey and associated documentation demonstrate that the property (exclusive of the ISFSI) is suitable for release.

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

Although performed in a controlled, safe manner, blasting, coring, drilling, scarification (surface removal), and the other decontamination activities will substantially degrade power block structures including the reactor, auxiliary, radioactive waste, low-level radioactive storage and solid radwaste storage 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.

It is not currently anticipated that these structures would be repaired and preserved after the radiological contamination is removed. The cost to dismantle site structures, once remediation is complete, with a work force already mobilized on site is more efficient than if the process is deferred.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 8 of 12 TLG Services, LLC This cost study presumes that non-essential structures and site facilities area are dismantled as a continuation of the decommissioning activity.

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

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

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

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

2.1.4 ISFSI Operations and Decommissioning For purposes only of this estimate, transfer of spent fuel to a DOE repository or interim facility is assumed to be exclusively from the ISFSI once the fuel pools have been emptied and the auxiliary buildings released for decommissioning. If this assumption is incorrect, it is assumed that DOE will have liability for costs incurred to transfer the fuel to DOE-supplied containers. The ISFSI will continue to operate under a general license (10 CFR Part 50) following the amendment of the operating licenses to release the adjacent (power block) property.

Assuming the DOE starts accepting fuel from ANO in 2038 (ANO-1),

transfer of spent fuel from the ISFSI is anticipated to continue through the year 2083. This assumption is made for purposes of this estimate, although it is acknowledged that the plant owner will seek the most expeditious means of removing fuel from the site when DOE commences performance.

At the conclusion of the spent fuel transfer process, the ISFSI will be decommissioned. The Commission will terminate the Part 50 license if it determines that the remediation of the ISFSI has been performed in accordance with an ISFSI license termination plan and that the final radiation survey and associated documentation demonstrate that the facility is suitable for release. Once the requirements are satisfied, the NRC can terminate the license for the ISFSI.

The design of the ISFSI is based upon the use of a multi-purpose canister and a vertical concrete module/overpack for pad storage. It is assumed

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 9 of 12 TLG Services, LLC that once the inner canisters containing the spent fuel assemblies have been removed, any required decontamination is performed on the storage modules (some minor neutron activation is assumed), and the license for the facility terminated, the modules can be dismantled using conventional techniques for the demolition of reinforced concrete. The concrete storage pad is then removed and the area regraded to minimize ponding.

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

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

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

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

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

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• Transferring the spent fuel from the storage pools to the DOE or to the ISFSI for interim storage, following the minimum required cooling period in the spent fuel pools.

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

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

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

• Draining and de-energizing non-essential, contaminated systems 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.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 11 of 12 TLG Services, LLC An environmental surveillance program is carried out during the dormancy period to ensure that releases of radioactive material to the environment are prevented or detected and controlled. Appropriate emergency procedures are established and initiated for potential releases that exceed prescribed limits. The environmental surveillance program constitutes an abbreviated version of the program in effect during normal plant operations.

Security during the dormancy period is conducted primarily to prevent unauthorized entry and to protect the public from the consequences of its own actions. The security fence, sensors, alarms, and other surveillance equipment are maintained throughout the dormancy period. Fire and radiation alarms are also functional.

Consistent with the DECON scenario, the spent fuel storage pools are emptied within five and one-half years of the cessation of operations. It is assumed that the transfer of the spent fuel from the ISFSI to a DOE facility begins in 2043 and continues throughout the dormancy period until completed in 2083. If the assumption of transfer of fuel from the ISFSI to DOE is incorrect, it is assumed that DOE will have liability for costs incurred to transfer the fuel to DOE-supplied containers. Once emptied, the ISFSI is secured for storage and decommissioned along with the power block structures in Period 4.

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

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

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 2, Page 12 of 12 TLG Services, LLC this deferred scenario is the absence, in the latter, of any constraint on the dismantling process due to the operation of the spent fuel pools in the DECON option.

Variations in the length of the dormancy period are expected to have some 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. However, due to the lower activity levels, a greater percentage of the waste volume can be designated for off-site processing and recovery.

The delay in decommissioning also yields lower working area radiation levels. As such, the estimate for this delayed scenario incorporates reduced ALARA controls for the SAFSTOR's lower occupational exposure potential.

Although the initial radiation levels due to 60Co will substantially decrease during the dormancy period, the internal components of the reactor vessel will still exhibit sufficiently high radiation dose rates to require remote sectioning under water due to the presence of long-lived radionuclides such as 94Nb, 59Ni, and 63Ni. Therefore, the dismantling procedures described for the DECON alternative would still be employed during this scenario. Portions of the biological shields 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 begin. Dismantling, as a continuation of the decommissioning process, is a cost-effective option as described in Section 2.1.3. The basis for the dismantling cost is consistent with that described for DECON, presuming the removal of structures and site facilities to a nominal depth of three feet below grade and the limited restoration of the site.

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

3.1 BASIS OF ESTIMATES The current estimates were developed using the site-specific, technical information relied upon in the decommissioning analysis prepared in 2019. This information was reviewed for the current analysis and updated as deemed appropriate. The site-specific considerations and assumptions used in the previous evaluation were also revisited. Modifications were incorporated where new information was available or experience from ongoing decommissioning programs provided viable alternatives or improved processes.

3.2 METHODOLOGY The methodology used to develop the estimates follows the basic approach originally presented in the AIF/NESP-036 study report, "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates,"[23] and the DOE "Decommissioning Handbook."[24] These documents present a unit factor method for estimating decommissioning activity costs, which simplifies the estimating calculations. Unit factors for concrete removal

($/cubic yard), steel removal ($/ton), and cutting costs ($/inch) are developed using local labor rates. The activity-dependent costs are estimated with the item quantities (cubic yards and tons), developed from plant drawings and inventory documents. Removal rates and material costs for the conventional disposition of components and structures rely upon information available in the industry publication, "Building Construction Cost Data," published by RSMeans.[25]

The unit factor method provides a demonstrable basis for establishing reliable cost estimates. The detail provided in the unit factors, including activity duration, labor costs (by craft), and equipment and consumable costs, ensures that essential elements have not been omitted. Appendix A presents the detailed development of a typical unit factor. Appendix B provides the values contained within one set of factors developed for this analysis.

Regulatory Guide 1.184[26] Revision 1, issued in October 2013, describes the methods and procedures that are acceptable to the NRC staff for implementing

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 2 of 52 TLG Services, LLC the requirements that relate to the initial activities and the major phases of the decommissioning process. The costs and schedules presented in this analysis follow the general guidance and sequence in the regulations. The format and content of the estimates is also consistent with the recommendations of Regulatory Guide 1.202,[27] issued February 2005.

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 Rancho Seco, Trojan, Yankee Rowe, Big Rock Point, Maine Yankee, Humboldt Bay-3, Oyster Creek, Connecticut Yankee, Crystal River, Vermont Yankee, Fort Calhoun, Pilgrim, and Indian Point nuclear units have provided additional insight into the process, the regulatory aspects, and the technical challenges of decommissioning commercial nuclear units.

Work Difficulty Factors TLG has historically applied work difficulty adjustment factors (WDFs) to account for the inefficiencies in working in a power plant environment. WDFs are assigned to each unique set of unit factors, commensurate with the inefficiencies associated with working in confined, hazardous environments.

The ranges used for the WDFs are as follows:

• Access Factor 10% to 20%

• Respiratory Protection Factor 10% to 50%

• Radiation/ALARA Factor 10% to 37%

• Protective Clothing Factor 10% to 30%

• Work Break Factor 8.33%

The factors and their associated range of values were developed in conjunction with the AIF/NESP-036 study. The application of the factors is discussed in more detail in that publication.

Scheduling Program Durations The unit factors, adjusted by the WDFs as described above, are applied against the inventory of materials to be removed in the radiological controlled areas. The resulting labor-hours, or crew-hours, are used in the development of the decommissioning program schedule, using resource loading and event sequencing considerations. The scheduling of conventional removal and

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 3 of 52 TLG Services, LLC dismantling activities is based upon productivity information available from the "Building Construction Cost Data" publication. In the DECON alternative, dismantling of the auxiliary buildings systems and decontamination of the spent fuel pools is also dependent upon the timetable for the transfer of the spent fuel assemblies from the pools to the ISFSI.

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

3.3 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. A summary of the principal impacts is listed below.

• The sequence of work generally follows the principle that the work is done at ANO-1 first, followed by similar work at ANO-2. This permits the experience gained at ANO-1 to be applied by the workforce at the second unit. It should be noted however, that the estimate does not consider productivity improvements at the second unit, since there is little documented experience with decommissioning two units simultaneously. However, there will be many common activities between the two units; therefore, the second unit costs for engineering and preparation of the dismantling procedures are assumed to be a fraction of the first unit (~55%).

• Segmenting the reactor vessel and internals will require the use of special equipment. The decommissioning project will be scheduled such that ANO-2s reactor internals and vessel are segmented after the activities at ANO-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.

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• 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 ANO-1, while ANO-2 still has ongoing radiological remediation work and waste handling in process.

• The final demolition of buildings at Units 1 and 2 are considered to take place concurrently.

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

• Shared systems and common structures are generally assigned to ANO-2.

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

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

3.4.1 Contingency Inherent in any cost estimate that does not rely on historical data is the inability to specify the precise source of costs imposed by factors such as tool breakage, accidents, illnesses, weather delays, and labor stoppages.

In the DECCER cost model, contingency fulfills this role. Contingency is added to each line item to account for costs that are difficult or impossible to develop analytically. Such costs are historically inevitable over the duration of a job of this magnitude; therefore, this cost analysis includes funds to cover these types of expenses.

The activity-and period-dependent costs are combined to develop the total decommissioning cost. A contingency is then applied on a line-item basis, using one or more of the contingency types listed in the AIF/NESP-036 study. "Contingencies" are defined in the American Association of Cost Engineers Project and Cost Engineers' Handbook[28] 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,

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 5 of 52 TLG Services, LLC consistent with industry practice, contingency is included. In the AIF/NESP-036 study, the types of unforeseeable events that are likely to occur in decommissioning are discussed and guidelines are provided for a contingency percentage in each category. It should be noted that contingency, as used in this analysis, does not account for price escalation and inflation in the cost of decommissioning over the remaining operating life of the station.

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

Individual activity contingencies ranged from 10% to 75%, depending on the degree of difficulty judged to be appropriate from TLGs actual decommissioning experience. The contingency values used in this study are as follows:

• Decontamination 50%

• Contaminated Component Removal 25%

• Contaminated Component Packaging 10%

• Contaminated Component Transport 15%

• Low-Level Radioactive Waste Disposal 25%

• Low-Level Radioactive Waste Processing 15%

• 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%

• Insurance, Taxes and Fees 10%

• Staffing 15%

• Characterization and Termination Surveys 30%

• Construction 15%

• Spent Fuel Capital Costs (Canisters and Overpacks) 15%

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 6 of 52 TLG Services, LLC

• Spent Fuel Transfer Costs 15%

• Operations and Maintenance Expenses 15%

• ISFSI Decommissioning 25%

The contingency values are applied to the appropriate components of the estimates on a line item basis. A composite value is then reported at the end of each detailed estimate (as provided in Appendices C and D). A contingency of 25% is applied to the subtotal of the ISFSI decommissioning costs in Appendix E.

3.4.2 Financial Risk In addition to the routine uncertainties addressed by contingency, another cost element that is sometimes necessary to consider when bounding decommissioning costs relates to uncertainty, or risk. Examples can include changes in work scope, pricing, job performance, and other variations that could conceivably, but not necessarily, occur.

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

• Transition activities and costs: ancillary expenses associated with reducing the size of the labor force 50% to 80% shortly after the cessation of plant operations, national or company-mandated retraining, and retention incentives for key personnel.

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

• Changes in the project work scope from the baseline estimate, involving the discovery of unexpected levels of contaminants, contamination in places not previously expected, contaminated soil previously undiscovered (either radioactive or hazardous material contamination), variations in plant inventory or configuration not indicated by the as-built drawings.

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

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

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

This cost study does not add any additional costs to the estimate for financial risk, since there is insufficient historical data from which to project future liabilities. Consequently, the areas of uncertainty or risk are revisited periodically and addressed through repeated revisions or updates of the base estimates.

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

3.5.1 Spent Fuel Management The cost to dispose of the spent fuel generated from plant operations is not reflected within the estimates to decommission ANO. Ultimate disposition of the spent fuel is within the province of the DOEs Waste Management System, as defined by the Nuclear Waste Policy Act. As such, the disposal cost is financed by a surcharge paid into the DOEs waste fund during operations. On November 19, 2013, the U.S. Court of Appeals for the D.C. Circuit ordered the Secretary of the Department of Energy to suspend collecting annual fees for nuclear waste disposal from nuclear power plant operators until the DOE has conducted a legally adequate fee assessment.

The NRC does, however, requires licensees to establish a program to manage and provide funding for the management of all irradiated fuel at the reactor site until title of the fuel is transferred to the Secretary of Energy. This requirement is prepared for through inclusion of certain high-level waste cost elements within the estimates, as described below.

Completion of the decommissioning process is highly dependent upon the DOEs ability to remove spent fuel from the site. DOE's repository program assumes that spent fuel is 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"). The DOE contracts provide mechanisms for altering the oldest fuel first allocation scheme, including emergency deliveries, exchanges of allocations amongst utilities and the option of providing priority acceptance from permanently shutdown

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 8 of 52 TLG Services, LLC nuclear reactors. Because it is unclear how these mechanisms may operate once DOE begins accepting spent fuel from commercial reactors, this study assumes that DOE will accept spent fuel in an oldest fuel first order. The timing for removal of spent fuel from the site is based upon the DOEs most recently published annual acceptance rates of 400 MTU/year for year 1, 3,800 MTU total for years 2 through 4 and 3,000 MTU/year for year 5 and beyond.[29]

ISFSI Due to DOEs inability to remove fuel from the site, an ISFSI has been constructed at the site and fuel casks have been emplaced thereon to support continued plant operations. The ISFSI will be expected to operate throughout decommissioning, and beyond the conclusion of the remediation phase in the DECON decommissioning scenario, until such time that the transfer of spent fuel to the DOE can be completed.

Assuming that DOE begins accepting commercial spent fuel from the industry in 2035, ANO fuel is projected to be removed from the site beginning in 2038. The process is expected to be completed by the year 2083, based upon the current shutdown dates. The scenario is similar for the SAFSTOR alternative; however, based upon the expected completion date for fuel transfer, the ISFSI will be emptied prior to the commencement of decommissioning operations.

Operation and maintenance costs for the spent fuel pools and the ISFSI are included within the estimates and address the cost for staffing the facility, as well as security, insurance, and licensing fees. The estimates include the costs to purchase, load, and transfer the multi-purpose spent fuel storage canisters (MPCs) from the pools to the DOE and/or ISFSI.

Costs are also provided for transfer of the MPCs to the DOE from the ISFSI (although it is acknowledged that this may not occur and that the fuel in the MPCs may have to be repackaged at DOE expense).

Storage Canister Design The ISFSI currently contains 24 Ventilated Storage Casks (VSC)-24 casks loaded with spent fuel, the last one loaded in 2003. Subsequent dry fuel storage campaign used a Holtec HI-STORM dry storage system. The Holtec system consists of MPCs with nominal capacities of 24 assemblies (ANO-1) and 32 fuel assemblies (ANO-2), and a concrete storage overpack.

These capacity MPCs were utilized until 2023 for ANO-1 and through 2025 at ANO-2 at which time both units will begin using the HOLTEC FW casks with a 37 assembly storage capacity.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 9 of 52 TLG Services, LLC Canister Loading and Transfer The estimates include the cost for the labor and equipment to load and transfer the spent fuel canisters to the DOE and/or ISFSI from the wet storage pools. For estimating purposes only, an allowance is used for the cost to transfer the fuel from the ISFSI into the DOE transport cask.

A total of 24 VSC-24 casks were loaded at ANO before switching to the Holtec multi-purpose canisters.

The casks are currently non-transportable. As such, the fuel stored in these canisters is assumed to be repackaged before being shipped off site.

For purposes of this analysis only, it is assumed that DOE will accept already-canistered fuel (it is recognized that the canisters may not be licensed or licensable for transportation when DOE performs). If this assumption is incorrect, it is assumed that DOE will have liability for costs incurred to transfer the fuel to DOE-supplied containers.

Operations and Maintenance The estimates also include the cost of operating and maintaining the spent fuel pools and the ISFSI, respectively. Pool operations are expected to continue approximately five and one half years after the cessation of operations. It is assumed that the five and one-half years provides the necessary cooling period for the final core to meet the dry cask storage vendors system specifications. ISFSI operating costs are based upon the previously stated assumptions on fuel transfer and DOE performance (in removing the fuel from the site).

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

A multi-purpose (storage and transport) dry shielded storage canister with a vertical, reinforced concrete storage overpack is used as a basis for the cost analyses. The overpack liners are assumed to have some level of neutron-induced activation, as a result of the long-term storage of the fuel,

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 10 of 52 TLG Services, LLC i.e., to levels exceeding free-release limits. As an allowance, 10 overpacks are assumed to require remediation, equivalent to the number of overpacks required to accommodate the final core off loads. The cost of the disposition of this material, as well as the demolition of the ISFSI facility, is included in the estimates.

In accordance with the specific requirements of 10 CFR §72.30 for the ISFSI work scope, the cost estimate for decommissioning the ISFSI reflects: 1) the cost of an independent contractor performing the decommissioning activities; 2) an adequate contingency factor; and 3) the cost of meeting the criteria for unrestricted use. The cost summary for decommissioning the ISFSI is presented in Appendix E.

GTCC The dismantling of the reactor internals is expected to generate radioactive waste considered unsuitable for shallow land disposal (i.e.,

low-level radioactive waste with concentrations of radionuclides that exceed the limits established by the NRC for Class C radioactive waste (GTCC)). The Low-Level Radioactive Waste Policy Amendments Act of 1985 assigned the federal government the responsibility for the disposal of this material. The Act also stated that the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste. Although the DOE is responsible for disposing of GTCC waste, any costs for that service have not been determined. For purposes of this estimate, the GTCC radioactive waste has been assumed to be packaged in the same canisters used to store spent fuel and disposed of as high-level waste, at a cost equivalent to that envisioned for the spent fuel. The number of canisters required and the packaged volume for GTCC was based upon experience at Maine Yankee (e.g., the constraints on loading as identified in the canisters certificate of compliance).

It is assumed only for purposes of these estimates that the DOE would not accept this waste prior to completing the transfer of spent fuel. Therefore, until such time as the DOE is ready to accept GTCC waste, it is assumed that this material would remain in storage at the ANO site (for the DECON alternative). It is acknowledged, however, that the plant owner will seek the most expeditious means of removing the GTCC from the site when DOE commences performance. In the SAFSTOR scenario, the GTCC material is shipped directly to a DOE facility as it is generated since the fuel has been removed from the site prior to the start of decommissioning.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 11 of 52 TLG Services, LLC 3.5.2 Reactor Vessel and Internal Components The reactor pressure vessel and internal components are segmented for disposal in shielded, reusable transportation casks. Segmentation is performed in the refueling canal, where a turntable and remote cutter are installed. The vessel is segmented in place, using a mast-mounted cutter supported off the lower head and directed from a shielded work platform installed overhead in the reactor cavity.

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

Intact disposal of reactor vessel shells has been successfully demonstrated at several of the sites that have been decommissioned. Access to navigable waterways has allowed these large packages to be transported to the Barnwell disposal site with minimal overland travel. Intact disposal of the reactor vessel and internal components can provide savings in cost and worker exposure by eliminating the complex segmentation requirements, isolation of the GTCC material, and transport/storage of the resulting waste packages. Portland General Electric (PGE) was able to dispose of the Trojan reactor as an intact package (including the internals).

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

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

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

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

As a member of the Northwest Compact, PGE had a site available for disposal of the package - the US Ecology facility in Washington State. The characteristics of this arid site proved favorable in demonstrating compliance with land disposal regulations.

It is not known whether this option will be available when the ANO plant 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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 12 of 52 TLG Services, LLC from the environment. Consequently, the study assumes that the reactor vessel will require segmentation, as a bounding condition.

3.5.3 Primary System Components In the DECON scenario, the reactor coolant system components are assumed to be decontaminated using chemical agents prior to the start of dismantling operations. This type of decontamination can be expected to have a significant ALARA impact, since in this scenario the removal work is done within the first few years of shutdown. A decontamination factor (average reduction) of 10 is assumed for the process. Disposal of the decontamination solution effluent is included within the estimate as a "process liquid waste" charge. In the SAFSTOR scenario, radionuclide decay is expected to provide the same benefit and, therefore, a chemical decontamination is not included.

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

A trolley crane is set up for the removal of the generators. It can also be used to move portions of the steam generator cubicle walls and floor slabs from the reactor building to a location where they can be decontaminated and transported to the material handling area. Interferences within the work area, such as grating, piping, and other components are removed to create sufficient laydown space for processing these large components.

The generators are rigged for removal, disconnected from the surrounding piping and supports, and maneuvered into the open area where they are lowered onto a dolly. Each generator is rotated into the horizontal position for extraction from the containment and placed onto a multi-wheeled vehicle for transport to an on-site processing and storage area.

The ANO-1 generators are shipped intact to the disposal site. The ANO-2 generators (with their larger diameter steam domes) are disassembled on-site with the dome and lightly contaminated subassemblies designated for off-site recycling. The more highly contaminated tube sheet and tube bundle are packaged for direct disposal.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 13 of 52 TLG Services, LLC Disposal costs are based upon the volume and weight of the units. Each component is then loaded onto a rail car for transport to the disposal facility.

Reactor coolant piping is cut from the reactor vessel once the water level in the vessel (used for personnel shielding during dismantling and cutting operations in and around the vessel) is dropped below the nozzle zone.

The piping is boxed and transported by shielded van. The reactor coolant pumps and motors are lifted out intact, packaged, and transported for processing and/or disposal.

3.5.4 Retired Components The estimate includes the disposition of the two retired steam generators for each unit. The steam generators currently reside in a mausoleum located at the site and, following the cessation of plant operations, will be routed for processing and disposal. The estimate also includes the segmentation, processing and disposal of the ANO-1 retired reactor vessel head and stored hot leg piping.

3.5.5 Main Turbine and Condenser The main turbine is dismantled using conventional maintenance procedures. The turbine rotors and shafts are removed to a laydown area.

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

3.5.6 Transportation Methods Contaminated piping, components, and structural material other than the highly activated reactor vessel and internal components will qualify as LSA-I, II or III or Surface Contaminated Object, SCO-I or II, as described in Title 49.[30] The contaminated material will be packaged in Industrial Packages (IP-1, IP-2, or IP-3, as defined in subpart 10 CFR §173.411) for transport unless demonstrated to qualify as their own shipping containers. The reactor vessel and internal components are expected to be transported in accordance with 10 CFR Part 71. It is conceivable that the reactor, due to its limited specific activity, could qualify as LSA II or III.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 14 of 52 TLG Services, LLC 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.

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

Transport of the highly activated metal, produced in the segmentation of the reactor vessel and internal components, will be by shielded cask. Cask shipments may exceed 95,000 pounds, including vessel segment(s),

supplementary shielding, cask tie-downs, and tractor-trailer. The maximum level of activity per shipment assumed permissible was based upon the license limits of the available shielded transport casks. The segmentation scheme for the vessel and internal segments is designed to meet these limits.

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

Transportation costs for Class A radioactive material requiring controlled disposal are based upon the route and mileage to the EnergySolutions facility in Clive, Utah. Transportation costs for the higher activity Class B and C radioactive material are based upon the route and mileage to the WCS facility in Andrews County, Texas. Transportation cost for the GTCC material is assumed to be included within the disposal charge.

Transportation costs for off-site waste processing are based upon the route and mileage to Oak Ridge, Tennessee. Truck transport costs were developed from published tariffs from Tri-State Motor Transit.[31]

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 15 of 52 TLG Services, LLC the site is subject to a survey and release charge, at a minimum.

The mass of radioactive waste generated during the various decommissioning activities at the site is shown on a line-item basis in the detailed Appendices C and D, and summarized in Section 5. The quantified waste summaries shown in these tables are consistent with 10 CFR Part 61 classifications. Commercially available steel containers are presumed to be used for the disposal of piping, small components, and concrete. Larger components can serve as their own containers, with proper closure of all openings, access ways, and penetrations. The volumes are calculated based on the exterior package dimensions for containerized material or a specific calculation for components serving as their own waste containers.

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

The cost to dispose of the lowest level waste and the majority of the material generated from the decontamination and dismantling activities is based upon the current cost for disposal at EnergySolutions facility in Clive, Utah. Disposal costs for the higher activity waste (Class B and C) were based upon Entergys most current agreement with WCS for the Andrews County facility.

3.5.8 Site Conditions Following Decommissioning The NRC will amend or terminate the site license if it determines that site remediation has been performed in accordance with the license termination plan, and that the terminal radiation survey and associated documentation demonstrate that the facility is suitable for release. The 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 owners own future plans for the site.

A significant amount of the below grade piping is located around the perimeter of the power block. The estimate includes a cost to excavate this area to an average depth of six feet so as to expose the piping, duct bank,

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 16 of 52 TLG Services, LLC conduit, and any near-surface grounding grid. The overburden is surveyed and stockpiled on site for future use in backfilling the below grade voids.

Structures are removed to a nominal depth of three feet below grade. The voids are backfilled with clean debris and capped with soil. The site is then re-graded to conform to the adjacent landscape. Vegetation is established to inhibit erosion. These non-radiological costs are included in the total cost of decommissioning.

Concrete rubble generated from demolition activities is processed and made available as clean fill for the power block foundations. Intake structures are removed back to the embankment and the cooling tower demolished. The station grounds will be regraded such that the site will have a final contour consistent with adjacent surroundings, i.e., the configuration of the Dardanelle Reservoir and the Arkansas River will be maintained. The large underground tunnels between the water intake and turbine building will be isolated, sealed, and abandoned in place. Site utilities and service piping are abandoned in place. Electrical manholes are backfilled with suitable earthen material and abandoned. Asphalt surfaces in the immediate vicinity of site buildings are broken up and the material used for backfill on site, if needed.

The existing switchyard will remain in support of the electrical transmission and distribution system. Structures outside the secured owner controlled area (e.g., GSB) and access roads will also be left intact.

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

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

3.6.1 Estimating Basis Decommissioning costs are reported in the year of projected expenditure; however, the values are provided in 2024 dollars. Costs are not inflated, escalated, or discounted over the periods of performance.

The estimates rely upon the physical plant inventory that was the basis for the 2019 analysis, adjusted as appropriate.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 17 of 52 TLG Services, LLC 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.

3.6.2 Labor Costs EAL will engage a Decommissioning Operations Contractor (DOC) to manage the decommissioning. The DOC will provide field level planning and supervision of the work force.

EAL 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 EAL.

Reduction in the operating organization is assumed to be handled through normal company human resource practices (e.g., reassignment and outplacement). Personnel costs are based upon average salary information provided by EAL. Overhead costs are included for site and corporate support, reduced commensurate with the staffing of the project.

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

A profile of the staffing levels for decommissioning, including contractors and craft, is provided in Figures 3.1 and 3.2 for the two alternatives.

Utility staffing levels will gradually decrease after completing the removal of physical systems. Staffing levels and management support will vary based upon the amount and type of decommissioning work. Craft manpower levels decrease after systems removal and structures decontamination and drop substantially during the license termination survey period. However, craft levels increase again during the site restoration period due to the work associated with structures demolition.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 18 of 52 TLG Services, LLC Security, while reduced from operating levels, is maintained throughout the decommissioning for access control, material control, and to safeguard the spent fuel (in accordance with the requirements of 10 CFR Part 37, Part 72, and Part 73). Security costs include provisions for institutional overtime and recurring expenses while the pool is still operational. Once the fuel has been transferred to the DOE in 2083, the security organization will be reduced to Part 37 requirements.

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

The curie contents of the vessel and internals at final shutdown are derived from those listed in NUREG/CR-3474.[32] Actual estimates are derived from the curie/gram values contained therein and adjusted for the different mass of the ANO components, projected operating life, and different periods of decay. Additional short-lived isotopes were derived from NUREG/CR-0130[33] and NUREG/CR-0672,[34] and benchmarked to the long-lived values from NUREG/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 buildings is confined to the biological shield.

3.6.4 General Transition Activities Existing warehouses are cleared of non-essential material and remain for use by Entergy and its subcontractors. The warehouses are removed once they are no longer needed. The plants operating staff performs the following activities at no additional cost or credit to the project during the transition period:

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 19 of 52 TLG Services, LLC

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

• Process operating waste inventories. Disposal of operating wastes (e.g., filtration media, resins) during this initial period is not considered a decommissioning expense.

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

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

It is assumed, for purposes of this analysis, that any value received from the sale of scrap generated in the dismantling process would be more than offset by the on-site processing costs. The dismantling techniques assumed in the decommissioning estimates do not include the additional cost for size reduction and preparation to meet furnace ready conditions.

For example, the recovery of copper from electrical cabling may require the removal and disposition of any contaminated insulation, an added expense. With a volatile market, the potential profit margin in scrap recovery is highly speculative, regardless of the ability to free release this material. This assumption is an implicit recognition of scrap value in the disposal of clean metallic waste at no additional cost to the project.

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 20 of 52 TLG Services, LLC Energy For estimating purposes, the plant is assumed to be de-energized, with the exception of those facilities associated with spent fuel storage.

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

Emergency Planning FEMA fees associated with emergency planning are assumed to continue for approximately 18 months following the cessation of operations. At this time, the fees are discontinued. The timing is based upon the anticipated condition of the spent fuel (i.e., the hottest spent fuel assemblies are assumed to be cool enough that no substantial Zircaloy oxidation and off-site event would occur with the loss of spent fuel pool water). State and local fees continue until all fuel has been moved from the pool into dry storage (approximately five and one-half years following the cessation of operations).

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 provided in SECY-00-0145, Integrated Rulemaking Plan for Nuclear Power Plant Decommissioning.[35] The NRCs financial protection requirements are based on various reactor (and spent fuel) configurations.

Taxes Property taxes are included within the estimates. However, the tax is based upon the land, without any consideration of any ongoing site operations and property assets.

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.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 21 of 52 TLG Services, LLC 3.7 COST ESTIMATE

SUMMARY

Schedules of expenditures are provided in Tables 3.1 through 3.4. The tables delineate the cost contributors by year of expenditures as well as cost contributor (e.g., labor, materials, and waste disposal).

The tables in Appendices C and D provide additional detail. The cost elements in these tables are assigned to one of three subcategories: License Termination, Spent Fuel Management, and Site Restoration. The subcategory License Termination is used to accumulate costs that are consistent with decommissioning as defined by the NRC in its financial assurance regulations (i.e., 10 CFR §50.75). The cost reported for this subcategory is generally sufficient to terminate the plants operating license, recognizing that there may be some additional cost impact from spent fuel management. Costs are included for approximately one year prior to the permanent cessation of operations for pre-planning and decommissioning preparations. The License Termination cost subcategory also includes costs to decommission the ISFSI (as required by 10 CFR §72.30). The basis for the ISFSI decommissioning cost that is included in both Appendices C and D is provided in Appendix E.

The Spent Fuel Management subcategory contains costs associated with the containerization and transfer of spent fuel from the wet storage pool to the DOE and/or ISFSI for interim storage, as well as the transfer of the spent fuel in storage at the ISFSI to the DOE. Costs are also included for the operations of the pool and management of the ISFSI until such time that the transfer of all fuel from this facility to an off-site location (e.g., interim storage facility) is complete.

Site Restoration is used to capture costs associated with the dismantling and demolition of buildings and facilities demonstrated to be free from contamination. This includes structures never exposed to radioactive materials, as well as those facilities that have been decontaminated to appropriate levels.

Structures are removed to a depth of three feet and backfilled.

As discussed in Section 3.5.1, it is assumed that the DOE will not accept the GTCC waste prior to completing the transfer of spent fuel. Therefore, the cost of GTCC disposal is shown in the final year of ISFSI operation (for the DECON alternative). While designated for disposal at a federal facility along with the spent fuel, GTCC waste is still classified as low-level radioactive waste and, as such, is included as a License Termination expense.

Decommissioning costs are reported in 2024 dollars. Costs are not inflated, escalated, or discounted over the period of expenditure (or projected lifetime of

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 22 of 52 TLG Services, LLC the plant). The schedules are based upon the detailed activity costs reported in Appendices C and D, along with the timelines presented in Section 4.

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 23 of 52 ANO-1, DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2034 45,259 1,910 1,115 25 16,915 65,224 2035 92,005 30,839 2,687 10,857 45,499 181,888 2036 81,196 42,506 1,715 44,655 26,285 196,357 2037 70,786 26,534 1,541 28,180 19,720 146,761 2038 69,375 38,803 1,350 9,830 12,435 131,793 2039 70,366 49,096 1,276 9,710 11,785 142,234 2040 14,049 2,089 443 2,009 3,856 22,445 2041 6,817 219 360 7

2,942 10,345 2042 7,586 2,525 360 7

2,942 13,419 2043 6,990 736 360 7

2,942 11,035 2044 24,704 2,158 361 21 3,277 30,521 2045 19,219 6,628 208 5

2,440 28,500 2046 16,160 6,992 180 0

2,251 25,584 2047 6,072 2,444 46 0

1,240 9,802 2048 2,549 776 0

0 892 4,217 2049 2,456 518 0

0 889 3,863 2050 2,542 776 0

0 889 4,208 2051 2,284 0

0 0

889 3,173 2052 2,462 518 0

0 892 3,872 2053 2,456 518 0

0 889 3,863 2054 2,542 776 0

0 889 4,208 2055 2,456 518 0

0 889 3,863 2056 2,462 518 0

0 892 3,872 2057 2,456 518 0

0 889 3,863 2058 2,456 518 0

0 889 3,863 2059 2,456 518 0

0 889 3,863 2060 2,462 518 0

0 892 3,872 2061 2,370 259 0

0 889 3,518 2062 2,456 518 0

0 889 3,863 2063 2,370 259 0

0 889 3,518 TABLE 3.1 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 24 of 52 ANO-1, DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2064 2,376 259 0

0 892 3,527 2065 2,456 518 0

0 889 3,863 2066 2,370 259 0

0 889 3,518 2067 2,456 518 0

0 889 3,863 2068 2,376 259 0

0 892 3,527 2069 2,456 518 0

0 889 3,863 2070 2,370 259 0

0 889 3,518 2071 2,370 259 0

0 889 3,518 2072 2,462 518 0

0 892 3,872 2073 2,370 259 0

0 889 3,518 2074 2,456 518 0

0 889 3,863 2075 2,370 259 0

0 889 3,518 2076 2,462 518 0

0 892 3,872 2077 2,370 259 0

0 889 3,518 2078 2,370 259 0

0 889 3,518 2079 2,456 518 0

0 889 3,863 2080 2,376 259 0

0 892 3,527 2081 2,456 518 0

0 889 3,863 2082 2,370 259 0

0 889 3,518 2083 2,456 2,018 0

0 8,975 13,448 2084 3,526 1,726 10 2,401 4,871 12,534 Total 621,548 232,230 12,012 107,713 199,522 1,173,026 TABLE 3.1 (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 25 of 52 ANO-1, DECON ALTERNATIVE LICENSE TERMINATION EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2034 44,727 1,910 1,115 25 15,420 63,198 2035 86,466 18,965 2,687 10,857 43,124 162,099 2036 80,646 42,477 1,715 44,655 24,183 193,676 2037 70,221 26,508 1,541 28,180 17,623 144,073 2038 58,771 8,719 1,350 9,830 10,338 89,008 2039 56,142 8,687 1,276 9,710 9,911 85,726 2040 11,064 2,089 443 2,009 3,645 19,250 2041 3,577 219 360 7

2,730 6,893 2042 3,577 219 360 7

2,730 6,893 2043 3,577 219 360 7

2,730 6,893 2044 21,884 1,641 361 21 3,073 26,979 2045 5,232 388 56 5

664 6,345 2046 141 0

0 0

183 324 2047 36 0

0 0

47 84 2048 - 82 0

0 0

0 0

0 2083 88 1,500 0

0 8,109 9,697 2084 541 355 7

2,401 4,304 7,608 Total 446,690 113,896 11,631 107,713 148,814 828,744 TABLE 3.1a TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 26 of 52 ANO-1, DECON ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2034 0

0 0

0 1,494 1,494 2035 3,957 11,871 0

0 2,375 18,203 2036 0

0 0

0 2,103 2,103 2037 0

0 0

0 2,097 2,097 2038 10,021 30,062 0

0 2,097 42,179 2039 13,708 40,391 0

0 1,874 55,973 2040 2,985 0

0 0

211 3,196 2041 3,240 0

0 0

212 3,452 2042 4,009 2,306 0

0 212 6,527 2043 3,412 518 0

0 212 4,142 2044 2,820 518 0

0 204 3,542 2045 2,542 776 0

0 564 3,882 2046 2,456 517 0

0 631 3,605 2047 2,542 776 0

0 823 4,141 2048 2,549 776 0

0 892 4,217 2049 2,456 518 0

0 889 3,863 2050 2,542 776 0

0 889 4,208 2051 2,284 0

0 0

889 3,173 2052 2,462 518 0

0 892 3,872 2053 2,456 518 0

0 889 3,863 2054 2,542 776 0

0 889 4,208 2055 2,456 518 0

0 889 3,863 2056 2,462 518 0

0 892 3,872 2057 2,456 518 0

0 889 3,863 2058 2,456 518 0

0 889 3,863 2059 2,456 518 0

0 889 3,863 2060 2,462 518 0

0 892 3,872 2061 2,370 259 0

0 889 3,518 2062 2,456 518 0

0 889 3,863 2063 2,370 259 0

0 889 3,518 TABLE 3.1b TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 27 of 52 ANO-1, DECON ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2064 2,376 259 0

0 892 3,527 2065 2,456 518 0

0 889 3,863 2066 2,370 259 0

0 889 3,518 2067 2,456 518 0

0 889 3,863 2068 2,376 259 0

0 892 3,527 2069 2,456 518 0

0 889 3,863 2070 2,370 259 0

0 889 3,518 2071 2,370 259 0

0 889 3,518 2072 2,462 518 0

0 892 3,872 2073 2,370 259 0

0 889 3,518 2074 2,456 518 0

0 889 3,863 2075 2,370 259 0

0 889 3,518 2076 2,462 518 0

0 892 3,872 2077 2,370 259 0

0 889 3,518 2078 2,370 259 0

0 889 3,518 2079 2,456 518 0

0 889 3,863 2080 2,376 259 0

0 892 3,527 2081 2,456 518 0

0 889 3,863 2082 2,370 259 0

0 889 3,518 2083 2,368 518 0

0 866 3,752 2084 0

0 0

0 0

0 Total 139,042 103,259 0

0 47,122 289,423 TABLE 3.1b (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 28 of 52 ANO-1, DECON ALTERNATIVE SITE RESTORATION EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2034 532 0

0 0

0 532 2035 1,582 4

0 0

0 1,586 2036 550 29 0

0 0

579 2037 565 26 0

0 0

591 2038 584 22 0

0 0

606 2039 515 19 0

0 0

534 2040 0

0 0

0 0

0 2041 0

0 0

0 0

0 2042 0

0 0

0 0

0 2043 0

0 0

0 0

0 2044 0

0 0

0 0

0 2045 11,445 5,464 152 0

1,212 18,273 2046 13,564 6,475 180 0

1,437 21,655 2047 3,493 1,667 46 0

370 5,577 2048 - 83 0

0 0

0 0

0 2084 2,986 1,371 3

0 567 4,926 Total 35,816 15,076 381 0

3,585 54,858 TABLE 3.1c TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 29 of 52 ANO-2, DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2038 30,569 1,420 922 19 12,346 45,275 2039 79,798 26,208 2,925 2,506 37,473 148,909 2040 85,317 53,619 1,989 39,473 24,719 205,117 2041 80,721 40,891 1,788 33,725 20,957 178,082 2042 75,606 23,707 1,502 16,415 14,302 131,532 2043 78,794 33,271 1,502 16,415 14,302 144,284 2044 43,517 6,866 581 3,808 6,122 60,893 2045 22,516 18,542 232 5

3,847 45,141 2046 19,787 20,582 200 0

3,765 44,334 2047 6,964 5,818 52 0

1,630 14,464 2048 2,549 776 0

0 892 4,217 2049 2,456 518 0

0 890 3,863 2050 2,542 776 0

0 890 4,208 2051 2,456 518 0

0 890 3,863 2052 2,549 776 0

0 892 4,217 2053 2,284 0

0 0

890 3,173 2054 2,456 518 0

0 890 3,863 2055 2,456 518 0

0 890 3,863 2056 2,462 518 0

0 892 3,872 2057 2,456 518 0

0 890 3,863 2058 2,456 518 0

0 890 3,863 2059 2,542 776 0

0 890 4,208 2060 2,462 518 0

0 892 3,872 2061 2,456 518 0

0 890 3,863 2062 2,456 518 0

0 890 3,863 2063 2,456 518 0

0 890 3,863 2064 2,462 518 0

0 892 3,872 2065 2,456 518 0

0 890 3,863 2066 2,370 259 0

0 890 3,518 2067 2,456 518 0

0 890 3,863 TABLE 3.2 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 30 of 52 ANO-2, DECON ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2068 2,462 518 0

0 892 3,872 2069 2,456 518 0

0 890 3,863 2070 2,456 518 0

0 890 3,863 2071 2,456 518 0

0 890 3,863 2072 2,462 518 0

0 892 3,872 2073 2,370 259 0

0 890 3,518 2074 2,456 518 0

0 890 3,863 2075 2,456 518 0

0 890 3,863 2076 2,462 518 0

0 892 3,872 2077 2,456 518 0

0 890 3,863 2078 2,456 518 0

0 890 3,863 2079 2,370 259 0

0 890 3,518 2080 2,462 518 0

0 892 3,872 2081 2,456 518 0

0 890 3,863 2082 2,456 518 0

0 890 3,863 2083 2,370 1,759 0

0 9,832 13,960 2084 3,526 1,726 11 2,401 4,871 12,535 Total 615,416 252,261 11,704 114,767 185,322 1,179,470 TABLE 3.2 (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 31 of 52 ANO-2, DECON ALTERNATIVE LICENSE TERMINATION EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2038 30,354 1,420 922 19 11,235 43,949 2039 73,912 11,100 2,925 2,506 35,060 125,503 2040 80,220 42,787 1,989 39,473 22,604 187,074 2041 77,047 34,375 1,788 33,725 18,860 165,795 2042 70,052 11,649 1,502 16,415 12,205 111,823 2043 70,052 11,649 1,502 16,415 12,205 111,823 2044 40,851 5,829 581 3,808 5,797 56,866 2045 5,269 398 63 5

929 6,662 2046 77 0

0 0

357 434 2047 20 0

0 0

92 112 2048 - 82 0

0 0

0 0

0 2083 88 1,500 0

0 8,966 10,554 2084 541 355 7

2,401 4,304 7,609 Total 448,481 121,061 11,279 114,767 132,613 828,202 TABLE 3.2a TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 32 of 52 ANO-2, DECON ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2038 0

0 0

0 1,111 1,111 2039 5,036 15,108 0

0 2,413 22,557 2040 3,597 10,791 0

0 2,115 16,503 2041 2,158 6,475 0

0 2,097 10,730 2042 4,006 12,018 0

0 2,097 18,121 2043 7,194 21,583 0

0 2,097 30,874 2044 2,603 1,035 0

0 325 3,963 2045 2,542 776 0

0 625 3,943 2046 2,283 0

0 0

691 2,974 2047 2,456 518 0

0 838 3,812 2048 2,549 776 0

0 892 4,217 2049 2,456 518 0

0 890 3,863 2050 2,542 776 0

0 890 4,208 2051 2,456 518 0

0 890 3,863 2052 2,549 776 0

0 892 4,217 2053 2,284 0

0 0

890 3,173 2054 2,456 518 0

0 890 3,863 2055 2,456 518 0

0 890 3,863 2056 2,462 518 0

0 892 3,872 2057 2,456 518 0

0 890 3,863 2058 2,456 518 0

0 890 3,863 2059 2,542 776 0

0 890 4,208 2060 2,462 518 0

0 892 3,872 2061 2,456 518 0

0 890 3,863 2062 2,456 518 0

0 890 3,863 2063 2,456 518 0

0 890 3,863 2064 2,462 518 0

0 892 3,872 2065 2,456 518 0

0 890 3,863 2066 2,370 259 0

0 890 3,518 2067 2,456 518 0

0 890 3,863 TABLE 3.2b TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 33 of 52 ANO-2, DECON ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2068 2,462 518 0

0 892 3,872 2069 2,456 518 0

0 890 3,863 2070 2,456 518 0

0 890 3,863 2071 2,456 518 0

0 890 3,863 2072 2,462 518 0

0 892 3,872 2073 2,370 259 0

0 890 3,518 2074 2,456 518 0

0 890 3,863 2075 2,456 518 0

0 890 3,863 2076 2,462 518 0

0 892 3,872 2077 2,456 518 0

0 890 3,863 2078 2,456 518 0

0 890 3,863 2079 2,370 259 0

0 890 3,518 2080 2,462 518 0

0 892 3,872 2081 2,456 518 0

0 890 3,863 2082 2,456 518 0

0 890 3,863 2083 2,282 259 0

0 866 3,407 2084 0

0 0

0 0

0 Total 120,088 86,416 0

0 46,432 252,937 TABLE 3.2b (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 34 of 52 ANO-2, DECON ALTERNATIVE SITE RESTORATION EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2038 215 0

0 0

0 215 2039 849 0

0 0

0 849 2040 1,500 40 0

0 0

1,540 2041 1,516 41 0

0 0

1,557 2042 1,548 40 0

0 0

1,588 2043 1,548 40 0

0 0

1,588 2044 64 2

0 0

0 65 2045 14,706 17,368 169 0

2,293 34,535 2046 17,427 20,582 200 0

2,717 40,927 2047 4,488 5,301 52 0

700 10,540 2048 - 83 0

0 0

0 0

0 2084 2,986 1,371 3

0 567 4,926 Total 46,847 44,783 424 0

6,276 98,331 TABLE 3.2c TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 35 of 52 ANO-1, SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2034 35,976 1,466 1,115 25 16,526 55,108 2035 57,612 19,203 1,627 927 42,483 121,851 2036 17,557 671 361 15 10,235 28,838 2037 17,509 669 360 15 10,207 28,759 2038 27,530 30,731 360 15 10,207 68,842 2039 29,393 41,030 339 14 9,186 79,962 2040 4,111 420 181 7

1,552 6,271 2041 4,100 419 180 7

1,548 6,254 2042 4,869 2,725 180 7

1,548 9,328 2043 4,273 937 180 7

1,548 6,944 2044 4,284 938 181 7

1,552 6,961 2045 4,359 1,195 180 7

1,548 7,289 2046 4,273 937 180 7

1,548 6,944 2047 4,359 1,195 180 7

1,548 7,289 2048 4,370 1,197 181 7

1,552 7,306 2049 4,273 937 180 7

1,548 6,944 2050 4,359 1,195 180 7

1,548 7,289 2051 4,100 419 180 7

1,548 6,254 2052 4,284 938 181 7

1,552 6,961 2053 4,273 937 180 7

1,548 6,944 2054 4,359 1,195 180 7

1,548 7,289 2055 4,273 937 180 7

1,548 6,944 2056 4,284 938 181 7

1,552 6,961 2057 4,273 937 180 7

1,548 6,944 2058 4,273 937 180 7

1,548 6,944 2059 4,273 937 180 7

1,548 6,944 2060 4,284 938 181 7

1,552 6,961 2061 4,186 678 180 7

1,548 6,599 2062 4,273 937 180 7

1,548 6,944 2063 4,186 678 180 7

1,548 6,599 TABLE 3.3 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 36 of 52 ANO-1, SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2064 4,198 679 181 7

1,552 6,616 2065 4,273 937 180 7

1,548 6,944 2066 4,186 678 180 7

1,548 6,599 2067 4,273 937 180 7

1,548 6,944 2068 4,198 679 181 7

1,552 6,616 2069 4,273 937 180 7

1,548 6,944 2070 4,186 678 180 7

1,548 6,599 2071 4,186 678 180 7

1,548 6,599 2072 4,284 938 181 7

1,552 6,961 2073 4,186 678 180 7

1,548 6,599 2074 4,273 937 180 7

1,548 6,944 2075 4,186 678 180 7

1,548 6,599 2076 4,284 938 181 7

1,552 6,961 2077 4,186 678 180 7

1,548 6,599 2078 4,186 678 180 7

1,548 6,599 2079 4,273 937 180 7

1,548 6,944 2080 4,198 679 181 7

1,552 6,616 2081 4,273 937 180 7

1,548 6,944 2082 4,186 678 180 7

1,548 6,599 2083 4,273 937 180 7

1,548 6,944 2084 1,981 414 181 7

1,208 3,791 2085 1,976 413 180 7

1,205 3,780 2086 1,976 413 180 7

1,205 3,780 2087 35,124 3,855 1,241 24 3,906 44,151 2088 59,958 14,345 1,791 9,938 9,316 95,349 2089 65,059 45,318 1,710 47,993 22,791 182,872 2090 46,089 16,919 1,424 18,056 12,457 94,945 2091 41,183 9,574 1,350 10,314 9,784 72,206 2092 10,501 2,398 592 2,407 3,820 19,717 2093 12,607 1,121 360 16 2,165 16,270 TABLE 3.3 (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 37 of 52 ANO-1, SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2094 20,316 5,362 249 11 1,818 27,755 2095 14,397 7,127 180 0

1,452 23,155 2096 6,942 3,437 87 0

700 11,165 Total 691,190 243,856 21,613 90,086 238,809 1,285,554 TABLE 3.3 (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 38 of 52 ANO-1, SAFSTOR ALTERNATIVE LICENSE TERMINATION EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2034 35,976 1,466 1,115 25 15,032 53,614 2035 53,388 7,332 1,627 927 40,026 103,299 2036 15,331 671 361 15 7,455 23,832 2037 15,289 669 360 15 7,434 23,767 2038 15,289 669 360 15 7,434 23,767 2039 13,705 640 339 14 6,702 21,399 2040 1,844 420 181 7

1,221 3,673 2041 1,839 419 180 7

1,218 3,663 2042 1,839 419 180 7

1,218 3,663 2043 1,839 419 180 7

1,218 3,663 2044 1,844 420 181 7

1,221 3,673 2045 1,839 419 180 7

1,218 3,663 2046 1,839 419 180 7

1,218 3,663 2047 1,839 419 180 7

1,218 3,663 2048 1,844 420 181 7

1,221 3,673 2049 1,839 419 180 7

1,218 3,663 2050 1,839 419 180 7

1,218 3,663 2051 1,839 419 180 7

1,218 3,663 2052 1,844 420 181 7

1,221 3,673 2053 1,839 419 180 7

1,218 3,663 2054 1,839 419 180 7

1,218 3,663 2055 1,839 419 180 7

1,218 3,663 2056 1,844 420 181 7

1,221 3,673 2057 1,839 419 180 7

1,218 3,663 2058 1,839 419 180 7

1,218 3,663 2059 1,839 419 180 7

1,218 3,663 2060 1,844 420 181 7

1,221 3,673 2061 1,839 419 180 7

1,218 3,663 2062 1,839 419 180 7

1,218 3,663 2063 1,839 419 180 7

1,218 3,663 TABLE 3.3a TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 39 of 52 ANO-1, SAFSTOR ALTERNATIVE LICENSE TERMINATION EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2064 1,844 420 181 7

1,221 3,673 2065 1,839 419 180 7

1,218 3,663 2066 1,839 419 180 7

1,218 3,663 2067 1,839 419 180 7

1,218 3,663 2068 1,844 420 181 7

1,221 3,673 2069 1,839 419 180 7

1,218 3,663 2070 1,839 419 180 7

1,218 3,663 2071 1,839 419 180 7

1,218 3,663 2072 1,844 420 181 7

1,221 3,673 2073 1,839 419 180 7

1,218 3,663 2074 1,839 419 180 7

1,218 3,663 2075 1,839 419 180 7

1,218 3,663 2076 1,844 420 181 7

1,221 3,673 2077 1,839 419 180 7

1,218 3,663 2078 1,839 419 180 7

1,218 3,663 2079 1,839 419 180 7

1,218 3,663 2080 1,844 420 181 7

1,221 3,673 2081 1,839 419 180 7

1,218 3,663 2082 1,839 419 180 7

1,218 3,663 2083 1,839 419 180 7

1,218 3,663 2084 1,981 414 181 7

1,208 3,791 2085 1,976 413 180 7

1,205 3,780 2086 1,976 413 180 7

1,205 3,780 2087 34,531 3,855 1,241 24 3,906 43,557 2088 58,354 14,340 1,791 9,938 9,316 93,740 2089 64,392 45,287 1,710 47,993 22,791 182,174 2090 45,414 16,893 1,424 18,056 12,457 94,244 2091 40,505 9,549 1,350 10,314 9,784 71,503 2092 10,343 2,392 592 2,407 3,820 19,554 2093 12,607 1,121 360 16 2,165 16,270 TABLE 3.3a (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 40 of 52 ANO-1, SAFSTOR ALTERNATIVE LICENSE TERMINATION EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2094 11,489 949 137 11 919 13,505 2095 141 0

0 0

0 141 2096 68 0

0 0

0 68 Total 513,741 125,527 21,235 90,086 206,486 957,075 TABLE 3.3a (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 41 of 52 ANO-1, SAFSTOR ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2034 0

0 0

0 1,494 1,494 2035 4,224 11,871 0

0 2,457 18,552 2036 2,226 0

0 0

2,780 5,006 2037 2,220 0

0 0

2,772 4,992 2038 12,240 30,062 0

0 2,772 45,074 2039 15,688 40,391 0

0 2,485 58,563 2040 2,267 0

0 0

331 2,597 2041 2,261 0

0 0

330 2,590 2042 3,029 2,306 0

0 330 5,665 2043 2,433 518 0

0 330 3,280 2044 2,439 518 0

0 331 3,287 2045 2,519 776 0

0 330 3,625 2046 2,433 518 0

0 330 3,280 2047 2,519 776 0

0 330 3,625 2048 2,526 776 0

0 331 3,632 2049 2,433 518 0

0 330 3,280 2050 2,519 776 0

0 330 3,625 2051 2,261 0

0 0

330 2,590 2052 2,439 518 0

0 331 3,287 2053 2,433 518 0

0 330 3,280 2054 2,519 776 0

0 330 3,625 2055 2,433 518 0

0 330 3,280 2056 2,439 518 0

0 331 3,287 2057 2,433 518 0

0 330 3,280 2058 2,433 518 0

0 330 3,280 2059 2,433 518 0

0 330 3,280 2060 2,439 518 0

0 331 3,287 2061 2,347 259 0

0 330 2,935 2062 2,433 518 0

0 330 3,280 2063 2,347 259 0

0 330 2,935 TABLE 3.3b TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 42 of 52 ANO-1, SAFSTOR ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2064 2,353 259 0

0 331 2,942 2065 2,433 518 0

0 330 3,280 2066 2,347 259 0

0 330 2,935 2067 2,433 518 0

0 330 3,280 2068 2,353 259 0

0 331 2,942 2069 2,433 518 0

0 330 3,280 2070 2,347 259 0

0 330 2,935 2071 2,347 259 0

0 330 2,935 2072 2,439 518 0

0 331 3,287 2073 2,347 259 0

0 330 2,935 2074 2,433 518 0

0 330 3,280 2075 2,347 259 0

0 330 2,935 2076 2,439 518 0

0 331 3,287 2077 2,347 259 0

0 330 2,935 2078 2,347 259 0

0 330 2,935 2079 2,433 518 0

0 330 3,280 2080 2,353 259 0

0 331 2,942 2081 2,433 518 0

0 330 3,280 2082 2,347 259 0

0 330 2,935 2083 2,433 518 0

0 330 3,280 2084 - 96 0

0 0

0 0

0 Total 143,118 103,259 0

0 29,273 275,649 TABLE 3.3b (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 43 of 52 ANO-1, SAFSTOR ALTERNATIVE SITE RESTORATION EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2034 - 86 0

0 0

0 0

0 2087 593 0

0 0

0 593 2088 1,604 5

0 0

0 1,609 2089 666 31 0

0 0

698 2090 676 26 0

0 0

702 2091 678 25 0

0 0

703 2092 158 6

0 0

0 164 2093 0

0 0

0 0

0 2094 8,827 4,413 111 0

899 14,250 2095 14,255 7,127 180 0

1,452 23,014 2096 6,874 3,437 87 0

700 11,097 Total 34,331 15,070 378 0

3,050 52,830 TABLE 3.3c TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 44 of 52 ANO-2, SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2038 25,355 1,090 922 19 12,202 39,587 2039 62,707 23,066 2,003 897 38,361 127,034 2040 23,912 11,713 463 90 10,705 46,883 2041 21,035 7,161 401 15 10,046 38,658 2042 22,883 12,705 401 15 10,046 46,049 2043 26,071 22,269 401 15 10,046 58,802 2044 5,181 1,471 209 7

1,881 8,749 2045 4,481 1,200 200 7

1,526 7,415 2046 4,222 424 200 7

1,526 6,380 2047 4,395 942 200 7

1,526 7,070 2048 4,493 1,201 201 7

1,530 7,432 2049 4,395 942 200 7

1,526 7,070 2050 4,481 1,200 200 7

1,526 7,415 2051 4,395 942 200 7

1,526 7,070 2052 4,493 1,201 201 7

1,530 7,432 2053 4,222 424 200 7

1,526 6,380 2054 4,395 942 200 7

1,526 7,070 2055 4,395 942 200 7

1,526 7,070 2056 4,406 943 201 7

1,530 7,087 2057 4,395 942 200 7

1,526 7,070 2058 4,395 942 200 7

1,526 7,070 2059 4,481 1,200 200 7

1,526 7,415 2060 4,406 943 201 7

1,530 7,087 2061 4,395 942 200 7

1,526 7,070 2062 4,395 942 200 7

1,526 7,070 2063 4,395 942 200 7

1,526 7,070 2064 4,406 943 201 7

1,530 7,087 2065 4,395 942 200 7

1,526 7,070 2066 4,308 683 200 7

1,526 6,725 2067 4,395 942 200 7

1,526 7,070 TABLE 3.4 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 45 of 52 ANO-2, SAFSTOR ALTERNATIVE SCHEDULE OF TOTAL ANNUAL EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2068 4,406 943 201 7

1,530 7,087 2069 4,395 942 200 7

1,526 7,070 2070 4,395 942 200 7

1,526 7,070 2071 4,395 942 200 7

1,526 7,070 2072 4,406 943 201 7

1,530 7,087 2073 4,308 683 200 7

1,526 6,725 2074 4,395 942 200 7

1,526 7,070 2075 4,395 942 200 7

1,526 7,070 2076 4,406 943 201 7

1,530 7,087 2077 4,395 942 200 7

1,526 7,070 2078 4,395 942 200 7

1,526 7,070 2079 4,308 683 200 7

1,526 6,725 2080 4,406 943 201 7

1,530 7,087 2081 4,395 942 200 7

1,526 7,070 2082 4,395 942 200 7

1,526 7,070 2083 4,308 683 200 7

1,526 6,725 2084 1,862 417 201 6

1,122 3,608 2085 1,857 416 200 6

1,119 3,599 2086 1,857 416 200 6

1,119 3,599 2087 1,857 416 200 6

1,119 3,599 2088 12,403 1,596 739 14 2,335 17,087 2089 38,097 5,606 2,003 33 5,381 51,120 2090 61,544 39,617 1,924 38,686 19,090 160,861 2091 64,307 33,532 1,737 35,769 18,501 153,846 2092 60,605 13,549 1,506 17,516 12,852 106,028 2093 48,557 9,159 1,065 10,540 8,960 78,281 2094 22,892 14,121 277 11 2,815 40,115 2095 18,196 21,234 200 0

2,634 42,264 2096 8,774 10,239 97 0

1,270 20,379 Total 701,190 265,746 22,966 103,918 231,167 1,324,988 TABLE 3.4 (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 46 of 52 ANO-2, SAFSTOR ALTERNATIVE LICENSE TERMINATION EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2038 25,355 1,090 922 19 11,091 38,477 2039 57,671 7,958 2,003 897 35,948 104,477 2040 18,047 922 463 90 7,974 27,495 2041 16,526 686 401 15 7,310 24,938 2042 16,526 686 401 15 7,310 24,938 2043 16,526 686 401 15 7,310 24,938 2044 2,522 436 209 7

1,449 4,622 2045 1,916 424 200 7

1,194 3,741 2046 1,916 424 200 7

1,194 3,741 2047 1,916 424 200 7

1,194 3,741 2048 1,921 425 201 7

1,197 3,751 2049 1,916 424 200 7

1,194 3,741 2050 1,916 424 200 7

1,194 3,741 2051 1,916 424 200 7

1,194 3,741 2052 1,921 425 201 7

1,197 3,751 2053 1,916 424 200 7

1,194 3,741 2054 1,916 424 200 7

1,194 3,741 2055 1,916 424 200 7

1,194 3,741 2056 1,921 425 201 7

1,197 3,751 2057 1,916 424 200 7

1,194 3,741 2058 1,916 424 200 7

1,194 3,741 2059 1,916 424 200 7

1,194 3,741 2060 1,921 425 201 7

1,197 3,751 2061 1,916 424 200 7

1,194 3,741 2062 1,916 424 200 7

1,194 3,741 2063 1,916 424 200 7

1,194 3,741 2064 1,921 425 201 7

1,197 3,751 2065 1,916 424 200 7

1,194 3,741 2066 1,916 424 200 7

1,194 3,741 2067 1,916 424 200 7

1,194 3,741 TABLE 3.4a TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 47 of 52 ANO-2, SAFSTOR ALTERNATIVE LICENSE TERMINATION EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2068 1,921 425 201 7

1,197 3,751 2069 1,916 424 200 7

1,194 3,741 2070 1,916 424 200 7

1,194 3,741 2071 1,916 424 200 7

1,194 3,741 2072 1,921 425 201 7

1,197 3,751 2073 1,916 424 200 7

1,194 3,741 2074 1,916 424 200 7

1,194 3,741 2075 1,916 424 200 7

1,194 3,741 2076 1,921 425 201 7

1,197 3,751 2077 1,916 424 200 7

1,194 3,741 2078 1,916 424 200 7

1,194 3,741 2079 1,916 424 200 7

1,194 3,741 2080 1,921 425 201 7

1,197 3,751 2081 1,916 424 200 7

1,194 3,741 2082 1,916 424 200 7

1,194 3,741 2083 1,916 424 200 7

1,194 3,741 2084 1,862 417 201 6

1,122 3,608 2085 1,857 416 200 6

1,119 3,599 2086 1,857 416 200 6

1,119 3,599 2087 1,857 416 200 6

1,119 3,599 2088 12,256 1,596 739 14 2,335 16,939 2089 37,368 5,606 2,003 33 5,381 50,391 2090 59,830 39,579 1,924 38,686 19,090 159,109 2091 62,498 33,485 1,737 35,769 18,501 151,991 2092 58,815 13,503 1,506 17,516 12,852 104,192 2093 47,481 9,132 1,065 10,540 8,960 77,178 2094 11,673 973 153 11 1,184 13,994 2095 77 0

0 0

0 77 2096 37 0

0 0

0 37 Total 525,405 134,551 22,545 103,918 197,766 984,185 TABLE 3.4a (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 48 of 52 ANO-2, SAFSTOR ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2038 0

0 0

0 1,111 1,111 2039 5,036 15,108 0

0 2,413 22,557 2040 5,865 10,791 0

0 2,731 19,387 2041 4,510 6,475 0

0 2,736 13,720 2042 6,357 12,018 0

0 2,736 21,112 2043 9,546 21,583 0

0 2,736 33,864 2044 2,659 1,035 0

0 432 4,127 2045 2,565 776 0

0 332 3,674 2046 2,306 0

0 0

332 2,639 2047 2,479 517 0

0 332 3,329 2048 2,571 776 0

0 333 3,681 2049 2,479 517 0

0 332 3,329 2050 2,565 776 0

0 332 3,674 2051 2,479 517 0

0 332 3,329 2052 2,571 776 0

0 333 3,681 2053 2,306 0

0 0

332 2,639 2054 2,479 517 0

0 332 3,329 2055 2,479 517 0

0 332 3,329 2056 2,485 517 0

0 333 3,336 2057 2,479 517 0

0 332 3,329 2058 2,479 517 0

0 332 3,329 2059 2,565 776 0

0 332 3,674 2060 2,485 517 0

0 333 3,336 2061 2,479 517 0

0 332 3,329 2062 2,479 517 0

0 332 3,329 2063 2,479 517 0

0 332 3,329 2064 2,485 517 0

0 333 3,336 2065 2,479 517 0

0 332 3,329 2066 2,393 259 0

0 332 2,984 2067 2,479 517 0

0 332 3,329 TABLE 3.4b TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 49 of 52 ANO-2, SAFSTOR ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2068 2,485 517 0

0 333 3,336 2069 2,479 517 0

0 332 3,329 2070 2,479 517 0

0 332 3,329 2071 2,479 517 0

0 332 3,329 2072 2,485 517 0

0 333 3,336 2073 2,393 259 0

0 332 2,984 2074 2,479 517 0

0 332 3,329 2075 2,479 517 0

0 332 3,329 2076 2,485 517 0

0 333 3,336 2077 2,479 517 0

0 332 3,329 2078 2,479 517 0

0 332 3,329 2079 2,393 259 0

0 332 2,984 2080 2,485 517 0

0 333 3,336 2081 2,479 517 0

0 332 3,329 2082 2,479 517 0

0 332 3,329 2083 2,393 259 0

0 332 2,984 2084 - 96 0

0 0

0 0

0 Total 130,445 86,416 0

0 27,866 244,728 TABLE 3.4b (continued)

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Section 3, Page 50 of 52 ANO-2, SAFSTOR ALTERNATIVE SITE RESTORATION EXPENDITURES (Thousands of 2024 Dollars)

Year Labor Equipment

& Materials Energy Burial Other Total 2038 - 87 0

0 0

0 0

0 2088 147 0

0 0

0 147 2089 729 0

0 0

0 729 2090 1,714 38 0

0 0

1,752 2091 1,809 47 0

0 0

1,856 2092 1,790 46 0

0 0

1,836 2093 1,076 28 0

0 0

1,104 2094 11,219 13,148 124 0

1,631 26,121 2095 18,119 21,234 200 0

2,634 42,187 2096 8,737 10,239 97 0

1,270 20,342 Total 45,340 44,779 421 0

5,534 96,074 TABLE 3.4c TLG Services, LLC

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 51 of 52 TLG Services, LLC FIGURE 3.1 DECOMMISSIONING PERSONNEL LEVELS DECON 0

100 200 300 400 500 600 700 FTEs Year Craft Utility DOC Security Other Staff Total

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 3, Page 52 of 52 TLG Services, LLC FIGURE 3.2 DECOMMISSIONING PERSONNEL LEVELS SAFSTOR 0

100 200 300 400 500 600 700 FTEs Year Craft Utility DOC Security Other Staff Total

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 1 of 7 TLG Services, LLC

4. SCHEDULE ESTIMATE The schedules for the decommissioning scenarios considered in this analysis follow the sequences presented in the AIF/NESP-036 study, with minor changes to reflect recent experience and site-specific constraints. In addition, the scheduling has been revised to reflect the spent fuel management described in Section 3.5.1.

A schedule or sequence of activities for the DECON alternative is presented in Figure 4.1. The scheduling sequence is based on the fuel being removed from the spent fuel pools within five and one half years. The key activities listed in the schedule do not reflect a one-to-one correspondence with those activities in the cost tables, but reflect dividing some activities for clarity and combining others for convenience. The schedule was prepared using the "Microsoft Project Professional" computer software.[36]

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

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

Decontamination and dismantling of the storage pools is initiated once the transfer of spent fuel is complete (DECON option).

• All work (except reactor vessel and reactor vessel internals removal and the spent fuel loading campaigns) is performed during an 8-hour workday, 5 days per week, with no overtime.

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

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 2 of 7 TLG Services, LLC 4.2 PROJECT SCHEDULE The period-dependent costs presented in the detailed cost tables are based upon the durations developed in the schedules for decommissioning. Durations are established between several milestones in each project period; these durations are used to establish a critical path for the entire project. In turn, the critical path duration for each period is used as the basis for determining the period-dependent costs. A second critical path is shown for the spent fuel storage period, which determines the release of the auxiliary buildings for final decontamination.

Project timelines are provided in Figures 4.2 and 4.3 with milestone dates based on the 2034 and 2038 shutdown dates for Units 1 and 2, respectively. The fuel pools are emptied approximately five and one half years after shutdown, while ISFSI operations continue until the DOE can complete the transfer of assemblies.

Deferred decommissioning in the SAFSTOR scenarios is assumed to commence so that the operating licenses are terminated within a 60-year period from the cessation of plant operations.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 3 of 7 TLG Services, LLC FIGURE 4.1 DECON ACTIVITY SCHEDULE

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 4 of 7 TLG Services, LLC FIGURE 4.1 (continued)

DECON ACTIVITY SCHEDULE

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 5 of 7 TLG Services, LLC FIGURE 4.1 (continued)

DECON ACTIVITY SCHEDULE

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 6 of 7 TLG Services, LLC FIGURE 4.2 DECOMMISSIONING TIMELINE DECON

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 4, Page 7 of 7 TLG Services, LLC FIGURE 4.3 DECOMMISSIONING TIMELINE SAFSTOR

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 1 of 6 TLG Services, LLC

5. RADIOACTIVE WASTES The objectives of the decommissioning process are the removal of all radioactive material from the site that would restrict its future use and the termination of the NRC license. This currently requires the remediation of all radioactive material at the site in excess of applicable legal limits. Under the Atomic Energy Act,[37] the NRC is responsible for protecting the public from sources of ionizing radiation. Title 10 of the Code of Federal Regulations delineates the production, utilization, and disposal of radioactive materials and processes. In particular, Part 71 defines radioactive material as it pertains to transportation and Part 61 specifies its disposition.

Most of the materials being transported for controlled burial are categorized as Low Specific Activity (LSA) or Surface Contaminated Object (SCO) materials containing Type A quantities, as defined in 49 CFR Parts 173-178. Shipping containers are required to be Industrial Packages (IP-1, IP-2 or IP-3, as defined in 10 CFR §173.411).

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

The destinations for the various waste streams from decommissioning are identified in Figures 5.1 and 5.2. The volumes are shown on a line-item basis in Appendices C and D and summarized in Tables 5.1 and 5.2. The volumes are calculated based on the exterior dimensions for containerized material and on the volume of components serving as their own waste containers.

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

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

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 2 of 6 TLG Services, LLC The waste material produced in the decontamination and dismantling of the nuclear plant is primarily generated during Period 2 of DECON and Period 4 of SAFSTOR.

Material that is considered potentially contaminated when removed from the radiological controlled area is sent to processing facilities in Tennessee for conditioning and disposal. Heavily contaminated components and activated materials are routed for controlled disposal. The disposal volumes reported in the tables reflect the savings resulting from reprocessing and recycling.

For purposes of constructing the estimates, the current cost for disposal at EnergySolutions facility in Clive, Utah was used for a majority of the radioactive waste produced from the decommissioning activities. Separate rates were used for containerized waste and large components.

Demolition debris including miscellaneous steel, scaffolding, and concrete was disposed of at a bulk rate. The decommissioning waste stream also included resins and dry active waste.

Since EnergySolutions is not currently able to receive the more highly radioactive components generated in the decontamination and dismantling of the reactor, disposal costs for the Class B and C material were based upon Entergys most current agreement with WCS for the Andrews County disposal facility.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 3 of 6 TLG Services, LLC Decommissioning Low-Level Radioactive Waste Streams DAW Resin / Filters (Class A)

Resin NSSS Decontamination (Class B/C)

Direct Burial Large Components and Containerized Waste Reactor Waste (Classes B/C)

Bulk Waste (Contaminated Soil and Concrete)

Metal Processing EnergySolutions Clive, Utah EnergySolutions Oak Ridge, TN Waste Control Specialists Andrews County, Texas Reactor Waste (Class A)

Reactor Waste (Class GTCC)

Geologic Disposal Federal Facility FIGURE 5.1 RADIOACTIVE WASTE DISPOSITION

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 4 of 6 TLG Services, LLC FIGURE 5.2 DECOMMISSIONING WASTE DESTINATIONS RADIOLOGICAL Waste Control Specialists Andrews County, TX EnergySolutions Clive, UT EnergySolutions Oak Ridge, TN ANO

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 5 of 6 TLG Services, LLC TABLE 5.1 DECON ALTERNATIVE DECOMMISSIONING WASTE

SUMMARY

Waste Cost Basis Class [1]

Waste Volume (cubic feet)

Weight (pounds)

Low-Level Radioactive Waste (near-surface disposal)

EnergySolutions Containerized A

349,524 25,550,660 EnergySolutions Bulk A

176,150 8,243,323 WCS B

3,212 382,473 WCS C

729 101,900 Greater than Class C (geologic repository)

Spent Fuel Equivalent GTCC 3,547 710,641 Processed/Conditioned (off-site recycling center)

Recycling Vendors A

696,830 27,660,516 Total [2]

1,229,992 62,649,513

[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.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 5, Page 6 of 6 TLG Services, LLC TABLE 5.2 SAFSTOR ALTERNATIVE DECOMMISSIONING WASTE

SUMMARY

Waste Cost Basis Class [1]

Waste Volume (cubic feet)

Weight (pounds)

Low-Level Radioactive Waste (near-surface disposal)

EnergySolutions Containerized A

180,661 16,928,702 EnergySolutions Bulk A

254,494 11,705,364 WCS B

1,502 155,287 WCS C

729 101,900 Greater than Class C (geologic repository)

Spent Fuel Equivalent GTCC 3,547 710,641 Processed/Conditioned (off-site recycling center)

Recycling Vendors A

778,321 31,013,930 Total [2]

1,219,254 60,615,824

[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.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 1 of 5 TLG Services, LLC

6. RESULTS The analysis to estimate the costs to decommission ANO relied upon the site-specific, technical information developed for a previous analysis prepared in 2019. While not an engineering study, the estimates provide the owner 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 cost projected to promptly decommission the station (DECON), dismantle the structures, and manage the spent fuel is estimated to be $2.352 billion. The majority of this cost (approximately 70.4%) is associated with the physical decontamination and dismantling of the nuclear plant so that the operating license can be terminated.

Another 23.1% is associated with the management, interim storage, and eventual transfer of the spent fuel. The remaining 6.5% is for the demolition of the designated structures and limited restoration of the site.

The cost projected for deferred decommissioning (SAFSTOR) is estimated to be $2.611 billion. The majority of this cost (approximately 74.4%) is associated with placing the plant in storage, ongoing caretaking of the plant during dormancy, and the eventual physical decontamination and dismantling of the nuclear plant so that the operating license can be terminated. Another 19.9% is associated with the management, interim storage, and eventual transfer of the spent fuel. The remaining 5.7% is for the demolition of the designated structures and limited restoration of the site.

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

Program management is the largest single contributor to the overall cost. The magnitude of the expense is a function of both the size of the organization required to manage the decommissioning, as well as the duration of the program. It is assumed, for purposes of this analysis, that Entergy Operations will oversee the decommissioning program and manage the decommissioning labor force (with the exception of the ISFSI decommissioning discussed in Section 3.4.1 above). The size and composition of the management organization varies with the decommissioning phase and associated site activities. However, once the operating license is amended or 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).

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 2 of 5 TLG Services, LLC 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 will be isolated and an independent spent fuel island created. This will allow decommissioning operations to proceed in and around the pool area. Over the five and one half-year period, the spent fuel will be packaged into canisters assumed to be loaded into a DOE-provided transport cask or relocated to the ISFSI.

The cost for waste disposal includes only those costs associated with the controlled disposition of the low-level radioactive waste generated from decontamination and dismantling activities, including plant equipment and components, structural material, filters, resins and dry-active waste. As described in Section 5, disposition of the majority of the low-level radioactive material requiring controlled disposal is at the EnergySolutions facility. Highly activated components, requiring additional isolation from the environment (GTCC), are packaged for geologic disposal. The cost of geologic disposal is based upon a cost equivalent for spent fuel.

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

The cost identified in the summary tables for processing is all-inclusive, incorporating the ultimate disposition of the material.

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

Decontamination and packaging costs also have a large labor component that is based upon prevailing 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.

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

Decontamination is used to reduce the 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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 3 of 5 TLG Services, LLC contaminated plant components and equipment can be decontaminated for uncontrolled release in-situ. Centralized processing centers have proven to be a more economical means of handling the large volumes of material produced in the dismantling of a nuclear plant.

License termination survey costs are associated with the labor intensive and complex activity of verifying that contamination has been removed from the site to the levels specified by the regulating agency. This process involves a systematic survey of all remaining plant surface areas and surrounding environs, sampling, isotopic analysis, and documentation of the findings. The status of any plant components and materials not removed in the decommissioning process will also require confirmation and will add to the expense of surveying the facilities alone.

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 4 of 5 TLG Services, LLC TABLE 6.1 DECON ALTERNATIVE DECOMMISSIONING COST ELEMENTS (thousands of 2024 dollars)

Cost Element Unit 1 Unit 2 Total Decontamination 15,431 16,761 32,192 1.4%

Removal 133,367 186,741 320,108 13.6%

Packaging 35,497 39,340 74,837 3.2%

Transportation 26,300 25,862 52,162 2.2%

Waste Disposal 88,677 68,312 156,989 6.7%

Off-site Waste Processing 27,510 56,150 83,659 3.6%

Program Management[1]

345,058 351,111 696,169 29.6%

Security 154,408 130,951 285,359 12.1%

Spent Fuel Pool Isolation 17,313 11,542 28,855 1.2%

Spent Fuel Management[2]

166,655 143,880 310,535 13.2%

Insurance and Regulatory Fees 28,220 21,886 50,106 2.1%

Energy 12,012 11,704 23,716 1.0%

Characterization and Licensing Surveys 24,197 21,503 45,700 1.9%

Property Taxes 151 96 247 0.01%

Miscellaneous Equipment 9,081 9,380 18,461 0.8%

Corporate A&G 66,325 61,538 127,863 5.4%

Indirect Overhead 12,389 12,198 24,587 1.0%

Miscellaneous Site Services 10,439 10,513 20,952 0.9%

Total [3]

1,173,026 1,179,470 2,352,495 100.0 Cost Element Unit 1 Unit 2 Total License Termination 828,744 828,202 1,656,946 70.4%

Spent Fuel Management 289,423 252,937 542,360 23.1%

Site Restoration 54,858 98,331 153,189 6.5%

Total [3]

1,173,026 1,179,470 2,352,495 100.0

[1]

Includes engineering costs

[2] Includes costs for operating the spent fuel pools and ISFSI, emergency planning and the cost to transfer the fuel to the DOE and/or ISFSI

[3] Columns may not add due to rounding

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 6, Page 5 of 5 TLG Services, LLC TABLE 6.2 SAFSTOR ALTERNATIVE DECOMMISSIONING COST ELEMENTS (thousands of 2024 dollars)

Cost Element Unit 1 Unit 2 Total Decontamination 16,012 18,242 34,254 1.3%

Removal 139,096 194,390 333,486 12.8%

Packaging 25,873 30,879 56,753 2.2%

Transportation 22,433 23,615 46,048 1.8%

Waste Disposal 62,203 56,167 118,370 4.5%

Off-site Waste Processing 36,355 57,446 93,802 3.6%

Program Management[1]

389,401 394,668 784,069 30.0%

Security 183,491 174,648 358,139 13.7%

Spent Fuel Pool Isolation 17,313 11,542 28,855 1.1%

Spent Fuel Management[2]

156,691 133,916 290,607 11.1%

Insurance and Regulatory Fees 63,608 56,849 120,458 4.6%

Energy 21,613 22,966 44,579 1.7%

Characterization and Licensing Surveys 24,372 21,711 46,083 1.8%

Property Taxes 175 120 295 0.01%

Miscellaneous Equipment 21,352 21,926 43,278 1.7%

Corporate A&G 75,562 72,398 147,960 5.7%

Indirect Overhead 18,137 18,115 36,253 1.4%

Miscellaneous Site Services 11,866 15,388 27,254 1.0%

Total [3]

1,285,554 1,324,988 2,610,541 100.0 Cost Element Unit 1 Unit 2 Total License Termination 957,075 984,185 1,941,260 74.4%

Spent Fuel Management 275,649 244,728 520,377 19.9%

Site Restoration 52,830 96,074 148,904 5.7%

Total [3]

1,285,554 1,324,988 2,610,541 100.0

[1]

Includes engineering costs

[2] Includes costs for operating the spent fuel pools and ISFSI, emergency planning and the cost to transfer the fuel to the DOE and/or ISFSI

[3] Columns may not add due to rounding

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 7, Page 1 of 4 TLG Services, LLC

7. REFERENCES

1.

Decommissioning Cost Analysis for the Arkansas Nuclear One, Units 1 and 2, Document E11-1763-001, Rev. 0, TLG Services, Inc., March 2019

2.

U.S. Code of Federal Regulations, Title 10, Parts 30, 40, 50, 51, 70 and 72, "General Requirements for Decommissioning Nuclear Facilities," Nuclear Regulatory Commission, 53 Fed. Reg. 24018, June 27, 1988 [Open]

3.

U.S. Nuclear Regulatory Commission, Regulatory Guide 1.159, "Assuring the Availability of Funds for Decommissioning Nuclear Reactors," Rev. 2, October 2011 [Open]

4.

Regulatory Improvement for Power Reactors Transitioning to Decommissioning, NRC Regulatory Basis Document, Docket ID NRC-2015-0070, RIN Number 3150-AJ59, November 20, 2017

5.

U.S. Code of Federal Regulations, Title 10, Parts 2, 50 and 51, "Decommissioning of Nuclear Power Reactors," Nuclear Regulatory Commission, 61 Fed. Reg. 39278, July 29, 1996 [Open]

6.

U.S. Code of Federal Regulations, Title 10, Parts 20, 30, 40, 50, 70, and 72, "Decommissioning Planning," Nuclear Regulatory Commission, Federal Register Volume 76, (p 35512 et seq.), June 17, 2011 [Open]

7.

Nuclear Waste Policy Act of 1982, 42 U.S. Code 10101, et seq. [Open]

8.

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

9.

Charter of the Blue Ribbon Commission on Americas Nuclear Future, Objectives and Scope of Activities [Open]

10.

Blue Ribbon Commission on Americas Nuclear Future, Report to the Secretary of Energy, p. 27, 32, January 2012 [Open]

11.

Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste, U.S. DOE, January 11, 2013 [Open]

12.

United States Court of Appeals for the District of Columbia Circuit, In Re:

Aiken County, Et Al., August 2013 [Open]

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 7, Page 2 of 4 TLG Services, LLC

7. REFERENCES (continued)

13.

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

[Open]

14.

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

15.

Low-Level Radioactive Waste Policy Act, Public Law 96-573, 1980 [Open]

16.

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

17.

U.S. Code of Federal Regulations, Title 10, Part 61, Licensing Requirements for Land Disposal of Radioactive Waste [Open]

18.

U.S. Code of Federal Regulations, Title 10, Part 20, Subpart E, Final Rule, Radiological Criteria for License Termination, 62 Fed. Reg. 39058, July 21, 1997

[Open]

19.

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

[Open]

20.

U.S. Code of Federal Regulations, Title 40, Part 141.66, Maximum contaminant levels for radionuclides [Open]

21.

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

22.

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

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

23.

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

24.

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

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 7, Page 3 of 4 TLG Services, LLC

7. REFERENCES (continued)

25.

"Building Construction Cost Data 2024," RSMeans (From the Gordian Group),

Greenville, South Carolina

26.

Decommissioning of Nuclear Power Reactors, Regulatory Guide 1.184, Nuclear Regulatory Commission, October 2013 [Open]

27.

Standard Format and Content of Decommissioning Cost Estimates for Nuclear Power Reactors, Regulatory Guide 1.202, Nuclear Regulatory Commission, February 2005 [Open]

28.

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

29.

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

30.

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

31.

Tri-State Motor Transit Company, Radioactive Materials Tariffs, TSMT 7000, January 2023

32.

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 [Open]

33.

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 [Open Main Report] [Open Appendices]

34.

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 [Open Main Report] [Open Appendices]

35.

SECY-00-0145, Integrated Rulemaking Plan for Nuclear Power Plant Decommissioning, June 2000

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Section 7, Page 4 of 4 TLG Services, LLC

7. REFERENCES (continued)

36.

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

37.

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

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 1 of 4 TLG Services, LLC APPENDIX A UNIT COST FACTOR DEVELOPMENT

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 2 of 4 TLG Services, LLC APPENDIX A UNIT COST FACTOR DEVELOPMENT Example:

Unit Factor for Removal of Contaminated Heat Exchanger < 3,000 lbs.

1.

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

2.

CALCULATIONS Activity Critical Act Activity Duration Duration ID Description (minutes)

(minutes)*

a Remove insulation 60 (b) b Mount pipe cutters 60 60 c

Install contamination controls 20 (b) d Disconnect inlet and outlet lines 60 60 e

Cap openings 20 (d) f Rig for removal 30 30 g

Unbolt from mounts 30 30 h

Remove contamination controls 15 15 i

Remove, wrap, send to waste processing area 60 60 Totals (Activity/Critical) 355 255 Duration adjustment(s):

+ Respiratory protection adjustment (50% of critical duration) 128

+ Radiation/ALARA adjustment (37.1% of critical duration) 95 Adjusted work duration 478

+ Protective clothing adjustment (30% of adjusted duration) 143 Productive work duration 621

+ Work break adjustment (8.33% of productive duration) 52 Total work duration (minutes) 673

• • • Total duration = 11.217 hr ***

• alpha designators indicate activities that can be performed in parallel

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 3 of 4 TLG Services, LLC APPENDIX A (continued)

3.

LABOR REQUIRED Duration Rate Crew Number (hours)

($/hr)

Cost Laborers 3.00 11.217

$38.24

$1,286.81 Craftsmen 2.00 11.217

$58.02

$1,301.62 Foreman 1.00 11.217

$62.05

$696.01 General Foreman 0.25 11.217

$66.09

$185.33 Fire Watch 0.05 11.217

$38.24

$21.45 Health Physics Technician 1.00 11.217

$48.75

$546.83 Total Labor Cost

$4,038.05

4.

EQUIPMENT & CONSUMABLES COSTS Equipment Costs none Consumables/Materials Costs

-Universal Sorbent 50 @ $0.70 sq. ft. {1}

$35.00

-Tarpaulins (oil resistant/fire retardant) 50 @ $0.41/sq. ft. {2}

$20.50

-Gas torch consumables 1 @ $21.51/hr. x 1 hr. {3}

$21.51 Subtotal cost of equipment and materials

$77.01 Overhead & profit on equipment and materials @ 17.50 %

$13.48 Total costs, equipment & material

$90.49 TOTAL COST:

Removal of contaminated heat exchanger <3000 pounds:

$4,128.54 Total labor cost:

$4,038.05 Total equipment/material costs:

$90.49 Total craft labor man-hours required per unit:

81.88

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 4 of 4 TLG Services, LLC

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, McMaster Carr Spill Control (7193T88)

2. RSMeans (2024) Division 01 56, Section 13.60-0600, page 23

3. RSMeans (2024) Division 01 54 33, Section 40-6360, page 744

• Material and consumable costs were adjusted using the regional indices for Geenville, South Carolina.

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Appendix B, Page 1 of 7 TLG Services, LLC APPENDIX B UNIT COST FACTOR LISTING (DECON: Power Block Structures Only)

Arkansas Nuclear One Document E11-1828-001, 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, LLC Removal of clean instrument and sampling tubing, $/linear foot 0.44 Removal of clean pipe 0.25 to 2 inches diameter, $/linear foot 4.66 Removal of clean pipe >2 to 4 inches diameter, $/linear foot 6.80 Removal of clean pipe >4 to 8 inches diameter, $/linear foot 13.65 Removal of clean pipe >8 to 14 inches diameter, $/linear foot 25.88 Removal of clean pipe >14 to 20 inches diameter, $/linear foot 33.79 Removal of clean pipe >20 to 36 inches diameter, $/linear foot 49.68 Removal of clean pipe >36 inches diameter, $/linear foot 58.97 Removal of clean valve >2 to 4 inches 90.26 Removal of clean valve >4 to 8 inches 136.46 Removal of clean valve >8 to 14 inches 258.81 Removal of clean valve >14 to 20 inches 337.92 Removal of clean valve >20 to 36 inches 496.84 Removal of clean valve >36 inches 589.67 Removal of clean pipe hanger for small bore piping 32.22 Removal of clean pipe hanger for large bore piping 109.01 Removal of clean pump, <300 pound 233.15 Removal of clean pump, 300-1000 pound 651.87 Removal of clean pump, 1000-10,000 pound 2,544.87 Removal of clean pump, >10,000 pound 4,932.05 Removal of clean pump motor, 300-1000 pound 270.52 Removal of clean pump motor, 1000-10,000 pound 1,054.55 Removal of clean pump motor, >10,000 pound 2,372.72 Removal of clean heat exchanger <3000 pound 1,373.88 Removal of clean heat exchanger >3000 pound 3,472.81 Removal of clean feedwater heater/deaerator 9,737.79 Removal of clean moisture separator/reheater 19,950.11 Removal of clean tank, <300 gallons 299.55 Removal of clean tank, 300-3000 gallon 938.90 Removal of clean tank, >3000 gallons, $/square foot surface area 8.04

Arkansas Nuclear One Document E11-1828-001, 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, LLC Removal of clean electrical equipment, <300 pound 124.60 Removal of clean electrical equipment, 300-1000 pound 440.44 Removal of clean electrical equipment, 1000-10,000 pound 880.85 Removal of clean electrical equipment, >10,000 pound 2,114.52 Removal of clean electrical transformer < 30 tons 1,468.50 Removal of clean electrical transformer > 30 tons 4,229.04 Removal of clean standby diesel generator, <100 kW 1,499.95 Removal of clean standby diesel generator, 100 kW to 1 MW 3,347.99 Removal of clean standby diesel generator, >1 MW 6,931.01 Removal of clean electrical cable tray, $/linear foot 11.84 Removal of clean electrical conduit, $/linear foot 5.18 Removal of clean mechanical equipment, <300 pound 124.60 Removal of clean mechanical equipment, 300-1000 pound 440.44 Removal of clean mechanical equipment, 1000-10,000 pound 880.85 Removal of clean mechanical equipment, >10,000 pound 2,114.52 Removal of clean HVAC equipment, <300 pound 150.67 Removal of clean HVAC equipment, 300-1000 pound 529.21 Removal of clean HVAC equipment, 1000-10,000 pound 1,054.71 Removal of clean HVAC equipment, >10,000 pound 2,114.52 Removal of clean HVAC ductwork, $/pound 0.47 Removal of contaminated instrument and sampling tubing, $/linear foot 1.41 Removal of contaminated pipe 0.25 to 2 inches diameter, $/linear foot 21.29 Removal of contaminated pipe >2 to 4 inches diameter, $/linear foot 35.53 Removal of contaminated pipe >4 to 8 inches diameter, $/linear foot 56.89 Removal of contaminated pipe >8 to 14 inches diameter, $/linear foot 109.58 Removal of contaminated pipe >14 to 20 inches diameter, $/linear foot 131.02 Removal of contaminated pipe >20 to 36 inches diameter, $/linear foot 179.82 Removal of contaminated pipe >36 inches diameter, $/linear foot 211.77 Removal of contaminated valve >2 to 4 inches 424.72 Removal of contaminated valve >4 to 8 inches 509.46

Arkansas Nuclear One Document E11-1828-001, 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, LLC Removal of contaminated valve >8 to 14 inches 1,030.60 Removal of contaminated valve >14 to 20 inches 1,306.16 Removal of contaminated valve >20 to 36 inches 1,733.03 Removal of contaminated valve >36 inches 2,052.45 Removal of contaminated pipe hanger for small bore piping 137.51 Removal of contaminated pipe hanger for large bore piping 446.40 Removal of contaminated pump, <300 pound 913.62 Removal of contaminated pump, 300-1000 pound 2,129.37 Removal of contaminated pump, 1000-10,000 pound 6,801.95 Removal of contaminated pump, >10,000 pound 16,566.31 Removal of contaminated pump motor, 300-1000 pound 925.23 Removal of contaminated pump motor, 1000-10,000 pound 2,788.33 Removal of contaminated pump motor, >10,000 pound 6,260.33 Removal of contaminated heat exchanger <3000 pound 4,128.54 Removal of contaminated heat exchanger >3000 pound 12,036.32 Removal of contaminated tank, <300 gallons 1,523.42 Removal of contaminated tank, >300 gallons, $/square foot 29.52 Removal of contaminated electrical equipment, <300 pound 694.56 Removal of contaminated electrical equipment, 300-1000 pound 1,712.71 Removal of contaminated electrical equipment, 1000-10,000 pound 3,299.46 Removal of contaminated electrical equipment, >10,000 pound 6,531.22 Removal of contaminated electrical cable tray, $/linear foot 33.67 Removal of contaminated electrical conduit, $/linear foot 16.83 Removal of contaminated mechanical equipment, <300 pound 772.44 Removal of contaminated mechanical equipment, 300-1000 pound 1,890.57 Removal of contaminated mechanical equipment, 1000-10,000 pound 3,636.13 Removal of contaminated mechanical equipment, >10,000 pound 6,531.22 Removal of contaminated HVAC equipment, <300 pound 772.44 Removal of contaminated HVAC equipment, 300-1000 pound 1,890.57 Removal of contaminated HVAC equipment, 1000-10,000 pound 3,636.13

Arkansas Nuclear One Document E11-1828-001, 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, LLC Removal of contaminated HVAC equipment, >10,000 pound 6,531.22 Removal of contaminated HVAC ductwork, $/pound 2.12 Removal/plasma arc cut of contaminated thin metal components, $/linear in.

3.73 Additional decontamination of surface by washing, $/square foot 7.51 Additional decontamination of surfaces by hydrolasing, $/square foot 35.02 Decontamination rig hook up and flush, $/ 250 foot length 6,494.28 Chemical flush of components/systems, $/gallon 29.11 Removal of clean standard reinforced concrete, $/cubic yard 65.51 Removal of grade slab concrete, $/cubic yard 74.42 Removal of clean concrete floors, $/cubic yard 370.23 Removal of sections of clean concrete floors, $/cubic yard 1,076.84 Removal of clean heavily rein concrete w/#9 rebar, $/cubic yard 94.29 Removal of contaminated heavily rein concrete w/#9 rebar, $/cubic yard 2,135.34 Removal of clean heavily rein concrete w/#18 rebar, $/cubic yard 127.60 Removal of contaminated heavily rein concrete w/#18 rebar, $/cubic yard 2,824.53 Removal heavily rein concrete w/#18 rebar & steel embedments, $/cubic yard 511.01 Removal of below-grade suspended floors, $/cubic yard 178.68 Removal of clean monolithic concrete structures, $/cubic yard 910.20 Removal of contaminated monolithic concrete structures, $/cubic yard 2,121.90 Removal of clean foundation concrete, $/cubic yard 717.04 Removal of contaminated foundation concrete, $/cubic yard 1,977.14 Explosive demolition of bulk concrete, $/cubic yard 49.84 Removal of clean hollow masonry block wall, $/cubic yard 26.64 Removal of contaminated hollow masonry block wall, $/cubic yard 69.03 Removal of clean solid masonry block wall, $/cubic yard 26.64 Removal of contaminated solid masonry block wall, $/cubic yard 69.03 Backfill of below-grade voids, $/cubic yard 25.67 Removal of subterranean tunnels/voids, $/linear foot 105.30 Placement of concrete for below-grade voids, $/cubic yard 195.16 Excavation of clean material, $/cubic yard 2.99

Arkansas Nuclear One Document E11-1828-001, 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, LLC Excavation of contaminated material, $/cubic yard 42.05 Removal of clean concrete rubble (tipping fee included), $/cubic yard 27.54 Removal of contaminated concrete rubble, $/cubic yard 27.18 Removal of building by volume, $/cubic foot 0.36 Removal of clean building metal siding, $/square foot 1.31 Removal of contaminated building metal siding, $/square foot 4.37 Removal of standard asphalt roofing, $/square foot 2.08 Removal of transite panels, $/square foot 2.19 Scarifying contaminated concrete surfaces (drill & spall), $/square foot 12.83 Scabbling contaminated concrete floors, $/square foot 7.65 Scabbling contaminated concrete walls, $/square foot 19.98 Scabbling contaminated ceilings, $/square foot 68.33 Scabbling structural steel, $/square foot 6.33 Removal of clean overhead crane/monorail < 10 ton capacity 629.09 Removal of contaminated overhead crane/monorail < 10 ton capacity 1,768.91 Removal of clean overhead crane/monorail >10-50 ton capacity 1,509.82 Removal of contaminated overhead crane/monorail >10-50 ton capacity 4,244.64 Removal of polar crane > 50 ton capacity 6,356.86 Removal of gantry crane > 50 ton capacity 23,612.15 Removal of structural steel, $/pound 0.27 Removal of clean steel floor grating, $/square foot 4.83 Removal of contaminated steel floor grating, $/square foot 13.81 Removal of clean free standing steel liner, $/square foot 12.06 Removal of contaminated free standing steel liner, $/square foot 34.40 Removal of clean concrete-anchored steel liner, $/square foot 6.03 Removal of contaminated concrete-anchored steel liner, $/square foot 40.12 Placement of scaffolding in clean areas, $/square foot 16.34 Placement of scaffolding in contaminated areas, $/square foot 25.73 Landscaping with topsoil, $/acre 20,181.02 Cost of CPC B-88 LSA box & preparation for use 2,087.45

Arkansas Nuclear One Document E11-1828-001, 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, LLC Cost of CPC B-25 LSA box & preparation for use 1,786.38 Cost of CPC B-12V 12 gauge LSA box & preparation for use 1,617.55 Cost of CPC B-144 LSA box & preparation for use 10,416.91 Cost of LSA drum & preparation for use 314.15 Cost of cask liner for CNSI 8 120A cask (resins) 13,707.83 Cost of cask liner for CNSI 8 120A cask (filters) 9,782.44 Decontamination of surfaces with vacuuming, $/square foot 0.82

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Appendix C, Page 1 of 22 TLG Services, LLC APPENDIX C DETAILED COST ANALYSIS DECON Schedule of Annual Expenditures, ANO-1............................................................... C-2 Schedule of Annual Expenditures, ANO-2............................................................. C-12

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 2 of 22 Table C-1 Arkansas Nuclear One Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 09:41:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 215 32 247 247 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 331 50 380 380 2,000 1a.1.7 Review plant dwgs & specs.

761 114 875 875 4,600 1a.1.8 Perform detailed rad survey a

1a.1.9 Estimate by-product inventory 165 25 190 190 1,000 1a.1.10 End product description 165 25 190 190 1,000 1a.1.11 Detailed by-product inventory 215 32 247 247 1,300 1a.1.12 Define major work sequence 1,240 186 1,426 1,426 7,500 1a.1.13 Perform SER and EA 513 77 590 590 3,100 1a.1.14 Prepare/submit Defueled Technical Specifications 1,240 186 1,426 1,426 7,500 1a.1.15 Perform Site-Specific Cost Study 827 124 951 951 5,000 1a.1.16 Prepare/submit Irradiated Fuel Management Plan 165 25 190 190 1,000 Activity Specifications 1a.1.17.1 Plant & temporary facilities 814 122 936 842 94 4,920 1a.1.17.2 Plant systems 689 103 792 713 79 4,167 1a.1.17.3 NSSS Decontamination Flush 83 12 95 95 500 1a.1.17.4 Reactor internals 1,174 176 1,350 1,350 7,100 1a.1.17.5 Reactor vessel 1,075 161 1,236 1,236 6,500 1a.1.17.6 Biological shield 83 12 95 95 500 1a.1.17.7 Steam generators 516 77 593 593 3,120 1a.1.17.8 Reinforced concrete 265 40 304 152 152 1,600 1a.1.17.9 Main Turbine 66 10 76 76 400 1a.1.17.10 Main Condensers 66 10 76 76 400 1a.1.17.11 Plant structures & buildings 516 77 593 297 297 3,120 1a.1.17.12 Waste management 761 114 875 875 4,600 1a.1.17.13 Facility & site closeout 149 22 171 86 86 900 1a.1.17 Total 6,256 938 7,194 6,335 859 37,827 Planning & Site Preparations 1a.1.18 Prepare dismantling sequence 397 60 456 456 2,400 1a.1.19 Plant prep. & temp. svces 4,200 630 4,830 4,830 1a.1.20 Design water clean-up system 232 35 266 266 1,400 1a.1.21 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,900 435 3,335 3,335 1a.1.22 Procure casks/liners & containers 203 31 234 234 1,230 1a.1 Subtotal Period 1a Activity Costs 20,026 3,004 23,029 22,170 859 78,157 Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 5,241 786 6,027 6,027 1a.3.2 Annual Fees 187 28 215 215 1a.3 Subtotal Period 1a Collateral Costs 5,429 814 6,243 215 6,027 Period 1a Period-Dependent Costs 1a.4.1 Insurance 1,421 142 1,564 1,564 1a.4.2 Property taxes 12 1

13 13 1a.4.3 Health physics supplies 970 242 1,212 1,212 1a.4.4 Heavy equipment rental 908 136 1,045 1,045 1a.4.5 Disposal of DAW generated 12 7

32 10 62 62 616 12,311 20 1a.4.6 Plant energy budget 1,565 235 1,800 1,800 1a.4.7 NRC Fees 1,464 146 1,611 1,611 1a.4.8 Emergency Planning Fees 1,049 105 1,154 1,154 1a.4.9 Indirect Overhead 1,912 287 2,199 2,199 1a.4.10 Spent Fuel Pool O&M 1,029 154 1,183 1,183 1a.4.11 ISFSI Operating Costs 66 10 76 76 1a.4.12 Corporate A&G Cost 16,073 2,411 18,484 18,484 1a.4.13 Environmental Audit 704 106 810 810 1a.4.14 Security Staff Cost 9,580 1,437 11,017 11,017 150,169 1a.4.15 Utility Staff Cost 34,665 5,200 39,864 39,864 432,640 1a.4 Subtotal Period 1a Period-Dependent Costs 1,878 12 7

32 69,542 10,623 82,095 79,681 2,413 616 12,311 20 582,809 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 3 of 22 Table C-1 Arkansas Nuclear One Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 09:41:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 1a.0 TOTAL PERIOD 1a COST 1,878 12 7

32 94,996 14,441 111,367 102,067 8,441 859 616 12,311 20 660,966 PERIOD 1b - Decommissioning Preparations Period 1b Direct Decommissioning Activities Detailed Work Procedures 1b.1.1.1 Plant systems 783 117 900 810 90 4,733 1b.1.1.2 NSSS Decontamination Flush 165 25 190 190 1,000 1b.1.1.3 Reactor internals 413 62 475 475 2,500 1b.1.1.4 Remaining buildings 223 33 257 64 193 1,350 1b.1.1.5 CRD cooling assembly 165 25 190 190 1,000 1b.1.1.6 CRD housings & ICI tubes 165 25 190 190 1,000 1b.1.1.7 Incore instrumentation 165 25 190 190 1,000 1b.1.1.8 Reactor vessel 600 90 690 690 3,630 1b.1.1.9 Facility closeout 198 30 228 114 114 1,200 1b.1.1.10 Missile shields 74 11 86 86 450 1b.1.1.11 Biological shield 198 30 228 228 1,200 1b.1.1.12 Steam generators 761 114 875 875 4,600 1b.1.1.13 Reinforced concrete 165 25 190 95 95 1,000 1b.1.1.14 Main Turbine 258 39 297 297 1,560 1b.1.1.15 Main Condensers 258 39 297 297 1,560 1b.1.1.16 Auxiliary building 451 68 519 467 52 2,730 1b.1.1.17 Reactor building 451 68 519 467 52 2,730 1b.1.1 Total 5,498 825 6,322 5,133 1,189 33,243 1b.1.2 Decon primary loop 979 489 1,468 1,468 1,067 1b.1 Subtotal Period 1b Activity Costs 979 5,498 1,314 7,791 6,602 1,189 1,067 33,243 Period 1b Additional Costs 1b.2.1 Spent Fuel Pool Isolation 15,055 2,258 17,313 17,313 1b.2.2 Site Characterization 6,075 1,823 7,898 7,898 32,260 10,796 1b.2.3 Asbestos Remediation 3,031 6

724 2,035 1,376 7,172 7,172 29,762 386,906 26,129 1b.2 Subtotal Period 1b Additional Costs 3,031 6

724 2,035 21,130 5,457 32,383 32,383 29,762 386,906 58,389 10,796 Period 1b Collateral Costs 1b.3.1 Decon equipment 1,253 188 1,441 1,441 1b.3.2 DOC staff relocation expenses 1,465 220 1,685 1,685 1b.3.3 Process decommissioning water waste 43 28 82 89 59 301 301 248 14,878 48 1b.3.4 Process decommissioning chemical flush waste 2

87 372 2,236 625 3,322 3,322 794 84,599 149 1b.3.5 Small tool allowance 45 7

52 52 1b.3.6 Pipe cutting equipment 1,500 225 1,725 1,725 1b.3.7 Decon rig 2,585 388 2,973 2,973 1b.3.8 Spent Fuel Capital and Transfer 6,863 1,029 7,892 7,892 1b.3.9 Annual Fees 79 12 91 91 1b.3 Subtotal Period 1b Collateral Costs 3,884 1,545 115 454 2,325 8,407 2,752 19,482 11,590 7,892 248 794 99,477 197 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 45 11 56 56 1b.4.2 Insurance 709 71 780 780 1b.4.3 Property taxes 6

1 7

7 1b.4.4 Health physics supplies 791 198 988 988 1b.4.5 Heavy equipment rental 453 68 521 521 1b.4.6 Disposal of DAW generated 7

4 19 6

36 36 359 7,182 12 1b.4.7 Plant energy budget 1,561 234 1,795 1,795 1b.4.8 NRC Fees 449 45 494 494 1b.4.9 Emergency Planning Fees 523 52 575 575 1b.4.10 Indirect Overhead 956 143 1,099 1,099 1b.4.11 Spent Fuel Pool O&M 513 77 590 590 1b.4.12 ISFSI Operating Costs 33 5

38 38 1b.4.13 Corporate A&G Cost 7,987 1,198 9,185 9,185 1b.4.14 Environmental Audit 351 53 404 404 1b.4.15 Security Staff Cost 4,726 709 5,435 5,435 74,154 1b.4.16 DOC Staff Cost 7,646 1,147 8,793 8,793 63,266 1b.4.17 Utility Staff Cost 17,198 2,580 19,778 19,778 216,765 1b.4 Subtotal Period 1b Period-Dependent Costs 45 1,244 7

4 19 42,659 6,597 50,575 49,371 1,203 359 7,182 12 354,185 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 4 of 22 Table C-1 Arkansas Nuclear One Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 09:41:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 1b.0 TOTAL PERIOD 1b COST 4,907 5,820 129 1,182 4,379 77,693 16,120 110,231 99,946 9,095 1,189 30,369 794 493,565 59,665 398,224 PERIOD 1 TOTALS 4,907 7,698 141 1,189 4,411 172,690 30,561 221,598 202,013 17,536 2,048 30,985 794 505,876 59,685 1,059,190 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.1 Reactor Coolant Piping 150 125 37 149 446 244 1,152 1,152 1,989 138,811 5,092 2a.1.1.2 Pressurizer Relief Tank 25 21 9

35 104 50 243 243 463 32,334 863 2a.1.1.3 Reactor Coolant Pumps & Motors 111 96 310 364 1,028 422 2,331 2,331 7,234 1,166,703 4,474 100 2a.1.1.4 Pressurizer 58 561 229 683 276 1,806 1,806 2,755 333,869 1,346 1,875 2a.1.1.5 Steam Generators 7,916 1,794 2,736 4,622 3,724 20,793 20,793 18,650 2,719,653 6,265 3,500 2a.1.1.6 Retired Steam Generator Units 650 2,687 4,622 1,624 9,582 9,582 18,650 2,552,436 52 2,250 2a.1.1.7 CRDMs/ICIs/Service Structure Removal 203 362 326 222 776 452 2,341 2,341 6,198 241,801 10,135 2a.1.1.8 Reactor Vessel Internals 78 7,856 17,525 1,637 17,827 366 19,690 64,979 64,979 2,002 1,118 393 292,874 30,540 1,380 2a.1.1.9 Reactor Vessel 112 9,845 2,965 2,055 3,155 366 10,327 28,825 28,825 13,268 949,917 30,540 1,380 2a.1.1 Totals 680 26,280 24,177 10,114 33,263 731 36,809 132,053 132,053 71,210 1,118 393 8,428,397 89,307 10,485 Removal of Major Equipment 2a.1.2 Main Turbine/Generator 318 224 106 439 298 258 1,643 1,643 2,780 1,548 265,162 6,088 2a.1.3 Main Condensers 1,003 144 149 597 430 484 2,807 2,807 5,044 2,107 360,822 19,329 Cascading Costs from Clean Building Demolition 2a.1.4.1 Reactor 382 57 439 439 3,325 2a.1.4.2 Auxiliary Building 138 21 159 159 1,020 2a.1.4 Totals 520 78 598 598 4,345 Disposal of Plant Systems 2a.1.5.1 1026 Hydrogen Purge & Particulate Mont.

102 13 42 269 72 91 588 588 2,514 349 124,539 1,842 2a.1.5.2 1030 Turbine Bldg Structure 112 17 129 129 2,287 2a.1.5.3 1031 Turbine Bldg Plumbing & Drainage 67 5

15 83 32 40 242 242 777 158 41,679 1,323 2a.1.5.4 1033 Turbine Bldg Domestic Water 15 2

17 17 347 2a.1.5.5 1034 Turbine Bldg Fire Protection 161 24 185 185 3,620 2a.1.5.6 1035 Turbine Bldg Heating/Chilled Water 38 6

44 44 839 2a.1.5.7 1037 Turbine Bldg Ventilation 94 14 108 108 1,867 2a.1.5.8 1038 Turbine Bldg Decontamination 2a.1.5.9 1040 Intake Stucture 24 4

28 28 495 2a.1.5.10 1042 Intake Structure Screens 68 10 78 78 1,357 2a.1.5.11 1046 Intake Structure Chlorination 28 4

33 33 593 2a.1.5.12 1047 Intake Structure Ventilation 15 2

17 17 298 2a.1.5.13 2011 Reactor Vessel Equipment 41 1

3 9

12 15 82 82 83 59 7,118 840 2a.1.5.14 2012 Reactor Instrumentation 172 19 34 73 126 92 516 516 683 604 67,000 3,025 2a.1.5.15 2013 Reactor Control Rods 202 14 60 497 53 149 975 975 4,655 261 205,618 3,933 2a.1.5.16 2022 Pressurizer Systems 329 10 47 413 30 160 989 989 3,871 146 166,454 6,664 2a.1.5.17 2031 Intermediate Cooling Water 594 58 148 525 461 370 2,155 2,155 4,911 2,242 342,896 11,105 2a.1.5.18 2032 Decay Heat Removal/Core Flooding 308 72 165 342 629 318 1,835 1,835 3,202 3,068 326,148 6,045 2a.1.5.19 2033 Reactor Bldg Spray 250 29 87 404 224 195 1,188 1,188 3,787 1,094 223,424 4,618 2a.1.5.20 2034 Service/Auxiliary Cooling Water 1,059 118 357 1,755 877 813 4,979 4,979 16,434 4,287 940,696 20,308 2a.1.5.21 2061 Primary Sampling 72 5

12 9

52 35 185 185 83 257 19,718 1,332 2a.1.5.22 2062 Nitrogen/High Purity Hydrogen 116 13 21 36 82 59 326 326 335 389 39,047 1,989 2a.1.5.23 2071 Condensate 821 95 286 1,548 637 649 4,037 4,037 14,497 3,104 787,309 15,915 2a.1.5.24 2072 Condensate Demineralizers 82 6

16 97 30 45 275 275 912 143 46,288 1,588 2a.1.5.25 2073 Feedwater Heaters/Moist Sep. Drains 565 89 235 736 774 489 2,889 2,889 6,895 3,785 521,242 11,070 2a.1.5.26 2074 Plant Makeup Water 174 5

28 288 91 587 587 2,692 109,326 2,990 2a.1.5.27 2081 Main Steam 306 45 135 678 324 284 1,771 1,771 6,344 1,580 358,506 6,109 2a.1.5.28 2082 Reheat Steam 395 49 139 641 359 311 1,894 1,894 6,005 1,750 355,793 7,520 2a.1.5.29 2083 Extraction Steam 901 83 251 1,106 679 607 3,627 3,627 10,354 3,323 631,898 17,152 2a.1.5.30 2084 Main Feedwater 291 47 147 794 326 300 1,905 1,905 7,436 1,594 403,680 5,757 2a.1.5.31 2085 Auxiliary Feedwater 35 5

11 54 27 26 158 158 507 131 29,147 683 2a.1.5.32 2086 Emergency Feedwater 129 13 36 155 101 87 521 521 1,448 494 90,316 2,420 2a.1.5.33 3011 Turbine Stator 7

2 3

17 8

7 43 43 157 38 8,919 134 2a.1.5.34 3021 Electro-Hydraulic 60 9

69 69 1,210 2a.1.5.35 3022 Gland Steam 135 11 25 69 87 71 398 398 645 423 53,345 2,421 2a.1.5.36 3023 Lube Oil 32 5

36 36 645 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 5 of 22 Table C-1 Arkansas Nuclear One Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 09:41:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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.1.5.37 3024 Moisture Separator/Reheaters 256 135 364 947 1,295 598 3,594 3,594 8,865 6,348 763,295 5,296 2a.1.5.38 3025 Turbine Sampling 142 15 41 100 147 95 541 541 941 720 83,941 2,724 2a.1.5.39 3032 Main Generator Exciter 2

0 2

2 41 2a.1.5.40 3042 Generator Cooling 38 6

44 44 837 2a.1.5.41 3043 Seal Oil 31 5

36 36 661 2a.1.5.42 3052 Condensate Vacuum 47 15 51 294 106 92 606 606 2,756 521 145,025 946 2a.1.5.43 3053 Main Condenser Piping 1

0 2

2 35 2a.1.5.44 3061 Circulating Water 42 6

48 48 839 2a.1.5.45 3062 Circulating Water Vacuum 13 2

15 15 264 2a.1.5.46 3063 Turbine Bldg Plant Additions(86-91) 7 1

8 8

158 2a.1.5.47 5021 Laboratory Equipment 16 2

19 19 330 2a.1.5 Totals 8,392 973 2,759 11,940 7,551 6,208 37,824 36,905 919 111,791 36,867 6,892,366 162,472 2a.1.6 Scaffolding in support of decommissioning 727 12 8

63 10 196 1,015 1,015 532 47 26,929 16,737 2a.1 Subtotal Period 2a Activity Costs 680 37,239 25,530 13,136 13,039 41,552 731 44,033 175,940 175,021 919 120,148 111,779 1,118 393 15,973,680 298,278 10,485 Period 2a Additional Costs 2a.2.1 Remedial Action Surveys 1,674 502 2,176 2,176 34,339 2a.2.2 Retired Reactor Closure Head 194 858 1,777 588 548 3,964 3,964 3,336 406,447 4,828 2,000 2a.2.3 Hot Leg Piping 4

11 36 11 62 62 11,300 191 6

2a.2 Subtotal Period 2a Additional Costs 194 861 1,788 625 1,674 1,061 6,203 6,203 14,636 406,638 39,173 2,000 Period 2a Collateral Costs 2a.3.1 Process decommissioning water waste 83 55 160 173 114 586 586 485 29,077 94 2a.3.2 Process decommissioning chemical flush waste 2a.3.3 Small tool allowance 305 46 351 316 35 2a.3.4 Spent Fuel Capital and Transfer 1,659 249 1,908 1,908 2a.3.5 Annual Fees 193 29 222 222 2a.3 Subtotal Period 2a Collateral Costs 83 305 55 160 173 1,852 438 3,068 1,125 1,908 35 485 29,077 94 Period 2a Period-Dependent Costs 2a.4.1 Decon supplies 149 37 186 186 2a.4.2 Insurance 685 69 754 754 2a.4.3 Property taxes 20 2

22 22 2a.4.4 Health physics supplies 4,634 1,159 5,793 5,793 2a.4.5 Heavy equipment rental 4,688 703 5,391 5,391 2a.4.6 Disposal of DAW generated 119 69 315 101 605 605 5,995 119,896 196 2a.4.7 Plant energy budget 2,457 369 2,825 2,825 2a.4.8 NRC Fees 1,359 136 1,495 1,495 2a.4.9 Emergency Planning Fees 1,258 126 1,384 1,384 2a.4.10 Indirect Overhead 2,560 384 2,944 2,944 2a.4.11 Spent Fuel Pool O&M 1,699 255 1,954 1,954 2a.4.12 ISFSI Operating Costs 110 16 126 126 2a.4.13 Corporate A&G Cost 13,279 1,992 15,270 15,270 2a.4.14 Environmental Audit 1,164 175 1,338 1,338 2a.4.15 Security Staff Cost 15,658 2,349 18,007 18,007 245,687 2a.4.16 DOC Staff Cost 30,670 4,600 35,270 35,270 261,157 2a.4.17 Utility Staff Cost 40,729 6,109 46,839 46,839 486,233 2a.4 Subtotal Period 2a Period-Dependent Costs 149 9,322 119 69 315 111,648 18,581 140,204 136,740 3,464 5,995 119,896 196 993,077 2a.0 TOTAL PERIOD 2a COST 912 47,061 26,565 15,153 13,039 42,665 115,906 64,114 325,415 319,089 5,372 954 120,148 132,894 1,118 393 16,529,290 337,741 1,005,562 PERIOD 2b - Site Decontamination Period 2b Direct Decommissioning Activities Disposal of Plant Systems 2b.1.1.1 1010 Site Demolition 3

0 3

3 56 2b.1.1.2 1021 Reactor Bldg Plumbing & Drainage 32 2

6 6

25 16 87 87 57 123 10,136 545 2b.1.1.3 1024 Reactor Bldg Fire Protection 48 4

9 9

38 25 132 132 87 186 15,370 827 2b.1.1.4 1025 Reactor Bldg Heating & Chilled Watr 49 4

8 16 33 24 134 134 151 161 16,384 869 2b.1.1.5 1027 Reactor Bldg Ventilation 113 9

34 224 55 82 516 516 2,097 272 102,416 2,124 2b.1.1.6 1028 Reactor Bldg Decontamination 456 15 61 450 77 211 1,270 1,270 4,214 378 195,129 9,241 2b.1.1.7 1050 Auxiliary Bldg Structure TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 6 of 22 Table C-1 Arkansas Nuclear One Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 09:41:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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) 2b.1.1.8 1051 Auxiliary Bldg Plumbing/Drainage 4

0 0

1 0

1 7

7 13 2

664 75 2b.1.1.9 1053 Auxiliary Bldg Domestic Water 88 1

7 74 34 204 204 690 28,002 1,387 2b.1.1.10 1054 Auxiliary Bldg Fire Protection 436 10 53 536 198 1,234 1,234 5,023 203,968 6,839 2b.1.1.11 1055 Auxiliary Bldg Heating/Chilled Watr 216 7

41 413 123 800 800 3,869 157,111 3,592 2b.1.1.12 1057 Auxiliary Bldg Ventilation 294 27 127 1,095 90 282 1,916 1,916 10,254 442 444,529 5,619 2b.1.1.13 1058 Auxiliary Bldg Decontamination 1,442 24 92 620 145 506 2,828 2,828 5,803 710 280,747 27,497 2b.1.1.14 1060 Boiler Plant Structure 34 5

39 39 683 2b.1.1.15 1065 Boiler Plant Heating 6

1 7

7 129 2b.1.1.16 1090 Plant Additions (86 - 91) 69 7

21 78 61 48 285 285 726 300 48,624 1,356 2b.1.1.17 2021 Reactor Coolant 26 10 32 166 76 56 365 365 1,551 370 86,526 507 2b.1.1.18 2023 Makeup Purification/Chem Addition 849 74 217 1,252 447 552 3,391 3,391 11,721 2,168 615,270 16,023 2b.1.1.19 2041 Gaseous Radwaste 278 47 92 105 392 202 1,117 1,117 987 1,903 162,214 4,979 2b.1.1.20 2042 Clean Liquid Radwaste 637 39 126 798 227 359 2,187 2,187 7,470 1,106 374,236 11,901 2b.1.1.21 2044 Dirty Liquid/Laundry Radwaste 88 17 31 43 128 67 373 373 401 615 56,063 1,585 2b.1.1.22 2051 Reactor Bldg Fuel Handling 14 3

10 49 22 18 116 116 461 110 25,708 267 2b.1.1.23 2087 Reactor Bldg Plant Additions(86-91) 185 16 35 103 117 98 554 554 968 566 75,709 3,312 2b.1.1.24 3026 Turbine Drains 168 20 41 76 162 102 570 570 713 785 79,440 2,952 2b.1.1.25 4021 Station Service Generator Bus/Aux 19 3

22 22 377 2b.1.1.26 4022 Station Start Up Equipment 6

1 7

7 114 2b.1.1.27 4023 Station Unit Auxiliary Equipment 4

1 5

5 80 2b.1.1.28 4024 Station Distribution System 6

1 7

7 118 2b.1.1.29 4025 DC Distribution System 33 5

38 38 679 2b.1.1.30 4041 Electrical Bus Duct 9

1 11 11 186 2b.1.1.31 4042 Electrical Structures, Wiring\\Cont.

914 137 1,051 1,051 18,290 2b.1.1.32 4043 Contaminated Conduit 1,303 17 82 722 52 461 2,638 2,638 6,759 255 290,662 22,950 2b.1.1.33 4052 Emergency Generator 33 5

38 38 689 2b.1.1.34 4061 Main Control Room Panels 29 4

34 34 585 2b.1.1.35 4062 Local Panels / Instruments 91 14 105 105 1,948 2b.1.1.36 4063 Plant Computer 4

1 5

5 88 2b.1.1.37 4064 Radiation Monitoring 71 3

8 44 20 31 176 176 414 96 22,944 1,389 2b.1.1.38 4065 Electrical Plant Additions(86-91) 52 3

8 42 19 26 150 150 397 95 22,132 1,024 2b.1.1.39 5011 Instrument Air 196 20 31 60 122 95 524 524 558 579 60,606 3,287 2b.1.1.40 5012 Service Air 131 14 20 23 87 62 337 337 215 412 35,753 2,126 2b.1.1.41 5013 Evacuation Alarm 1

0 2

2 29 2b.1.1.42 5014 Public Address 98 2

6 46 8

34 193 193 428 38 19,789 1,814 2b.1.1.43 5015 Security 21 3

24 24 415 2b.1.1.44 5017 Telephone 145 2

9 75 8

51 290 290 700 38 30,843 2,585 2b.1.1.45 5025 Health Physics Equipment 75 2

6 33 15 28 159 159 306 73 17,048 1,512 2b.1.1.46 5031 Misc. Lab,HP/Shop Furnishings 150 10 27 70 96 77 429 429 655 469 56,385 2,942 2b.1.1.47 5032 Misc. Test Equipment/Instruments 82 3

11 58 24 37 215 215 539 120 29,482 1,624 2b.1.1.48 5033 Misc. Portable Pwr Tool/Misc Equip 59 2

7 37 17 26 147 147 345 82 19,250 1,159 2b.1.1.49 5042 Kitchen Equipment 0

0 1

1 10 2b.1.1.50 5043 Laundry Equipment 3

0 0

1 1

1 6

6 6

4 537 60 2b.1.1.51 5301 Main Transformers 25 4

29 29 522 2b.1.1.52 Plant Additions(98-02) 25 1

5 48 14 94 94 453 18,393 491 2b.1.1 Totals 9,120 415 1,265 7,373 2,564 4,134 24,872 23,447 1,425 69,029 12,458 3,602,067 169,461 2b.1.2 Scaffolding in support of decommissioning 908 14 10 79 12 245 1,269 1,269 665 59 33,662 20,921 Decontamination of Site Buildings 2b.1.3.1 Reactor 2,105 2,486 244 2,640 1,717 6,773 4,045 20,010 20,010 16,077 79,429 4,021,813 71,261 2b.1.3.2 Auxiliary Building 845 212 16 187 54 134 547 1,994 1,994 506 4,697 242,720 20,123 2b.1.3.3 Misc. Site Structures - contaminated 74 30 3

9 91 7

61 274 274 852 35 36,730 1,327 2b.1.3.4 Turbine Building 221 7

1 3

25 2

117 375 375 234 9

10,092 4,366 2b.1.3 Totals 3,244 2,734 263 2,839 1,887 6,916 4,770 22,653 22,653 17,668 84,170 4,311,355 97,077 2b.1.4 Prepare/submit License Termination Plan 677 102 779 779 4,096 2b.1.5 Receive NRC approval of termination plan a

2b.1 Subtotal Period 2b Activity Costs 3,244 12,763 692 4,115 9,338 9,492 677 9,251 49,572 48,147 1,425 87,362 96,687 7,947,083 287,459 4,096 Period 2b Additional Costs 2b.2.1 Remedial Action Surveys 2,385 715 3,100 3,100 48,918 2b.2 Subtotal Period 2b Additional Costs 2,385 715 3,100 3,100 48,918 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 7 of 22 Table C-1 Arkansas Nuclear One Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 09:41:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 Collateral Costs 2b.3.1 Process decommissioning water waste 77 53 153 166 108 557 557 463 27,784 90 2b.3.2 Process decommissioning chemical flush waste 2b.3.3 Small tool allowance 240 36 276 276 2b.3.4 Spent Fuel Capital and Transfer 81,684 12,253 93,936 93,936 2b.3.5 Annual Fees 229 34 264 264 2b.3 Subtotal Period 2b Collateral Costs 77 240 53 153 166 81,913 12,431 95,033 1,096 93,936 463 27,784 90 Period 2b Period-Dependent Costs 2b.4.1 Decon supplies 1,452 363 1,815 1,815 2b.4.2 Insurance 976 98 1,074 1,074 2b.4.3 Property taxes 19 2

21 21 2b.4.4 Health physics supplies 5,171 1,293 6,464 6,464 2b.4.5 Heavy equipment rental 6,845 1,027 7,872 7,872 2b.4.6 Disposal of DAW generated 97 57 258 83 495 495 4,911 98,221 160 2b.4.7 Plant energy budget 2,763 414 3,178 3,178 2b.4.8 NRC Fees 1,936 194 2,130 2,130 2b.4.9 Emergency Planning Fees 1,792 179 1,971 1,971 2b.4.10 Indirect Overhead 3,314 497 3,812 3,812 2b.4.11 Spent Fuel Pool O&M 2,421 363 2,784 2,784 2b.4.12 Liquid Radwaste Processing Equipment/Services 610 92 702 702 2b.4.13 ISFSI Operating Costs 156 23 180 180 2b.4.14 Corporate A&G Cost 8,214 1,232 9,447 9,447 2b.4.15 Environmental Audit 1,658 249 1,907 1,907 2b.4.16 Security Staff Cost 22,306 3,346 25,651 25,651 349,992 2b.4.17 DOC Staff Cost 35,195 5,279 40,474 40,474 304,290 2b.4.18 Utility Staff Cost 45,295 6,794 52,089 52,089 565,558 2b.4 Subtotal Period 2b Period-Dependent Costs 1,452 12,017 97 57 258 126,656 21,528 162,065 157,130 4,935 4,911 98,221 160 1,219,839 2b.0 TOTAL PERIOD 2b COST 4,773 25,019 842 4,325 9,338 9,916 211,632 43,925 309,771 209,474 98,871 1,425 87,362 102,061 8,073,088 336,627 1,223,935 PERIOD 2d - Decontamination Following Wet Fuel Storage Period 2d Direct Decommissioning Activities 2d.1.1 Remove spent fuel racks 305 31 105 109 522 318 1,390 1,390 2,561 162,662 705 Disposal of Plant Systems 2d.1.2.1 2052 Auxiliary Bldg Fuel Handling 54 10 32 167 76 64 404 404 1,566 374 87,342 1,056 2d.1.2.2 2054 Spent Fuel Cooling 152 14 34 121 105 89 515 515 1,133 508 78,678 2,792 2d.1.2 Totals 206 24 66 288 181 153 919 919 2,699 882 166,020 3,848 Decontamination of Site Buildings 2d.1.3.1 Fuel Handling Area 412 481 5

23 146 17 356 1,440 1,440 1,363 267 68,925 16,643 2d.1.3 Totals 412 481 5

23 146 17 356 1,440 1,440 1,363 267 68,925 16,643 2d.1.4 Scaffolding in support of decommissioning 182 3

2 16 2

49 254 254 133 12 6,732 4,184 2d.1 Subtotal Period 2d Activity Costs 717 900 137 201 450 723 876 4,003 4,003 4,195 3,721 404,340 25,381 Period 2d Additional Costs 2d.2.1 License Termination Survey Planning 1,503 451 1,954 1,954 6,240 2d.2.2 Operational Tools & Equipment 11 52 385 67 514 514 5,850 146,250 16 2d.2.3 Remedial Action Surveys 350 105 455 455 7,175 2d.2 Subtotal Period 2d Additional Costs 11 52 385 1,853 623 2,923 2,923 5,850 146,250 7,191 6,240 Period 2d Collateral Costs 2d.3.1 Process decommissioning water waste 63 44 126 136 89 458 458 381 22,864 74 2d.3.2 Process decommissioning chemical flush waste 2d.3.3 Small tool allowance 27 4

31 31 2d.3.4 Decommissioning Equipment Disposition 130 104 710 108 162 1,214 1,214 6,000 529 303,608 147 2d.3.5 Annual Fees 34 5

39 32 6

2d.3 Subtotal Period 2d Collateral Costs 63 27 174 230 710 244 34 260 1,742 1,736 6

6,000 910 326,472 221 Period 2d Period-Dependent Costs 2d.4.1 Decon supplies 100 25 126 126 2d.4.2 Insurance 143 14 158 158 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 8 of 22 Table C-1 Arkansas Nuclear One Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 09:41:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 2d Period-Dependent Costs (continued) 2d.4.3 Property taxes 1

0 1

1 2d.4.4 Health physics supplies 568 142 710 710 2d.4.5 Heavy equipment rental 1,004 151 1,155 1,155 2d.4.6 Disposal of DAW generated 17 10 46 15 88 88 871 17,410 28 2d.4.7 Plant energy budget 216 32 249 249 2d.4.8 NRC Fees 269 27 296 296 2d.4.9 Indirect Overhead 141 21 162 154 7

2d.4.10 Liquid Radwaste Processing Equipment/Services 179 27 206 206 2d.4.11 ISFSI Operating Costs 23 3

26 26 2d.4.12 Corporate A&G Cost 571 86 657 627 30 2d.4.13 Environmental Audit 243 36 280 280 2d.4.14 Security Staff Cost 1,692 254 1,946 1,401 545 35,182 2d.4.15 DOC Staff Cost 2,967 445 3,412 3,412 26,208 2d.4.16 Utility Staff Cost 3,270 490 3,760 3,587 173 43,441 2d.4 Subtotal Period 2d Period-Dependent Costs 100 1,572 17 10 46 9,715 1,769 13,229 12,448 782 871 17,410 28 104,831 2d.0 TOTAL PERIOD 2d COST 881 2,500 339 493 1,544 1,013 11,601 3,527 21,898 21,110 788 16,045 5,501 894,472 32,822 111,071 PERIOD 2e - Delay before License Termination Period 2e Direct Decommissioning Activities Period 2e Collateral Costs 2e.3.1 Spent Fuel Capital and Transfer 3,498 525 4,023 4,023 2e.3.2 Annual Fees 249 37 286 3

283 2e.3 Subtotal Period 2e Collateral Costs 3,747 562 4,309 3

4,306 Period 2e Period-Dependent Costs 2e.4.1 Insurance 1,722 172 1,894 1,894 2e.4.2 Property taxes 7

1 8

8 2e.4.3 Health physics supplies 720 180 900 900 2e.4.4 Disposal of DAW generated 8

5 22 7

42 42 414 8,275 13 2e.4.5 Plant energy budget 1,300 195 1,494 1,494 2e.4.6 NRC Fees 1,905 191 2,096 2,096 2e.4.7 Indirect Overhead 482 72 554 517 37 2e.4.8 ISFSI Operating Costs 276 41 317 317 2e.4.9 Corporate A&G Cost 3,206 481 3,687 3,444 243 2e.4.10 Environmental Audit 2,924 439 3,363 3,363 2e.4.11 Security Staff Cost 20,344 3,052 23,395 10,271 13,125 423,026 2e.4.12 Utility Staff Cost 4,261 639 4,900 4,577 323 60,434 2e.4 Subtotal Period 2e Period-Dependent Costs 720 8

5 22 36,427 5,469 42,651 28,605 14,045 414 8,275 13 483,460 2e.0 TOTAL PERIOD 2e COST 720 8

5 22 40,174 6,031 46,960 28,609 18,351 414 8,275 13 483,460 PERIOD 2f - License Termination Period 2f Direct Decommissioning Activities 2f.1.1 ORISE confirmatory survey 176 53 229 229 2f.1.2 Terminate license a

2f.1 Subtotal Period 2f Activity Costs 176 53 229 229 Period 2f Additional Costs 2f.2.1 License Termination Survey 6,449 1,935 8,384 8,384 113,831 3,120 2f.2 Subtotal Period 2f Additional Costs 6,449 1,935 8,384 8,384 113,831 3,120 Period 2f Collateral Costs 2f.3.1 DOC staff relocation expenses 1,465 220 1,685 1,685 2f.3.2 Spent Fuel Capital and Transfer 516 77 593 593 2f.3.3 Annual Fees 47 7

54 34 20 2f.3 Subtotal Period 2f Collateral Costs 2,028 304 2,332 1,718 614 Period 2f Period-Dependent Costs 2f.4.1 Insurance 325 33 358 358 2f.4.2 Property taxes 1

0 2

2 2f.4.3 Health physics supplies 1,229 307 1,537 1,537 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 9 of 22 Table C-1 Arkansas Nuclear One Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 09:41:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 2f Period-Dependent Costs (continued) 2f.4.4 Disposal of DAW generated 7

4 18 6

35 35 350 7,004 11 2f.4.5 Plant energy budget 245 37 282 282 2f.4.6 NRC Fees 645 65 710 710 2f.4.7 Indirect Overhead 224 34 258 236 22 2f.4.8 ISFSI Operating Costs 52 8

60 60 2f.4.9 Corporate A&G Cost 551 83 633 580 54 2f.4.10 Environmental Audit 552 83 635 635 2f.4.11 Security Staff Cost 3,840 576 4,417 3,180 1,237 79,858 2f.4.12 DOC Staff Cost 5,778 867 6,644 6,644 48,487 2f.4.13 Utility Staff Cost 5,640 846 6,485 5,934 551 62,340 2f.4 Subtotal Period 2f Period-Dependent Costs 1,229 7

4 18 17,854 2,943 22,055 20,132 1,924 350 7,004 11 190,685 2f.0 TOTAL PERIOD 2f COST 1,229 7

4 18 26,507 5,235 33,000 30,463 2,537 350 7,004 113,843 193,805 PERIOD 2 TOTALS 6,566 76,528 27,761 19,979 23,921 53,634 405,820 122,832 737,043 608,744 125,920 2,379 223,555 241,220 1,118 393 25,512,130 821,046 3,017,834 PERIOD 3b - Site Restoration Period 3b Direct Decommissioning Activities Demolition of Remaining Site Buildings 3b.1.1.1 Reactor 2,283 342 2,625 2,625 19,459 3b.1.1.2 Administrative Building 29 4

33 33 319 3b.1.1.3 Auxiliary Building 1,277 192 1,468 1,468 9,936 3b.1.1.4 Circulating Water Tunnels/Pipe 136 20 157 157 2,091 3b.1.1.5 Intake 114 17 131 131 1,040 3b.1.1.6 Misc Site Structures -clean 28 4

32 32 213 3b.1.1.7 Site Additions (98-02) 8 1

9 9

120 3b.1.1.8 Turbine Building 1,218 183 1,400 1,400 13,436 3b.1.1.9 Turbine Pedestal 346 52 398 398 2,152 3b.1.1.10 Fuel Handling Area 24 4

27 27 457 3b.1.1 Totals 5,462 819 6,282 6,282 49,223 Site Closeout Activities 3b.1.2 Grade & landscape site 109 16 125 125 284 3b.1.3 Final report to NRC 258 39 297 297 1,560 3b.1 Subtotal Period 3b Activity Costs 5,571 258 874 6,704 297 6,407 49,507 1,560 Period 3b Additional Costs 3b.2.1 Concrete Crushing 416 7

64 487 487 1,856 3b.2.2 Construction Debris 19 3

22 22 3b.2.3 GTCC SFP Legacy Waste 335 50 385 385 3,900 3b.2 Subtotal Period 3b Additional Costs 416 361 117 894 385 509 3,900 1,856 Period 3b Collateral Costs 3b.3.1 Small tool allowance 45 7

52 52 3b.3.2 Spent Fuel Capital and Transfer 1,591 239 1,830 1,830 3b.3.3 Annual Fees 126 19 145 145 3b.3 Subtotal Period 3b Collateral Costs 45 1,717 264 2,027 1,975 52 Period 3b Period-Dependent Costs 3b.4.1 Insurance 436 44 479 479 3b.4.2 Property taxes 4

0 4

4 3b.4.3 Heavy equipment rental 8,367 1,255 9,622 9,622 3b.4.4 Plant energy budget 329 49 378 378 3b.4.5 NRC ISFSI Fees 515 52 567 567 3b.4.6 Indirect Overhead 209 31 241 63 178 3b.4.7 ISFSI Operating Costs 140 21 161 161 3b.4.8 Corporate A&G Cost 884 133 1,017 387 629 3b.4.9 Environmental Audit 1,480 222 1,702 1,702 3b.4.10 Security Staff Cost 5,416 812 6,228 3,320 2,909 104,898 3b.4.11 DOC Staff Cost 14,481 2,172 16,653 16,653 115,828 3b.4.12 Utility Staff Cost 6,491 974 7,465 0

1,478 5,987 73,758 3b.4 Subtotal Period 3b Period-Dependent Costs 8,367 30,385 5,765 44,517 0

5,980 38,537 294,483 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 10 of 22 Table C-1 Arkansas Nuclear One Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 09:41:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 14,400 32,721 7,020 54,141 681 7,955 45,505 3,900 51,363 296,043 PERIOD 3c - Fuel Storage Operations/Shipping Period 3c Direct Decommissioning Activities Period 3c Collateral Costs 3c.3.1 Spent Fuel Capital and Transfer 18,668 2,800 21,468 21,468 3c.3.2 Annual Fees 2,202 330 2,533 2,533 3c.3 Subtotal Period 3c Collateral Costs 20,870 3,131 24,001 24,001 Period 3c Period-Dependent Costs 3c.4.1 Insurance 7,618 762 8,380 8,380 3c.4.2 Property taxes 66 7

73 73 3c.4.3 Plant energy budget 3c.4.4 NRC ISFSI Fees 9,002 900 9,902 9,902 3c.4.5 Indirect Overhead 961 144 1,105 1,105 3c.4.6 ISFSI Operating Costs 2,441 366 2,808 2,808 3c.4.7 Corporate A&G Cost 6,837 1,026 7,863 7,863 3c.4.8 Security Staff Cost 50,465 7,570 58,035 58,035 1,069,513 3c.4.9 Utility Staff Cost 22,466 3,370 25,836 25,836 257,836 3c.4 Subtotal Period 3c Period-Dependent Costs 99,857 14,144 114,001 114,001 1,327,349 3c.0 TOTAL PERIOD 3c COST 120,727 17,275 138,002 138,002 1,327,349 PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d.1.1.1 Vessel & Internals GTCC Disposal 1,200 7,033 1,355 9,588 9,588 1,773 345,227 3d.1.1 Totals 1,200 7,033 1,355 9,588 9,588 1,773 345,227 3d.1 Subtotal Period 3d Activity Costs 1,200 7,033 1,355 9,588 9,588 1,773 345,227 Period 3d Collateral Costs 3d.3.1 Annual Fees 2

0 3

3 3d.3 Subtotal Period 3d Collateral Costs 2

0 3

3 Period 3d Period-Dependent Costs 3d.4.1 Insurance 8

1 9

9 3d.4.2 Property taxes 0

0 0

0 3d.4.3 Plant energy budget 3d.4.4 NRC ISFSI Fees 7

1 8

8 3d.4.5 Indirect Overhead 1

0 1

1 3d.4.6 ISFSI Operating Costs 3

0 3

3 3d.4.7 Corporate A&G Cost 7

1 8

8 3d.4.8 Security Staff Cost 53 8

61 61 1,117 3d.4.9 Utility Staff Cost 23 4

27 27 269 3d.4 Subtotal Period 3d Period-Dependent Costs 102 15 116 106 11 1,386 3d.0 TOTAL PERIOD 3d COST 1,200 7,033 104 1,370 9,707 9,697 11 1,773 345,227 1,386 PERIOD 3e - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 3e Additional Costs 3e.2.1 License Termination ISFSI 246 184 1,269 1,921 2,056 1,419 7,097 7,097 12,855 1,641,085 10,687 1,245 3e.2 Subtotal Period 3e Additional Costs 246 184 1,269 1,921 2,056 1,419 7,097 7,097 12,855 1,641,085 10,687 1,245 Period 3e Collateral Costs 3e.3.1 Annual Fees 20 5

25 25 3e.3 Subtotal Period 3e Collateral Costs 20 5

25 25 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 11 of 22 Table C-1 Arkansas Nuclear One Unit 1 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 09:41:03 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

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

Manhours Manhours Period 3e Period-Dependent Costs 3e.4.1 Insurance 50 12 62 62 3e.4.2 Property taxes 1

0 1

1 3e.4.3 Plant energy budget 5

1 7

7 3e.4.4 Indirect Overhead 8

2 10 10 3e.4.5 Corporate A&G Cost 40 10 50 50 3e.4.6 Security Staff Cost 118 30 148 148 2,541 3e.4.7 Utility Staff Cost 168 42 209 209 1,928 3e.4 Subtotal Period 3e Period-Dependent Costs 389 97 486 486 4,468 3e.0 TOTAL PERIOD 3e COST 246 184 1,269 1,921 2,466 1,522 7,608 7,608 12,855 1,641,085 10,687 5,713 PERIOD 3f - ISFSI Site Restoration Period 3f Direct Decommissioning Activities Period 3f Additional Costs 3f.2.1 Demolition and Site Restoration ISFSI 3,610 469 612 4,691 4,691 30,191 80 3f.2 Subtotal Period 3f Additional Costs 3,610 469 612 4,691 4,691 30,191 80 Period 3f Collateral Costs 3f.3.1 Small tool allowance 43 7

50 50 3f.3 Subtotal Period 3f Collateral Costs 43 7

50 50 Period 3f Period-Dependent Costs 3f.4.1 Insurance 3f.4.2 Property taxes 0

0 0

0 3f.4.3 Plant energy budget 3

0 3

3 3f.4.4 Indirect Overhead 3

1 4

4 3f.4.5 Corporate A&G Cost 20 3

23 23 3f.4.6 Security Staff Cost 60 9

68 68 1,281 3f.4.7 Utility Staff Cost 75 11 86 86 795 3f.4 Subtotal Period 3f Period-Dependent Costs 161 24 185 185 2,076 3f.0 TOTAL PERIOD 3f COST 3,654 630 643 4,926 4,926 30,191 2,156 PERIOD 3 TOTALS 18,300 1,384 1,269 8,955 156,648 27,829 214,385 17,986 145,967 50,431 12,855 1,773 1,990,212 92,241 1,632,646 TOTAL COST TO DECOMMISSION 11,474 102,526 29,287 22,438 23,921 67,000 735,158 181,223 1,173,026 828,744 289,423 54,859 223,555 285,060 1,912 393 1,773 28,008,210 972,972 5,709,670 TOTAL COST TO DECOMMISSION WITH 18.27% CONTINGENCY:

$1,173,026 thousands of 2024 dollars TOTAL NRC LICENSE TERMINATION COST IS 70.65% OR:

$828,744 thousands of 2024 dollars SPENT FUEL MANAGEMENT COST IS 24.67% OR:

$289,423 thousands of 2024 dollars NON-NUCLEAR DEMOLITION COST IS 4.68% OR:

$54,858 thousands of 2024 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

287,365 Cubic Feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

1,773 Cubic Feet TOTAL SCRAP METAL REMOVED:

34,665 Tons TOTAL CRAFT LABOR REQUIREMENTS:

972,972 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, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 12 of 22 Table C-2 Arkansas Nuclear One Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 10:30:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 117 18 135 135 707 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 180 27 207 207 1,088 1a.1.7 Review plant dwgs & specs.

414 62 476 476 2,502 1a.1.8 Perform detailed rad survey a

1a.1.9 Estimate by-product inventory 90 13 103 103 544 1a.1.10 End product description 90 13 103 103 544 1a.1.11 Detailed by-product inventory 117 18 135 135 707 1a.1.12 Define major work sequence 675 101 776 776 4,080 1a.1.13 Perform SER and EA 279 42 321 321 1,686 1a.1.14 Prepare/submit Defueled Technical Specifications 675 101 776 776 4,080 1a.1.15 Perform Site-Specific Cost Study 450 67 517 517 2,720 1a.1.16 Prepare/submit Irradiated Fuel Management Plan 90 13 103 103 544 Activity Specifications 1a.1.17.1 Plant & temporary facilities 443 66 509 458 51 2,676 1a.1.17.2 Plant systems 375 56 431 388 43 2,267 1a.1.17.3 NSSS Decontamination Flush 45 7

52 52 272 1a.1.17.4 Reactor internals 639 96 735 735 3,862 1a.1.17.5 Reactor vessel 585 88 673 673 3,536 1a.1.17.6 Biological shield 45 7

52 52 272 1a.1.17.7 Steam generators 281 42 323 323 1,697 1a.1.17.8 Reinforced concrete 144 22 166 83 83 870 1a.1.17.9 Main Turbine 36 5

41 41 218 1a.1.17.10 Main Condensers 36 5

41 41 218 1a.1.17.11 Plant structures & buildings 281 42 323 161 161 1,697 1a.1.17.12 Waste management 414 62 476 476 2,502 1a.1.17.13 Facility & site closeout 81 12 93 47 47 490 1a.1.17 Total 3,403 510 3,914 3,446 468 20,578 Planning & Site Preparations 1a.1.18 Prepare dismantling sequence 216 32 248 248 1,306 1a.1.19 Plant prep. & temp. svces 4,200 630 4,830 4,830 1a.1.20 Design water clean-up system 126 19 145 145 762 1a.1.21 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,900 435 3,335 3,335 1a.1.22 Procure casks/liners & containers 111 17 127 127 669 1a.1 Subtotal Period 1a Activity Costs 14,132 2,120 16,251 15,784 468 42,517 Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 9,454 1,418 10,872 10,872 1a.3.2 Annual Fees 187 28 215 215 1a.3 Subtotal Period 1a Collateral Costs 9,641 1,446 11,088 215 10,872 Period 1a Period-Dependent Costs 1a.4.1 Insurance 1,421 142 1,564 1,564 1a.4.2 Property taxes 6

1 7

7 1a.4.3 Health physics supplies 970 242 1,212 1,212 1a.4.4 Heavy equipment rental 908 136 1,045 1,045 1a.4.5 Disposal of DAW generated 12 7

32 10 62 62 616 12,311 20 1a.4.6 Plant energy budget 1,742 261 2,003 2,003 1a.4.7 NRC Fees 914 91 1,006 1,006 1a.4.8 Emergency Planning Fees 1,049 105 1,154 1,154 1a.4.9 Indirect Overhead 1,912 287 2,199 2,199 1a.4.10 Spent Fuel Pool O&M 1,029 154 1,183 1,183 1a.4.11 ISFSI Operating Costs 66 10 76 76 1a.4.12 Corporate A&G Cost 15,950 2,392 18,342 18,342 1a.4.13 Environmental Audit 929 139 1,068 1,068 1a.4.14 Security Staff Cost 9,580 1,437 11,017 11,017 150,169 1a.4.15 Utility Staff Cost 34,749 5,212 39,962 39,962 432,640 1a.4 Subtotal Period 1a Period-Dependent Costs 1,878 12 7

32 69,348 10,622 81,899 79,486 2,413 616 12,311 20 582,809 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 13 of 22 Table C-2 Arkansas Nuclear One Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 10:30:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 1a.0 TOTAL PERIOD 1a COST 1,878 12 7

32 93,121 14,188 109,238 95,485 13,286 468 616 12,311 20 625,326 PERIOD 1b - Decommissioning Preparations Period 1b Direct Decommissioning Activities Detailed Work Procedures 1b.1.1.1 Plant systems 426 64 490 441 49 2,575 1b.1.1.2 NSSS Decontamination Flush 90 13 103 103 544 1b.1.1.3 Reactor internals 225 34 259 259 1,360 1b.1.1.4 Remaining buildings 121 18 140 35 105 734 1b.1.1.5 CRD cooling assembly 90 13 103 103 544 1b.1.1.6 CRD housings & ICI tubes 90 13 103 103 544 1b.1.1.7 Incore instrumentation 90 13 103 103 544 1b.1.1.8 Reactor vessel 327 49 376 376 1,975 1b.1.1.9 Facility closeout 108 16 124 62 62 653 1b.1.1.10 Missile shields 40 6

47 47 245 1b.1.1.11 Biological shield 108 16 124 124 653 1b.1.1.12 Steam generators 414 62 476 476 2,502 1b.1.1.13 Reinforced concrete 90 13 103 52 52 544 1b.1.1.14 Main Turbine 140 21 161 161 849 1b.1.1.15 Main Condensers 140 21 161 161 849 1b.1.1.16 Auxiliary building 246 37 282 254 28 1,485 1b.1.1.17 Reactor building 246 37 282 254 28 1,485 1b.1.1 Total 2,991 449 3,439 2,793 647 18,084 1b.1.2 Decon primary loop 908 454 1,362 1,362 1,067 1b.1 Subtotal Period 1b Activity Costs 908 2,991 903 4,802 4,155 647 1,067 18,084 Period 1b Additional Costs 1b.2.1 Spent Fuel Pool Isolation 10,037 1,505 11,542 11,542 1b.2.2 Site Characterization 3,307 992 4,299 4,299 17,559 5,876 1b.2 Subtotal Period 1b Additional Costs 13,343 2,497 15,841 15,841 17,559 5,876 Period 1b Collateral Costs 1b.3.1 Decon equipment 1,253 188 1,441 1,441 1b.3.2 DOC staff relocation expenses 1,465 220 1,685 1,685 1b.3.3 Process decommissioning water waste 43 28 81 88 58 298 298 245 14,730 48 1b.3.4 Process decommissioning chemical flush waste 2

80 340 2,046 572 3,040 3,040 727 77,421 136 1b.3.5 Small tool allowance 3

0 3

3 1b.3.6 Pipe cutting equipment 1,500 225 1,725 1,725 1b.3.7 Decon rig 2,585 388 2,973 2,973 1b.3.8 Spent Fuel Capital and Transfer 8,541 1,281 9,822 9,822 1b.3.9 Annual Fees 82 12 94 94 1b.3 Subtotal Period 1b Collateral Costs 3,883 1,503 108 422 2,134 10,088 2,944 21,081 11,259 9,822 245 727 92,150 184 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 45 11 56 56 1b.4.2 Insurance 709 71 780 780 1b.4.3 Property taxes 1

0 1

1 1b.4.4 Health physics supplies 551 138 688 688 1b.4.5 Heavy equipment rental 453 68 521 521 1b.4.6 Disposal of DAW generated 7

4 19 6

36 36 359 7,182 12 1b.4.7 Plant energy budget 1,737 261 1,998 1,998 1b.4.8 NRC Fees 315 32 347 347 1b.4.9 Emergency Planning Fees 523 52 575 575 1b.4.10 Indirect Overhead 956 143 1,099 1,099 1b.4.11 Spent Fuel Pool O&M 513 77 590 590 1b.4.12 ISFSI Operating Costs 33 5

38 38 1b.4.13 Corporate A&G Cost 7,673 1,151 8,824 8,824 1b.4.14 Environmental Audit 463 69 533 533 1b.4.15 Security Staff Cost 4,726 709 5,435 5,435 74,154 1b.4.16 DOC Staff Cost 7,646 1,147 8,793 8,793 63,266 1b.4.17 Utility Staff Cost 17,188 2,578 19,766 19,766 216,765 1b.4 Subtotal Period 1b Period-Dependent Costs 45 1,003 7

4 19 42,484 6,518 50,080 48,877 1,203 359 7,182 12 354,185 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 14 of 22 Table C-2 Arkansas Nuclear One Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 10:30:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 1b.0 TOTAL PERIOD 1b COST 4,836 2,506 115 426 2,153 68,905 12,863 91,803 80,131 11,026 647 605 727 99,332 18,821 378,145 PERIOD 1 TOTALS 4,836 4,384 127 433 2,185 162,026 27,050 201,041 175,616 24,311 1,114 1,220 727 111,643 18,841 1,003,472 PERIOD 2a - Large Component Removal Period 2a Direct Decommissioning Activities Nuclear Steam Supply System Removal 2a.1.1.1 Reactor Coolant Piping 117 120 28 113 338 193 910 910 1,510 105,345 4,257 2a.1.1.2 Pressurizer Quench Tank 9

8 3

13 37 18 87 87 167 11,627 310 2a.1.1.3 Reactor Coolant Pumps & Motors 104 96 296 377 914 390 2,176 2,176 6,430 1,207,176 4,352 100 2a.1.1.4 Pressurizer 58 555 188 592 246 1,639 1,639 2,388 193,729 1,346 1,875 2a.1.1.5 Steam Generators 7,916 3,910 2,823 2,662 3,961 4,183 25,456 25,456 33,353 15,984 2,976,034 11,677 3,500 2a.1.1.6 Retired Steam Generator Units 3,034 2,789 2,662 3,870 2,088 14,443 14,443 33,353 15,614 2,861,244 5,463 2,250 2a.1.1.7 CRDMs/ICIs/Service Structure Removal 208 363 353 242 838 476 2,480 2,480 6,034 261,201 10,247 2a.1.1.8 Reactor Vessel Internals 51 7,957 17,404 1,311 11,052 379 16,254 54,407 54,407 2,669 574 337 220,455 31,807 1,431 2a.1.1.9 Reactor Vessel 127 9,749 3,223 2,598 4,180 379 10,977 31,233 31,233 17,933 1,235,343 31,807 1,431 2a.1.1 Totals 616 26,267 28,805 10,454 5,323 25,781 758 34,826 132,830 132,830 66,707 68,728 574 337 9,072,153 101,266 10,586 Removal of Major Equipment 2a.1.2 Main Turbine/Generator 361 255 119 499 339 293 1,867 1,867 3,161 1,760 301,493 6,922 2a.1.3 Main Condensers 1,804 178 184 738 531 740 4,174 4,174 6,233 2,603 445,878 34,761 Cascading Costs from Clean Building Demolition 2a.1.4.1 Reactor 425 64 489 489 3,619 2a.1.4.2 Auxiliary Building 181 27 208 208 1,323 2a.1.4 Totals 606 91 697 697 4,942 Disposal of Plant Systems 2a.1.5.1 1010 Site Improvements 312 47 359 359 6,281 2a.1.5.2 1026 Hydrogen Purge/Particulate Monitor 83 8

44 449 96 681 681 4,208 170,904 1,393 2a.1.5.3 1030 Turbine Bldg Structure 290 43 333 333 5,947 2a.1.5.4 1031 Turbine Bldg Plumbing/Drainage 47 2

11 111 30 202 202 1,039 42,211 934 2a.1.5.5 1033 Turbine Bldg Domestic Water 11 2

12 12 242 2a.1.5.6 1034 Turbine Bldg Fire Protection 284 43 327 327 6,312 2a.1.5.7 1035 Turbine Bldg Heating/Chilled Water 101 15 117 117 2,229 2a.1.5.8 1037 Turbine Bldg Ventilation 258 39 296 296 5,105 2a.1.5.9 1038 Turbine Bldg Decontamination 2

0 0

1 1

4 4

13 548 31 2a.1.5.10 1039 Turbine Bldg Maintenance Facility 11 2

13 13 222 2a.1.5.11 1040 Intake Structure 7

1 8

8 136 2a.1.5.12 1042 Intake Structure Screens 17 3

20 20 345 2a.1.5.13 1046 Intake Structure Chlorination 16 2

18 18 327 2a.1.5.14 1047 Intake Structure Ventilation 5

1 6

6 107 2a.1.5.15 1081 Yard Structures 5

1 5

5 94 2a.1.5.16 1089 Other Facilites 2

0 3

3 45 2a.1.5.17 1091 Start-UP Boiler(92-97) 73 11 84 84 1,544 2a.1.5.18 1093 Central Support Bldg (92-97) 30 5

35 35 598 2a.1.5.19 2011 Reactor Vessel Equipment 24 3

9 47 21 20 124 124 438 105 24,421 480 2a.1.5.20 2012 Reactor Instrumentation 25 3

10 73 13 22 146 146 681 64 31,688 491 2a.1.5.21 2013 Reactor Control Rods 32 14 42 213 102 73 476 476 1,994 502 112,912 622 2a.1.5.22 2022 Pressurizer 163 11 60 606 142 982 982 5,676 230,488 3,145 2a.1.5.23 2031 Component Cooling Water 350 10 58 584 185 1,188 1,188 5,471 222,192 6,093 2a.1.5.24 2032 Safety Injection 365 26 144 1,456 334 2,326 2,326 13,636 553,775 6,569 2a.1.5.25 2033 Containment Spray 257 11 59 594 163 1,083 1,083 5,561 225,832 4,350 2a.1.5.26 2042 Boron Management 389 56 133 539 382 299 1,798 1,798 5,049 1,852 323,930 7,041 2a.1.5.27 2043 Boric Acid Concentrator 106 3

18 177 56 360 360 1,661 67,459 1,815 2a.1.5.28 2061 Primary Sampling 81 6

12 44 35 38 216 216 410 170 27,695 1,494 2a.1.5.29 2062 Nitrogen/High Purity Hydrogen 79 11 15 18 64 42 229 229 166 306 26,817 1,181 2a.1.5.30 2063 Start-Up Boiler 106 16 122 122 2,209 2a.1.5.31 2071 Condensate 1,468 76 423 4,268 1,078 7,314 7,314 39,964 1,622,965 27,271 2a.1.5.32 2073 Feedwater Htrs/Moisture Sep Drains 134 6

35 349 92 616 616 3,271 132,832 2,467 2a.1.5.33 2074 Plant Makeup Water 646 16 91 917 314 1,984 1,984 8,583 348,546 11,100 2a.1.5.34 2081 Main Steam 422 34 191 1,926 427 3,000 3,000 18,033 732,348 8,029 2a.1.5.35 2082 Reheat Steam 291 21 119 1,199 273 1,903 1,903 11,228 455,964 5,194 2a.1.5.36 2083 Extraction Steam 700 29 158 1,600 441 2,928 2,928 14,976 608,184 12,576 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 15 of 22 Table C-2 Arkansas Nuclear One Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 10:30:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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.1.5.37 2084 Main Feedwater 606 41 225 2,275 531 3,677 3,677 21,298 864,940 11,385 2a.1.5.38 2086 Emergency Feedwater 118 3

19 195 62 397 397 1,823 74,016 2,073 2a.1.5.39 3011 Turbine Stator 11 1

4 38 9

64 64 360 14,634 224 2a.1.5.40 3021 Electro-Hydraulic 83 12 95 95 1,807 2a.1.5.41 3022 Gland Steam 94 3

15 147 48 306 306 1,379 56,005 1,594 2a.1.5.42 3023 Lube Oil 148 22 170 170 3,043 2a.1.5.43 3024 Moisture Separator/Reheaters 94 17 95 959 183 1,349 1,349 8,983 364,815 1,861 2a.1.5.44 3025 Turbine Sampling 73 2

13 130 40 258 258 1,214 49,298 1,411 2a.1.5.45 3032 Main Generator Exciter 25 4

29 29 502 2a.1.5.46 3042 Generator Cooling 91 14 104 104 1,908 2a.1.5.47 3043 Seal Oil 48 7

56 56 997 2a.1.5.48 3052 Condensate Vacuum 26 6

31 316 59 438 438 2,957 120,103 522 2a.1.5.49 3053 Main Condenser Pumps 25 4

28 28 500 2a.1.5.50 3054 Condenser Tube Cleaning 26 4

30 30 560 2a.1.5.51 3061 Circulating Water 150 23 173 173 3,136 2a.1.5.52 3071 Cooling Tower Structure 52 8

60 60 1,112 2a.1.5.53 3072 Cooling Tower Pumphouse Structure 2

0 2

2 39 2a.1.5.54 3073 Cooling Tower Chemical Traetment 13 2

15 15 258 2a.1.5.55 3074 Plant Additions (86-91) 19 3

22 22 399 2a.1.5.56 5021 Laboratory Equipment 9

1 11 11 188 2a.1.5.57 5026 Service Equipment 1

0 1

1 18 2a.1.5 Totals 8,906 420 2,033 19,233 618 5,391 36,601 34,048 2,553 180,075 2,998 7,505,521 167,552 2a.1.6 Scaffolding in support of decommissioning 787 12 9

68 10 212 1,098 1,098 572 50 28,969 18,121 2a.1 Subtotal Period 2a Activity Costs 616 38,731 29,670 12,799 25,860 27,280 758 41,553 177,267 174,714 2,553 256,748 76,140 574 337 17,354,010 333,564 10,586 Period 2a Additional Costs 2a.2.1 Remedial Action Surveys 1,699 510 2,209 2,209 34,852 2a.2 Subtotal Period 2a Additional Costs 1,699 510 2,209 2,209 34,852 Period 2a Collateral Costs 2a.3.1 Process decommissioning water waste 85 56 163 176 117 597 597 493 29,593 96 2a.3.2 Process decommissioning chemical flush waste 2a.3.3 Small tool allowance 325 49 374 337 37 2a.3.4 Spent Fuel Capital and Transfer 17,381 2,607 19,988 19,988 2a.3.5 Annual Fees 202 30 232 232 2a.3 Subtotal Period 2a Collateral Costs 85 325 56 163 176 17,583 2,803 21,191 1,166 19,988 37 493 29,593 96 Period 2a Period-Dependent Costs 2a.4.1 Decon supplies 151 38 189 189 2a.4.2 Insurance 696 70 765 765 2a.4.3 Property taxes 3

0 3

3 2a.4.4 Health physics supplies 4,935 1,234 6,168 6,168 2a.4.5 Heavy equipment rental 4,758 714 5,472 5,472 2a.4.6 Disposal of DAW generated 121 71 322 103 617 617 6,118 122,354 200 2a.4.7 Plant energy budget 2,775 416 3,191 3,191 2a.4.8 NRC Fees 990 99 1,089 1,089 2a.4.9 Emergency Planning Fees 1,277 128 1,404 1,404 2a.4.10 Indirect Overhead 2,598 390 2,988 2,988 2a.4.11 Spent Fuel Pool O&M 1,725 259 1,983 1,983 2a.4.12 ISFSI Operating Costs 111 17 128 128 2a.4.13 Corporate A&G Cost 12,072 1,811 13,882 13,882 2a.4.14 Environmental Audit 1,557 234 1,791 1,791 2a.4.15 Security Staff Cost 15,834 2,375 18,209 18,209 249,354 2a.4.16 DOC Staff Cost 31,128 4,669 35,797 35,797 265,055 2a.4.17 Utility Staff Cost 40,249 6,037 46,286 46,286 493,490 2a.4 Subtotal Period 2a Period-Dependent Costs 151 9,693 121 71 322 111,014 18,592 139,964 136,448 3,516 6,118 122,354 200 1,007,899 2a.0 TOTAL PERIOD 2a COST 851 48,749 29,848 13,032 25,860 27,778 131,054 63,458 340,631 314,537 23,504 2,591 256,748 82,751 574 337 17,505,960 368,711 1,018,485 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 16 of 22 Table C-2 Arkansas Nuclear One Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 10:30:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

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

Manhours Manhours PERIOD 2b - Site Decontamination Period 2b Direct Decommissioning Activities Disposal of Plant Systems 2b.1.1.1 1011 Site Drainage/ Storm Sewer 2

0 2

2 39 2b.1.1.2 1012 Site Sanitary Sewer 11 2

13 13 220 2b.1.1.3 1013 Site Raw Water 46 7

53 53 917 2b.1.1.4 1014 Site Fire Protection 216 32 249 249 4,801 2b.1.1.5 1016 Site Fuel Oil 85 13 98 98 1,654 2b.1.1.6 1021 Reactor Bldg Plumbing/Drainage 32 1

6 60 18 117 117 561 22,773 506 2b.1.1.7 1024 Reactor Bldg Fire Protection 53 1

7 68 24 153 153 636 25,832 862 2b.1.1.8 1025 Reactor Bldg Heating/Chilled Water 58 1

7 68 26 160 160 637 25,887 942 2b.1.1.9 1027 Reactor Bldg Ventilation 106 7

40 407 94 655 655 3,813 154,855 1,950 2b.1.1.10 1028 Reactor Bldg Decontamination 266 5

28 287 114 701 701 2,687 109,137 4,886 2b.1.1.11 1050 Auxiliary Bldg Structure 471 71 541 541 9,658 2b.1.1.12 1051 Auxiliary Bldg Plumbing/Drainage 7

0 1

5 3

15 15 48 1,959 122 2b.1.1.13 1053 Auxiliary Bldg Domestic Water 77 1

8 78 32 196 196 729 29,600 1,260 2b.1.1.14 1054 Auxiliary Bldg Fire Protection 459 9

51 511 200 1,230 1,230 4,785 194,309 7,142 2b.1.1.15 1055 Auxiliary Bldg Heating/Chilled Watr 507 18 102 1,033 299 1,959 1,959 9,668 392,623 8,875 2b.1.1.16 1057 Auxiliary Bldg Ventilation 344 31 173 1,748 377 2,673 2,673 16,362 664,464 6,438 2b.1.1.17 1058 Auxiliary Bldg Decontamination 751 11 58 588 286 1,694 1,694 5,508 223,684 13,750 2b.1.1.18 1060 Boiler Plant Structure 3

0 3

3 61 2b.1.1.19 1065 Boiler Plant Heating 54 8

62 62 1,114 2b.1.1.20 1070 Administrative Bldg 56 8

65 65 1,145 2b.1.1.21 1090 Plant Additions (86-91) 78 12 90 90 1,646 2b.1.1.22 1092 Station Black-Out Boiler(92-97) 90 13 103 103 1,804 2b.1.1.23 1094 Control Room Extension (92-97) 95 14 109 109 1,952 2b.1.1.24 1095 Hazardous WasteStorage Bldg(92-97) 6 1

7 7

117 2b.1.1.25 2021 Reactor Coolant 35 2

10 85 6

25 163 163 798 31 34,408 682 2b.1.1.26 2023 Chemical/Volume Control 656 25 136 1,373 393 2,583 2,583 12,859 522,217 11,779 2b.1.1.27 2034 Service/Auxiliary Cooling Water 2,172 163 903 9,121 2,063 14,423 14,423 85,396 3,467,988 40,796 2b.1.1.28 2041 Gaseous Radwaste 110 24 48 147 160 99 589 589 1,378 773 105,925 1,814 2b.1.1.29 2044 Liquid Radwaste 161 152 22 46 147 151 187 865 865 1,375 727 102,736 5,328 2b.1.1.30 2045 Liquid Radwaste Concentrator 105 74 14 23 25 96 104 440 440 235 461 39,412 2,207 2b.1.1.31 2045 Liquid Radwaste Electrical 9

2 11 110 21 153 153 1,034 42,000 171 2b.1.1.32 2046 Solid Radwaste 85 21 55 222 157 104 644 644 2,076 767 133,322 1,525 2b.1.1.33 2051 Reactor Bldg Fuel Handling 14 1

5 49 12 80 80 457 18,563 269 2b.1.1.34 2064 Regenerative Waste 328 52 124 349 427 265 1,545 1,545 3,265 2,085 265,763 5,741 2b.1.1.35 2065 Regenerative Waste Evaporator 56 18 48 200 136 87 546 546 1,871 666 118,462 1,027 2b.1.1.36 2072 Startup/Blowdown Demineralizer 228 34 262 262 4,868 2b.1.1.37 2087 Reactor Bldg Additions (86-91) 45 3

15 151 37 251 251 1,416 57,517 853 2b.1.1.38 3026 Turbine Drains 59 1

6 62 25 154 154 585 23,756 886 2b.1.1.39 4011 Station Switchgear 119 18 137 137 2,339 2b.1.1.40 4021 Station Service Generator Bus/Aux 14 2

16 16 282 2b.1.1.41 4022 Station Startup Equipment 13 2

15 15 260 2b.1.1.42 4023 StationUnit Auxiliary Equipment 13 2

15 15 259 2b.1.1.43 4024 Station Distribution System 8

1 9

9 154 2b.1.1.44 4025 DC Distribution System 46 7

53 53 948 2b.1.1.45 4041 Electrical Bus Duct 6

1 7

7 125 2b.1.1.46 4042 Elect Structures/Wiring/Contners 1,122 168 1,291 1,291 22,469 2b.1.1.47 4043 Contaminated Conduit 1,921 26 150 1,513 732 4,343 4,343 14,167 575,341 35,938 2b.1.1.48 4051 Emergency Diesel Engines 40 6

46 46 824 2b.1.1.49 4061 Main Control Room Panels 33 5

38 38 666 2b.1.1.50 4062 Local Panels/Instruments 125 19 144 144 2,721 2b.1.1.51 4063 Plant Computer 11 2

13 13 225 2b.1.1.52 4064 Radiation Monitoring 80 2

11 110 38 241 241 1,030 41,823 1,544 2b.1.1.53 4065 Plant Additions (86-91) 10 1

11 11 197 2b.1.1.54 4065 Plant Additions (86-91)Contaminated 20 0

2 19 8

49 49 174 7,049 388 2b.1.1.55 5011 Instrument Air 199 3

15 156 76 448 448 1,457 59,182 3,330 2b.1.1.56 5012 Service Air 180 2

13 129 66 390 390 1,210 49,153 3,005 2b.1.1.57 5014 Public Address 51 8

59 59 1,024 2b.1.1.58 5016 Site Environment Monitoring 24 4

28 28 467 2b.1.1.59 5017 Telephone 69 10 80 80 1,389 2b.1.1.60 5031 Lab/Health Physics/Shop Equipment 55 8

63 63 1,110 2b.1.1.61 5042 Kitchen Equipment 0

0 1

1 9

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 17 of 22 Table C-2 Arkansas Nuclear One Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 10:30:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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) 2b.1.1.62 5051 Machine Shop Equipment 1

0 1

1 18 2b.1.1.63 5301 Main Transformers 12 2

13 13 225 2b.1.1.64 Plant Additions(98-02) 70 1

8 82 31 193 193 765 31,078 1,314 2b.1.1 Totals 266 12,139 470 2,108 18,903 1,134 6,328 41,348 37,651 3,697 176,984 5,511 7,540,817 231,034 2b.1.2 Scaffolding in support of decommissioning 983 16 11 85 13 265 1,372 1,372 716 63 36,211 22,651 Decontamination of Site Buildings 2b.1.3.1 Reactor 2,558 3,059 304 3,310 2,075 8,598 5,031 24,936 24,936 19,428 100,080 5,027,329 86,577 2b.1.3.2 Administrative Building 24 75 952 683 327 2,060 2,060 24,492 1,156,952 262 2b.1.3.3 Auxiliary Building 905 141 9

101 89 72 535 1,853 1,853 837 2,393 147,529 20,331 2b.1.3.4 CA-3 Building 4

2 6

6 76 2b.1.3.5 Low Level Radwaste Storage 238 13 1

2 24 2

126 405 405 221 8

9,497 4,966 2b.1.3.6 Solid Radwaste Storage Building 33 6

0 3

3 2

20 68 68 32 73 4,746 767 2b.1.3 Totals 3,738 3,243 390 4,368 2,191 9,356 6,042 29,328 29,328 20,518 127,046 6,346,053 112,978 2b.1.4 Prepare/submit License Termination Plan 369 55 424 424 2,228 2b.1.5 Receive NRC approval of termination plan a

2b.1 Subtotal Period 2b Activity Costs 4,004 16,365 875 6,487 21,179 10,504 369 12,690 72,473 68,775 3,697 198,217 132,621 13,923,080 366,663 2,228 Period 2b Additional Costs 2b.2.1 Remedial Action Surveys 2,360 708 3,068 3,068 48,405 2b.2.2 Cooling Tower Remediation 7,306 973 1,242 9,522 9,522 105,927 2b.2.3 Chemical Waste Pond Closure 493 67 84 644 644 2,233 2b.2 Subtotal Period 2b Additional Costs 7,800 3,400 2,034 13,234 13,234 156,566 Period 2b Collateral Costs 2b.3.1 Process decommissioning water waste 100 69 198 215 140 722 722 600 36,016 117 2b.3.2 Process decommissioning chemical flush waste 0

16 67 91 35 210 210 144 15,316 27 2b.3.3 Small tool allowance 398 60 458 458 2b.3.4 Spent Fuel Capital and Transfer 41,166 6,175 47,341 47,341 2b.3.5 Annual Fees 227 34 261 261 2b.3 Subtotal Period 2b Collateral Costs 101 398 84 266 306 41,393 6,444 48,992 1,650 47,341 744 51,333 144 Period 2b Period-Dependent Costs 2b.4.1 Decon supplies 1,719 430 2,149 2,149 2b.4.2 Insurance 966 97 1,063 1,063 2b.4.3 Property taxes 4

0 5

5 2b.4.4 Health physics supplies 6,924 1,731 8,655 8,655 2b.4.5 Heavy equipment rental 6,774 1,016 7,790 7,790 2b.4.6 Disposal of DAW generated 108 63 287 92 549 549 5,448 108,951 178 2b.4.7 Plant energy budget 3,042 456 3,499 3,499 2b.4.8 NRC Fees 1,375 138 1,513 1,513 2b.4.9 Emergency Planning Fees 1,773 177 1,950 1,950 2b.4.10 Indirect Overhead 3,533 530 4,063 4,063 2b.4.11 Spent Fuel Pool O&M 2,396 359 2,755 2,755 2b.4.12 Liquid Radwaste Processing Equipment/Services 604 91 694 694 2b.4.13 ISFSI Operating Costs 155 23 178 178 2b.4.14 Corporate A&G Cost 8,089 1,213 9,303 9,303 2b.4.15 Environmental Audit 2,163 324 2,487 2,487 2b.4.16 Security Staff Cost 22,129 3,319 25,449 25,449 346,325 2b.4.17 DOC Staff Cost 41,649 6,247 47,896 47,896 353,600 2b.4.18 Utility Staff Cost 53,596 8,039 61,636 61,636 656,340 2b.4 Subtotal Period 2b Period-Dependent Costs 1,719 13,698 108 63 287 141,475 24,284 181,633 176,750 4,883 5,448 108,951 178 1,356,265 2b.0 TOTAL PERIOD 2b COST 5,824 38,260 1,067 6,816 21,179 11,096 186,637 45,452 316,331 260,409 52,225 3,697 198,217 138,812 14,083,360 523,550 1,358,493 PERIOD 2d - Decontamination Following Wet Fuel Storage Period 2d Direct Decommissioning Activities 2d.1.1 Remove spent fuel racks 312 32 107 111 533 324 1,419 1,419 2,613 166,023 720 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 18 of 22 Table C-2 Arkansas Nuclear One Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 10:30:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 2d.1.2.1 2052 Auxiliary Bldg Fuel Handling 7

1 3

33 7

52 52 309 12,553 145 2d.1.2.2 2054 Fuel Pool Cooling 136 9

49 495 117 806 806 4,634 188,182 2,355 2d.1.2 Totals 144 9

52 528 124 857 857 4,943 200,735 2,501 Decontamination of Site Buildings 2d.1.3.1 Fuel Handling Area 417 473 5

19 147 14 356 1,431 1,431 1,374 170 64,782 16,608 2d.1.3 Totals 417 473 5

19 147 14 356 1,431 1,431 1,374 170 64,782 16,608 2d.1.4 Scaffolding in support of decommissioning 197 3

2 17 3

53 274 274 143 13 7,242 4,530 2d.1 Subtotal Period 2d Activity Costs 728 845 124 185 692 550 857 3,982 3,982 6,460 2,796 438,782 24,359 Period 2d Additional Costs 2d.2.1 License Termination Survey Planning 1,503 451 1,954 1,954 6,240 2d.2.2 Operational Tools & Equipment 11 52 385 67 514 514 5,850 146,250 16 2d.2.3 Excavation of Underground Services 1,184 403 356 1,943 1,943 10,264 2d.2.4 Remedial Action Surveys 339 102 440 440 6,948 2d.2 Subtotal Period 2d Additional Costs 1,184 11 52 385 2,245 976 4,852 4,852 5,850 146,250 17,227 6,240 Period 2d Collateral Costs 2d.3.1 Process decommissioning water waste 67 46 133 144 94 484 484 403 24,155 78 2d.3.2 Process decommissioning chemical flush waste 2d.3.3 Small tool allowance 36 5

41 41 2d.3.4 Decommissioning Equipment Disposition 130 104 710 108 162 1,214 1,214 6,000 529 303,608 147 2d.3.5 Spent Fuel Capital and Transfer 400 60 460 460 2d.3.6 Annual Fees 33 5

37 31 6

2d.3 Subtotal Period 2d Collateral Costs 67 36 176 237 710 252 433 326 2,237 1,771 466 6,000 932 327,763 225 Period 2d Period-Dependent Costs 2d.4.1 Decon supplies 99 25 123 123 2d.4.2 Insurance 139 14 153 153 2d.4.3 Property taxes 1

0 1

1 2d.4.4 Health physics supplies 618 155 773 773 2d.4.5 Heavy equipment rental 972 146 1,118 1,118 2d.4.6 Disposal of DAW generated 18 10 47 15 90 90 897 17,936 29 2d.4.7 Plant energy budget 233 35 268 268 2d.4.8 NRC Fees 190 19 209 209 2d.4.9 Indirect Overhead 200 30 230 219 11 2d.4.10 Liquid Radwaste Processing Equipment/Services 173 26 199 199 2d.4.11 ISFSI Operating Costs 22 3

26 26 2d.4.12 Corporate A&G Cost 532 80 611 583 28 2d.4.13 Environmental Audit 310 47 357 357 2d.4.14 Security Staff Cost 1,638 246 1,884 1,356 528 34,065 2d.4.15 DOC Staff Cost 4,108 616 4,724 4,724 34,762 2d.4.16 Utility Staff Cost 5,646 847 6,493 6,195 299 66,395 2d.4 Subtotal Period 2d Period-Dependent Costs 99 1,591 18 10 47 13,192 2,303 17,259 16,369 890 897 17,936 29 135,222 2d.0 TOTAL PERIOD 2d COST 894 3,656 329 485 1,786 849 15,870 4,462 28,330 26,973 1,357 18,310 4,624 930,731 41,841 141,462 PERIOD 2f - License Termination Period 2f Direct Decommissioning Activities 2f.1.1 ORISE confirmatory survey 176 53 229 229 2f.1.2 Terminate license a

2f.1 Subtotal Period 2f Activity Costs 176 53 229 229 Period 2f Additional Costs 2f.2.1 License Termination Survey 6,800 2,040 8,840 8,840 121,022 3,120 2f.2 Subtotal Period 2f Additional Costs 6,800 2,040 8,840 8,840 121,022 3,120 Period 2f Collateral Costs 2f.3.1 DOC staff relocation expenses 1,465 220 1,685 1,685 2f.3.2 Spent Fuel Capital and Transfer 891 134 1,025 1,025 2f.3.3 Annual Fees 47 7

54 34 20 2f.3 Subtotal Period 2f Collateral Costs 2,403 360 2,764 1,718 1,045 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 19 of 22 Table C-2 Arkansas Nuclear One Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 10:30:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 2f Period-Dependent Costs 2f.4.1 Insurance 325 33 358 358 2f.4.2 Property taxes 1

0 2

2 2f.4.3 Health physics supplies 1,270 317 1,587 1,587 2f.4.4 Disposal of DAW generated 7

4 18 6

35 35 350 7,004 11 2f.4.5 Plant energy budget 273 41 314 314 2f.4.6 NRC Fees 465 47 512 512 2f.4.7 Indirect Overhead 224 34 258 236 22 2f.4.8 ISFSI Operating Costs 52 8

60 60 2f.4.9 Corporate A&G Cost 1,109 166 1,275 1,167 108 2f.4.10 Environmental Audit 728 109 837 837 2f.4.11 Security Staff Cost 3,840 576 4,417 3,180 1,237 79,858 2f.4.12 DOC Staff Cost 5,778 867 6,644 6,644 48,487 2f.4.13 Utility Staff Cost 5,640 846 6,485 5,934 551 62,340 2f.4 Subtotal Period 2f Period-Dependent Costs 1,270 7

4 18 18,435 3,049 22,783 20,805 1,978 350 7,004 11 190,685 2f.0 TOTAL PERIOD 2f COST 1,270 7

4 18 27,815 5,503 34,617 31,593 3,023 350 7,004 121,033 193,805 PERIOD 2 TOTALS 7,569 91,935 31,251 20,337 48,826 39,741 361,376 118,874 719,909 633,513 80,108 6,288 473,275 226,538 574 337 32,527,060 1,055,135 2,712,245 PERIOD 3b - Site Restoration Period 3b Direct Decommissioning Activities Demolition of Remaining Site Buildings 3b.1.1.1 Reactor 2,531 380 2,911 2,911 21,126 3b.1.1.2 AAC Generator Building 18 3

21 21 187 3b.1.1.3 Administrative Building 54 8

62 62 327 3b.1.1.4 Auxiliary Building 1,663 250 1,913 1,913 12,716 3b.1.1.5 CA-3 Building 16 2

18 18 158 3b.1.1.6 Circulating Water Tunnels/Pipe 285 43 327 327 4,380 3b.1.1.7 Cooling Tower Concrete Removal 22 3

26 26 137 3b.1.1.8 Cooling Tower Pump House 66 10 76 76 696 3b.1.1.9 Degasifier Building 9

1 10 10 89 3b.1.1.10 Diesel Fuel Storage Vault 139 21 160 160 1,393 3b.1.1.11 Flex Buildings 2 (2019) 160 24 184 184 1,250 3b.1.1.12 Intake Structure 42 6

48 48 290 3b.1.1.13 Low Level Radwaste Office 8

1 10 10 163 3b.1.1.14 Low Level Radwaste Storage 339 51 390 390 2,055 3b.1.1.15 Maintenance Facility 369 55 425 425 4,283 3b.1.1.16 Misc Site Structures 1,357 204 1,561 1,561 11,587 3b.1.1.17 Oily Water Seperator 6

1 7

7 37 3b.1.1.18 Old Steam Gen. Storage Facility 164 25 189 189 1,002 3b.1.1.19 Site Additions (02-08) 383 57 440 440 3,132 3b.1.1.20 Site Additions (98-02) 239 36 275 275 2,426 3b.1.1.21 Site Drainage & Storm Sewers 124 19 143 143 1,906 3b.1.1.22 Site Manholes 61 9

71 71 673 3b.1.1.23 Site Paving,Rail & Fencing 633 95 728 728 6,070 3b.1.1.24 Solid Radwaste Storage Building 39 6

45 45 437 3b.1.1.25 Start-Up Boiler 44 7

51 51 612 3b.1.1.26 Tank Foundations 29 4

34 34 208 3b.1.1.27 Turbine Building 1,032 155 1,187 1,187 11,874 3b.1.1.28 Turbine Pedestal 464 70 533 533 2,881 3b.1.1 Totals 10,298 1,545 11,843 11,843 92,097 Site Closeout Activities 3b.1.2 BackFill Site 21,946 3,292 25,238 25,238 51,296 3b.1.3 Grade & landscape site 168 25 194 194 559 3b.1.4 Final report to NRC 140 21 161 161 849 3b.1 Subtotal Period 3b Activity Costs 32,413 140 4,883 37,436 161 37,274 143,952 849 Period 3b Additional Costs 3b.2.1 Concrete Crushing 691 12 105 808 808 3,079 3b.2.2 Construction Debris 1,438 216 1,654 1,654 3b.2.3 Cooling Tower Removal 4,762 714 5,476 5,476 17,913 3b.2.4 Mobile Barrier Removal 183 267 68 518 518 1,200 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 20 of 22 Table C-2 Arkansas Nuclear One Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 10:30:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

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

Manhours Manhours Period 3b Additional Costs (continued) 3b.2.5 Intake and Discharge Cofferdams 653 98 751 751 5,226 3b.2.6 GTCC SFP Legacy Waste 652 98 750 750 7,600 3b.2 Subtotal Period 3b Additional Costs 6,288 2,370 1,299 9,956 750 9,207 7,600 27,418 Period 3b Collateral Costs 3b.3.1 Small tool allowance 170 25 195 195 3b.3.2 Spent Fuel Capital and Transfer 914 137 1,051 1,051 3b.3.3 Annual Fees 126 19 145 145 3b.3 Subtotal Period 3b Collateral Costs 170 1,040 181 1,391 1,196 195 Period 3b Period-Dependent Costs 3b.4.1 Insurance 436 44 479 479 3b.4.2 Property taxes 4

0 4

4 3b.4.3 Heavy equipment rental 8,367 1,255 9,622 9,622 3b.4.4 Plant energy budget 366 55 421 421 3b.4.5 NRC ISFSI Fees 515 52 567 567 3b.4.6 Indirect Overhead 209 31 241 63 178 3b.4.7 ISFSI Operating Costs 140 21 161 161 3b.4.8 Corporate A&G Cost 1,170 176 1,346 (0) 513 833 3b.4.9 Environmental Audit 1,952 293 2,244 2,244 3b.4.10 Security Staff Cost 5,416 812 6,228 3,320 2,909 104,898 3b.4.11 DOC Staff Cost 14,481 2,172 16,653 16,653 115,828 3b.4.12 Utility Staff Cost 6,491 974 7,465 0

1,478 5,987 73,758 3b.4 Subtotal Period 3b Period-Dependent Costs 8,367 31,180 5,884 45,431 0

6,105 39,326 294,483 3b.0 TOTAL PERIOD 3b COST 47,237 34,730 12,247 94,214 911 7,301 86,002 7,600 171,370 295,332 PERIOD 3c - Fuel Storage Operations/Shipping Period 3c Direct Decommissioning Activities Period 3c Collateral Costs 3c.3.1 Spent Fuel Capital and Transfer 21,445 3,217 24,662 24,662 3c.3.2 Annual Fees 2,202 330 2,533 2,533 3c.3 Subtotal Period 3c Collateral Costs 23,648 3,547 27,195 27,195 Period 3c Period-Dependent Costs 3c.4.1 Insurance 7,618 762 8,380 8,380 3c.4.2 Property taxes 66 7

73 73 3c.4.3 Plant energy budget 3c.4.4 NRC ISFSI Fees 9,002 900 9,902 9,902 3c.4.5 Indirect Overhead 961 144 1,105 1,105 3c.4.6 ISFSI Operating Costs 2,441 366 2,808 2,808 3c.4.7 Corporate A&G Cost 6,846 1,027 7,873 7,873 3c.4.8 Security Staff Cost 50,465 7,570 58,035 58,035 1,069,513 3c.4.9 Utility Staff Cost 22,466 3,370 25,836 25,836 257,836 3c.4 Subtotal Period 3c Period-Dependent Costs 99,865 14,146 114,011 114,011 1,327,349 3c.0 TOTAL PERIOD 3c COST 123,513 17,693 141,206 141,206 1,327,349 PERIOD 3d - GTCC shipping Period 3d Direct Decommissioning Activities Nuclear Steam Supply System Removal 3d.1.1.1 Vessel & Internals GTCC Disposal 1,200 7,778 1,467 10,445 10,445 1,773 353,913 3d.1.1 Totals 1,200 7,778 1,467 10,445 10,445 1,773 353,913 3d.1 Subtotal Period 3d Activity Costs 1,200 7,778 1,467 10,445 10,445 1,773 353,913 Period 3d Collateral Costs 3d.3.1 Annual Fees 2

0 3

3 3d.3 Subtotal Period 3d Collateral Costs 2

0 3

3 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 21 of 22 Table C-2 Arkansas Nuclear One Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 10:30:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

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

Manhours Manhours Period 3d Period-Dependent Costs 3d.4.1 Insurance 8

1 9

9 3d.4.2 Property taxes 0

0 0

0 3d.4.3 Plant energy budget 3d.4.4 NRC ISFSI Fees 7

1 8

8 3d.4.5 Indirect Overhead 1

0 1

1 3d.4.6 ISFSI Operating Costs 3

0 3

3 3d.4.7 Corporate A&G Cost 7

1 8

8 3d.4.8 Security Staff Cost 53 8

61 61 1,117 3d.4.9 Utility Staff Cost 23 4

27 27 269 3d.4 Subtotal Period 3d Period-Dependent Costs 102 15 116 106 11 1,386 3d.0 TOTAL PERIOD 3d COST 1,200 7,778 104 1,482 10,564 10,554 11 1,773 353,913 1,386 PERIOD 3e - ISFSI Decontamination Period 3e Direct Decommissioning Activities Period 3e Additional Costs 3e.2.1 License Termination ISFSI 246 184 1,269 1,921 2,056 1,419 7,097 7,097 12,855 1,641,085 10,687 1,245 3e.2 Subtotal Period 3e Additional Costs 246 184 1,269 1,921 2,056 1,419 7,097 7,097 12,855 1,641,085 10,687 1,245 Period 3e Collateral Costs 3e.3.1 Annual Fees 20 5

25 25 3e.3 Subtotal Period 3e Collateral Costs 20 5

25 25 Period 3e Period-Dependent Costs 3e.4.1 Insurance 50 12 62 62 3e.4.2 Property taxes 1

0 1

1 3e.4.3 Plant energy budget 6

1 7

7 3e.4.4 Indirect Overhead 8

2 10 10 3e.4.5 Corporate A&G Cost 40 10 50 50 3e.4.6 Security Staff Cost 118 30 148 148 2,541 3e.4.7 Utility Staff Cost 168 42 209 209 1,928 3e.4 Subtotal Period 3e Period-Dependent Costs 390 97 487 487 4,468 3e.0 TOTAL PERIOD 3e COST 246 184 1,269 1,921 2,466 1,522 7,609 7,609 12,855 1,641,085 10,687 5,713 PERIOD 3f - ISFSI Site Restoration Period 3f Direct Decommissioning Activities Period 3f Additional Costs 3f.2.1 Demolition and Site Restoration ISFSI 3,610 469 612 4,691 4,691 30,191 80 3f.2 Subtotal Period 3f Additional Costs 3,610 469 612 4,691 4,691 30,191 80 Period 3f Collateral Costs 3f.3.1 Small tool allowance 43 7

50 50 3f.3 Subtotal Period 3f Collateral Costs 43 7

50 50 Period 3f Period-Dependent Costs 3f.4.1 Insurance 3f.4.2 Property taxes 0

0 0

0 3f.4.3 Plant energy budget 3

0 3

3 3f.4.4 Indirect Overhead 3

1 4

4 3f.4.5 Corporate A&G Cost 20 3

23 23 3f.4.6 Security Staff Cost 60 9

68 68 1,281 3f.4.7 Utility Staff Cost 75 11 86 86 795 3f.4 Subtotal Period 3f Period-Dependent Costs 161 24 185 185 2,076 3f.0 TOTAL PERIOD 3f COST 3,654 630 643 4,926 4,926 30,191 2,156 PERIOD 3 TOTALS 51,137 1,384 1,269 9,700 161,443 33,586 258,520 19,074 148,518 90,928 12,855 1,773 2,002,598 212,248 1,631,935 TOTAL COST TO DECOMMISSION 12,405 147,456 32,762 22,039 48,826 51,626 684,845 179,510 1,179,470 828,202 252,937 98,331 473,275 240,613 1,301 337 1,773 34,641,300 1,286,224 5,347,652 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix C, Page 22 of 22 Table C-2 Arkansas Nuclear One Unit 2 DECON Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Tue, Mar 5, 2024 at 10:30:46 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 17.95% CONTINGENCY:

$1,179,470 thousands of 2024 dollars TOTAL NRC LICENSE TERMINATION COST IS 70.22% OR:

$828,202 thousands of 2024 dollars SPENT FUEL MANAGEMENT COST IS 21.44% OR:

$252,937 thousands of 2024 dollars NON-NUCLEAR DEMOLITION COST IS 8.34% OR:

$98,331 thousands of 2024 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

242,251 Cubic Feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

1,773 Cubic Feet TOTAL SCRAP METAL REMOVED:

50,204 Tons TOTAL CRAFT LABOR REQUIREMENTS:

1,286,224 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, LLC

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Appendix D, Page 1 of 25 TLG Services, LLC APPENDIX D DETAILED COST ANALYSIS SAFSTOR Schedule of Annual Expenditures, ANO-1............................................................... D-2 Schedule of Annual Expenditures, ANO-2............................................................. D-14

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 2 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 379 114 493 493 1a.1.2 Prepare preliminary decommissioning cost 215 32 247 247 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 331 50 380 380 2,000 1a.1.8 Review plant dwgs & specs.

215 32 247 247 1,300 1a.1.9 Perform detailed rad survey a

1a.1.10 Estimate by-product inventory 165 25 190 190 1,000 1a.1.11 End product description 165 25 190 190 1,000 1a.1.12 Detailed by-product inventory 248 37 285 285 1,500 1a.1.13 Define major work sequence 165 25 190 190 1,000 1a.1.14 Perform SER and EA 513 77 590 590 3,100 1a.1.15 Perform Site-Specific Cost Study 827 124 951 951 5,000 Activity Specifications 1a.1.16.1 Prepare plant and facilities for SAFSTOR 814 122 936 936 4,920 1a.1.16.2 Plant systems 689 103 792 792 4,167 1a.1.16.3 Plant structures and buildings 516 77 593 593 3,120 1a.1.16.4 Waste management 331 50 380 380 2,000 1a.1.16.5 Facility and site dormancy 331 50 380 380 2,000 1a.1.16 Total 2,680 402 3,082 3,082 16,207 Detailed Work Procedures 1a.1.17.1 Plant systems 196 29 225 225 1,183 1a.1.17.2 Facility closeout & dormancy 198 30 228 228 1,200 1a.1.17 Total 394 59 453 453 2,383 1a.1.18 Procure vacuum drying system 17 2

19 19 100 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 6,315 1,004 7,319 7,319 35,890 Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 5,241 786 6,027 6,027 1a.3.2 Annual Fees 187 28 215 215 1a.3 Subtotal Period 1a Collateral Costs 5,429 814 6,243 215 6,027 Period 1a Period-Dependent Costs 1a.4.1 Insurance 1,421 142 1,564 1,564 1a.4.2 Property taxes 12 1

13 13 1a.4.3 Health physics supplies 970 242 1,212 1,212 1a.4.4 Heavy equipment rental 908 136 1,045 1,045 1a.4.5 Disposal of DAW generated 12 7

32 10 62 62 616 12,311 20 1a.4.6 Plant energy budget 1,565 235 1,800 1,800 1a.4.7 NRC Fees 1,182 118 1,300 1,300 1a.4.8 Emergency Planning Fees 1,049 105 1,154 1,154 1a.4.9 Indirect Overhead 1,912 287 2,199 2,199 1a.4.10 Spent Fuel Pool O&M 1,029 154 1,183 1,183 1a.4.11 ISFSI Operating Costs 66 10 76 76 1a.4.12 Corporate A&G Cost 15,798 2,370 18,168 18,168 1a.4.13 Environmental Audit 704 106 810 810 1a.4.14 Security Staff Cost 9,580 1,437 11,017 11,017 150,169 1a.4.15 Utility Staff Cost 34,665 5,200 39,864 39,864 432,640 1a.4 Subtotal Period 1a Period-Dependent Costs 1,878 12 7

32 68,985 10,553 81,468 79,054 2,413 616 12,311 20 582,809 1a.0 TOTAL PERIOD 1a COST 1,878 12 7

32 80,728 12,372 95,029 86,589 8,441 616 12,311 20 618,699 PERIOD 1b - SAFSTOR Limited DECON Activities TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 3 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 Direct Decommissioning Activities Decontamination of Site Buildings 1b.1.1.1 Reactor 981 490 1,471 1,471 19,077 1b.1.1.2 Auxiliary Building 818 409 1,227 1,227 16,447 1b.1.1.3 Fuel Handling Area 410 205 615 615 7,158 1b.1.1 Totals 2,209 1,104 3,313 3,313 42,682 1b.1 Subtotal Period 1b Activity Costs 2,209 1,104 3,313 3,313 42,682 Period 1b Additional Costs 1b.2.1 Spent Fuel Pool Isolation 15,055 2,258 17,313 17,313 1b.2 Subtotal Period 1b Additional Costs 15,055 2,258 17,313 17,313 Period 1b Collateral Costs 1b.3.1 Decon equipment 1,253 188 1,441 1,441 1b.3.2 Process decommissioning water waste 154 101 291 315 210 1,071 1,071 882 52,918 172 1b.3.3 Process decommissioning chemical flush waste 1b.3.4 Small tool allowance 36 5

42 42 1b.3.5 Spent Fuel Capital and Transfer 3,431 515 3,946 3,946 1b.3.6 Annual Fees 43 6

49 49 1b.3 Subtotal Period 1b Collateral Costs 1,407 36 101 291 315 3,474 924 6,549 2,603 3,946 882 52,918 172 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 1,257 314 1,571 1,571 1b.4.2 Insurance 354 35 390 390 1b.4.3 Property taxes 3

0 3

3 1b.4.4 Health physics supplies 624 156 780 780 1b.4.5 Heavy equipment rental 226 34 260 260 1b.4.6 Disposal of DAW generated 12 7

31 10 60 60 596 11,927 19 1b.4.7 Plant energy budget 390 59 449 449 1b.4.8 NRC Fees 224 22 247 247 1b.4.9 Emergency Planning Fees 262 26 288 288 1b.4.10 Indirect Overhead 477 71 548 548 1b.4.11 Spent Fuel Pool O&M 256 38 295 295 1b.4.12 ISFSI Operating Costs 17 2

19 19 1b.4.13 Corporate A&G Cost 3,893 584 4,476 4,476 1b.4.14 Environmental Audit 176 26 202 202 1b.4.15 Security Staff Cost 2,363 354 2,717 2,717 37,077 1b.4.16 Utility Staff Cost 8,552 1,283 9,834 9,834 107,864 1b.4 Subtotal Period 1b Period-Dependent Costs 1,257 850 12 7

31 16,966 3,017 22,140 21,538 602 596 11,927 19 144,941 1b.0 TOTAL PERIOD 1b COST 4,872 886 113 298 347 35,495 7,304 49,315 44,767 4,548 1,478 64,845 42,873 144,941 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 536 80 616 616 3,000 1c.1.2 Install containment pressure equal. lines 41 6

47 47 700 1c.1.3 Interim survey prior to dormancy 733 220 953 953 14,150 1c.1.4 Secure building accesses a

1c.1.5 Prepare & submit interim report 96 14 111 111 583 1c.1 Subtotal Period 1c Activity Costs 577 829 321 1,727 1,727 17,850 583 Period 1c Collateral Costs 1c.3.1 Process decommissioning water waste 182 119 344 373 248 1,267 1,267 1,043 62,584 203 1c.3.2 Process decommissioning chemical flush waste 1c.3.3 Small tool allowance 4

1 4

4 1c.3.4 Spent Fuel Capital and Transfer 3,431 515 3,946 3,946 1c.3.5 Annual Fees 42 6

48 48 1c.3 Subtotal Period 1c Collateral Costs 182 4

119 344 373 3,473 769 5,265 1,319 3,946 1,043 62,584 203 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 4 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 1c.4.1 Insurance 354 35 390 390 1c.4.2 Property taxes 3

0 3

3 1c.4.3 Health physics supplies 403 101 503 503 1c.4.4 Heavy equipment rental 226 34 260 260 1c.4.5 Disposal of DAW generated 3

2 8

3 15 15 153 3,069 5

1c.4.6 Plant energy budget 390 59 449 449 1c.4.7 NRC Fees 224 22 247 247 1c.4.8 Emergency Planning Fees 262 26 288 288 1c.4.9 Indirect Overhead 477 71 548 548 1c.4.10 Spent Fuel Pool O&M 256 38 295 295 1c.4.11 ISFSI Operating Costs 17 2

19 19 1c.4.12 Corporate A&G Cost 3,893 584 4,476 4,476 1c.4.13 Environmental Audit 176 26 202 202 1c.4.14 Security Staff Cost 2,363 354 2,717 2,717 37,077 1c.4.15 Utility Staff Cost 8,552 1,283 9,834 9,834 107,864 1c.4 Subtotal Period 1c Period-Dependent Costs 629 3

2 8

16,966 2,640 20,248 19,646 602 153 3,069 5

144,941 1c.0 TOTAL PERIOD 1c COST 182 1,210 122 346 381 21,269 3,730 27,240 22,692 4,548 1,197 65,653 18,059 145,524 PERIOD 1 TOTALS 5,054 3,974 247 651 760 137,492 23,406 171,584 154,048 17,536 3,290 142,809 60,952 909,164 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 94 14 108 108 2a.1.5 Maintenance supplies 608 152 760 760 2a.1 Subtotal Period 2a Activity Costs 702 166 868 868 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 77,826 11,674 89,500 89,500 2a.3.2 Annual Fees 470 71 541 264 276 2a.3 Subtotal Period 2a Collateral Costs 78,296 11,744 90,041 264 89,776 Period 2a Period-Dependent Costs 2a.4.1 Insurance 1,662 166 1,828 1,828 2a.4.2 Property taxes 39 4

43 43 2a.4.3 Health physics supplies 1,502 376 1,878 1,878 2a.4.4 Disposal of DAW generated 18 10 47 15 90 90 888 17,752 29 2a.4.5 Plant energy budget 1,254 188 1,442 1,442 2a.4.6 NRC Fees 1,601 160 1,761 1,761 2a.4.7 Emergency Planning Fees 3,050 305 3,355 3,355 2a.4.8 Indirect Overhead 3,829 574 4,403 3,976 427 2a.4.9 Spent Fuel Pool O&M 4,120 618 4,738 4,738 2a.4.10 ISFSI Operating Costs 266 40 306 306 2a.4.11 Corporate A&G Cost 17,944 2,692 20,636 18,634 2,002 2a.4.12 Environmental Audit 2,822 423 3,245 3,245 2a.4.13 Security Staff Cost 37,964 5,695 43,658 37,328 6,330 595,679 2a.4.14 Utility Staff Cost 22,959 3,444 26,402 23,841 2,561 270,451 2a.4 Subtotal Period 2a Period-Dependent Costs 1,502 18 10 47 97,509 14,699 113,786 94,066 19,720 888 17,752 29 866,130 2a.0 TOTAL PERIOD 2a COST 1,502 18 10 47 176,508 26,610 204,694 95,199 109,496 888 17,752 29 866,130 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 1,033 155 1,188 1,188 2b.1.5 Maintenance supplies 6,702 1,676 8,378 8,378 2b.1 Subtotal Period 2b Activity Costs 7,736 1,831 9,566 9,566 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 5 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 29,791 4,469 34,259 34,259 2b.3.2 Annual Fees 5,184 778 5,961 2,915 3,046 2b.3 Subtotal Period 2b Collateral Costs 34,974 5,246 40,221 2,915 37,305 Period 2b Period-Dependent Costs 2b.4.1 Insurance 18,314 1,831 20,146 20,146 2b.4.2 Property taxes 79 8

87 87 2b.4.3 Health physics supplies 7,820 1,955 9,774 9,774 2b.4.4 Disposal of DAW generated 90 52 238 76 457 457 4,530 90,604 148 2b.4.5 Plant energy budget 6,911 1,037 7,948 7,948 2b.4.6 NRC Fees 17,094 1,709 18,803 18,803 2b.4.7 Indirect Overhead 3,988 598 4,586 2,697 1,890 2b.4.8 ISFSI Operating Costs 2,935 440 3,375 3,375 2b.4.9 Corporate A&G Cost 13,172 1,976 15,147 8,907 6,241 2b.4.10 Security Staff Cost 93,362 14,004 107,366 37,578 69,788 1,790,592 2b.4.11 Utility Staff Cost 63,358 9,504 72,862 42,843 30,019 866,340 2b.4 Subtotal Period 2b Period-Dependent Costs 7,820 90 52 238 219,213 33,139 260,551 149,240 111,312 4,530 90,604 148 2,656,932 2b.0 TOTAL PERIOD 2b COST 7,820 90 52 238 261,923 40,216 310,338 161,721 148,617 4,530 90,604 148 2,656,932 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 78 12 90 90 2c.1.5 Maintenance supplies 508 127 635 635 2c.1 Subtotal Period 2c Activity Costs 587 139 725 725 Period 2c Collateral Costs 2c.3.1 Annual Fees 393 59 452 452 2c.3 Subtotal Period 2c Collateral Costs 393 59 452 452 Period 2c Period-Dependent Costs 2c.4.1 Insurance 824 82 906 906 2c.4.2 Property taxes 6

1 7

7 2c.4.3 Health physics supplies 577 144 722 722 2c.4.4 Disposal of DAW generated 7

4 17 6

33 33 331 6,624 11 2c.4.5 Plant energy budget 524 79 603 603 2c.4.6 NRC Fees 1,210 121 1,331 1,331 2c.4.7 Indirect Overhead 247 37 284 284 2c.4.8 Corporate A&G Cost 903 135 1,038 1,038 2c.4.9 Security Staff Cost 2,676 401 3,077 3,077 52,228 2c.4.10 Utility Staff Cost 3,024 454 3,478 3,478 44,394 2c.4 Subtotal Period 2c Period-Dependent Costs 577 7

4 17 9,413 1,460 11,478 11,478 331 6,624 11 96,622 2c.0 TOTAL PERIOD 2c COST 577 7

4 17 10,393 1,658 12,656 12,656 331 6,624 11 96,622 PERIOD 2 TOTALS 9,899 114 66 302 448,823 68,483 527,689 269,575 258,113 5,749 114,980 188 3,619,683 PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy Period 3a Direct Decommissioning Activities 3a.1.1 Prepare preliminary decommissioning cost 215 32 247 247 1,300 3a.1.2 Review plant dwgs & specs.

761 114 875 875 4,600 3a.1.3 Perform detailed rad survey a

3a.1.4 End product description 165 25 190 190 1,000 3a.1.5 Detailed by-product inventory 215 32 247 247 1,300 3a.1.6 Define major work sequence 1,240 186 1,426 1,426 7,500 3a.1.7 Perform SER and EA 513 77 590 590 3,100 3a.1.8 Prepare/submit Defueled Technical Specifications 1,240 186 1,426 1,426 7,500 3a.1.9 Perform Site-Specific Cost Study 827 124 951 951 5,000 3a.1.10 Prepare/submit Irradiated Fuel Management Plan 165 25 190 190 1,000 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 6 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

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

Manhours Manhours Activity Specifications 3a.1.11.1 Re-activate plant & temporary facilities 1,219 183 1,402 1,262 140 7,370 3a.1.11.2 Plant systems 689 103 792 713 79 4,167 3a.1.11.3 Reactor internals 1,174 176 1,350 1,350 7,100 3a.1.11.4 Reactor vessel 1,075 161 1,236 1,236 6,500 3a.1.11.5 Biological shield 83 12 95 95 500 3a.1.11.6 Steam generators 516 77 593 593 3,120 3a.1.11.7 Reinforced concrete 265 40 304 152 152 1,600 3a.1.11.8 Main Turbine 66 10 76 76 400 3a.1.11.9 Main Condensers 66 10 76 76 400 3a.1.11.10 Plant structures & buildings 516 77 593 297 297 3,120 3a.1.11.11 Waste management 761 114 875 875 4,600 3a.1.11.12 Facility & site closeout 149 22 171 86 86 900 3a.1.11 Total 6,578 987 7,565 6,659 906 39,777 Planning & Site Preparations 3a.1.12 Prepare dismantling sequence 397 60 456 456 2,400 3a.1.13 Plant prep. & temp. svces 4,200 630 4,830 4,830 3a.1.14 Design water clean-up system 232 35 266 266 1,400 3a.1.15 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,900 435 3,335 3,335 3a.1.16 Procure casks/liners & containers 203 31 234 234 1,230 3a.1 Subtotal Period 3a Activity Costs 19,852 2,978 22,830 21,924 906 77,107 Period 3a Additional Costs 3a.2.1 Site Characterization 6,075 1,823 7,898 7,898 32,260 10,796 3a.2 Subtotal Period 3a Additional Costs 6,075 1,823 7,898 7,898 32,260 10,796 Period 3a Collateral Costs 3a.3.1 Annual Fees 97 15 112 112 3a.3 Subtotal Period 3a Collateral Costs 97 15 112 112 Period 3a Period-Dependent Costs 3a.4.1 Insurance 246 25 271 271 3a.4.2 Property taxes 2

0 2

2 3a.4.3 Health physics supplies 856 214 1,071 1,071 3a.4.4 Heavy equipment rental 908 136 1,045 1,045 3a.4.5 Disposal of DAW generated 10 6

27 9

52 52 514 10,287 17 3a.4.6 Plant energy budget 1,565 235 1,800 1,800 3a.4.7 NRC Fees 541 54 595 595 3a.4.8 Indirect Overhead 1,454 218 1,673 1,673 3a.4.9 Corporate A&G Cost 1,619 243 1,862 1,862 3a.4.10 Environmental Audit 704 106 810 810 3a.4.11 Security Staff Cost 1,650 248 1,898 1,898 35,620 3a.4.12 Utility Staff Cost 20,450 3,068 23,518 23,518 257,920 3a.4 Subtotal Period 3a Period-Dependent Costs 1,765 10 6

27 28,232 4,554 34,594 34,594 514 10,287 17 293,540 3a.0 TOTAL PERIOD 3a COST 1,765 10 6

27 54,257 9,369 65,434 64,528 906 514 10,287 32,277 381,443 PERIOD 3b - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 783 117 900 810 90 4,733 3b.1.1.2 Reactor internals 413 62 475 475 2,500 3b.1.1.3 Remaining buildings 223 33 257 64 193 1,350 3b.1.1.4 CRD cooling assembly 165 25 190 190 1,000 3b.1.1.5 CRD housings & ICI tubes 165 25 190 190 1,000 3b.1.1.6 Incore instrumentation 165 25 190 190 1,000 3b.1.1.7 Reactor vessel 600 90 690 690 3,630 3b.1.1.8 Facility closeout 198 30 228 114 114 1,200 3b.1.1.9 Missile shields 74 11 86 86 450 3b.1.1.10 Biological shield 198 30 228 228 1,200 3b.1.1.11 Steam generators 761 114 875 875 4,600 3b.1.1.12 Reinforced concrete 165 25 190 95 95 1,000 3b.1.1.13 Main Turbine 258 39 297 297 1,560 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 7 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 Detailed Work Procedures (continued) 3b.1.1.14 Main Condensers 258 39 297 297 1,560 3b.1.1.15 Auxiliary building 451 68 519 467 52 2,730 3b.1.1.16 Reactor building 451 68 519 467 52 2,730 3b.1.1 Total 5,332 800 6,132 4,943 1,189 32,243 3b.1 Subtotal Period 3b Activity Costs 5,332 800 6,132 4,943 1,189 32,243 Period 3b Additional Costs 3b.2.1 Asbestos Remediation 3,031 6

724 2,035 1,376 7,172 7,172 29,762 386,906 26,129 3b.2 Subtotal Period 3b Additional Costs 3,031 6

724 2,035 1,376 7,172 7,172 29,762 386,906 26,129 Period 3b Collateral Costs 3b.3.1 Decon equipment 1,253 188 1,441 1,441 3b.3.2 DOC staff relocation expenses 1,465 220 1,685 1,685 3b.3.3 Small tool allowance 43 6

49 49 3b.3.4 Pipe cutting equipment 1,500 225 1,725 1,725 3b.3.5 Annual Fees 49 7

56 56 3b.3 Subtotal Period 3b Collateral Costs 1,253 1,543 1,514 646 4,956 4,956 Period 3b Period-Dependent Costs 3b.4.1 Decon supplies 45 11 57 57 3b.4.2 Insurance 209 21 230 230 3b.4.3 Property taxes 1

0 1

1 3b.4.4 Health physics supplies 700 175 875 875 3b.4.5 Heavy equipment rental 458 69 527 527 3b.4.6 Disposal of DAW generated 6

3 15 5

30 30 293 5,866 10 3b.4.7 Plant energy budget 789 118 908 908 3b.4.8 NRC Fees 272 27 300 300 3b.4.9 Indirect Overhead 733 110 843 843 3b.4.10 Corporate A&G Cost 1,134 170 1,304 1,304 3b.4.11 Environmental Audit 355 53 408 408 3b.4.12 Security Staff Cost 832 125 957 957 17,956 3b.4.13 DOC Staff Cost 7,086 1,063 8,149 8,149 58,719 3b.4.14 Utility Staff Cost 10,309 1,546 11,856 11,856 130,020 3b.4 Subtotal Period 3b Period-Dependent Costs 45 1,158 6

3 15 21,722 3,494 26,444 26,444 293 5,866 10 206,695 3b.0 TOTAL PERIOD 3b COST 1,298 5,732 12 727 2,051 28,568 6,316 44,704 43,515 1,189 30,055 392,772 26,139 238,938 PERIOD 3 TOTALS 1,298 7,497 22 733 2,078 82,824 15,686 110,138 108,043 2,095 30,570 403,059 58,416 620,381 PERIOD 4a - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Reactor Coolant Piping 29 114 37 78 165 223 139 784 784 940 995 132,027 2,799 4a.1.1.2 Pressurizer Relief Tank 5

19 9

18 38 52 30 170 170 219 232 30,754 482 4a.1.1.3 Reactor Coolant Pumps & Motors 24 85 87 350 1,012 347 1,905 1,905 7,124 1,117,939 2,545 100 4a.1.1.4 Pressurizer 58 561 229 683 276 1,806 1,806 2,755 333,869 1,346 1,875 4a.1.1.5 Steam Generators 7,916 692 2,687 4,622 3,607 19,524 19,524 18,650 2,552,436 5,585 3,500 4a.1.1.6 Retired Steam Generator Units 650 2,687 4,622 1,624 9,582 9,582 18,650 2,552,436 52 2,250 4a.1.1.7 CRDMs/ICIs/Service Structure Removal 40 319 314 151 209 481 305 1,819 1,819 2,147 3,536 229,377 6,595 4a.1.1.8 Reactor Vessel Internals 51 7,267 14,116 993 15,203 287 16,898 54,816 54,816 2,764 876 393 291,423 23,157 1,085 4a.1.1.9 Vessel & Internals GTCC Disposal 7,033 1,055 8,088 8,088 1,773 345,227 4a.1.1.10 Reactor Vessel 9,194 1,905 1,430 3,184 287 9,365 25,365 25,365 15,250 955,467 23,157 1,085 4a.1.1 Totals 149 24,972 18,370 8,623 412 37,115 575 33,644 123,860 123,860 3,306 69,955 876 393 1,773 8,540,955 65,718 9,894 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 281 151 65 462 164 1,123 1,123 2,926 175,589 5,369 4a.1.3 Main Condensers 900 105 62 628 339 2,034 2,034 5,310 238,934 17,268 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor 382 57 439 439 3,325 4a.1.4.2 Auxiliary Building 138 21 159 159 1,020 4a.1.4 Totals 520 78 598 598 4,345 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 8 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

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

Manhours Manhours Disposal of Plant Systems 4a.1.5.1 1026 Hydrogen Purge & Particulate Mont.

93 6

32 320 77 527 527 2,997 121,711 1,640 4a.1.5.2 1030 Turbine Bldg Structure 112 17 129 129 2,287 4a.1.5.3 1031 Turbine Bldg Plumbing & Drainage 60 2

11 107 33 211 211 997 40,506 1,177 4a.1.5.4 1033 Turbine Bldg Domestic Water 15 2

17 17 347 4a.1.5.5 1034 Turbine Bldg Fire Protection 161 24 185 185 3,620 4a.1.5.6 1035 Turbine Bldg Heating/Chilled Water 38 6

44 44 839 4a.1.5.7 1037 Turbine Bldg Ventilation 94 14 108 108 1,867 4a.1.5.8 1038 Turbine Bldg Decontamination 4a.1.5.9 1040 Intake Stucture 24 4

28 28 495 4a.1.5.10 1042 Intake Structure Screens 68 10 78 78 1,357 4a.1.5.11 1046 Intake Structure Chlorination 28 4

33 33 593 4a.1.5.12 1047 Intake Structure Ventilation 15 2

17 17 298 4a.1.5.13 2011 Reactor Vessel Equipment 37 0

2 18 12 68 68 165 6,714 748 4a.1.5.14 2012 Reactor Instrumentation 159 3

16 162 67 406 406 1,514 61,478 2,696 4a.1.5.15 2013 Reactor Control Rods 180 9

53 536 134 912 912 5,019 203,839 3,488 4a.1.5.16 2022 Pressurizer Systems 294 8

43 435 146 926 926 4,074 165,459 5,940 4a.1.5.17 2031 Intermediate Cooling Water 538 15 85 857 277 1,773 1,773 8,028 326,025 9,833 4a.1.5.18 2032 Decay Heat Removal/Core Flooding 278 14 79 798 202 1,371 1,371 7,471 303,413 5,304 4a.1.5.19 2033 Reactor Bldg Spray 227 10 56 567 151 1,012 1,012 5,312 215,728 4,102 4a.1.5.20 2034 Service/Auxiliary Cooling Water 958 42 237 2,393 638 4,268 4,268 22,407 909,951 18,003 4a.1.5.21 2061 Primary Sampling 65 1

5 47 24 142 142 442 17,939 1,184 4a.1.5.22 2062 Nitrogen/High Purity Hydrogen 107 2

9 93 42 253 253 869 35,290 1,766 4a.1.5.23 2071 Condensate 742 35 199 2,009 520 3,505 3,505 18,811 763,934 14,142 4a.1.5.24 2072 Condensate Demineralizers 73 2

12 118 38 243 243 1,109 45,032 1,409 4a.1.5.25 2073 Feedwater Heaters/Moist Sep. Drains 508 23 129 1,300 344 2,303 2,303 12,170 494,214 9,796 4a.1.5.26 2074 Plant Makeup Water 174 5

28 288 91 587 587 2,692 109,326 2,990 4a.1.5.27 2081 Main Steam 276 16 90 912 221 1,516 1,516 8,543 346,949 5,423 4a.1.5.28 2082 Reheat Steam 359 16 89 901 240 1,606 1,606 8,438 342,672 6,681 4a.1.5.29 2083 Extraction Steam 815 28 159 1,601 470 3,073 3,073 14,991 608,809 15,215 4a.1.5.30 2084 Main Feedwater 261 18 102 1,031 237 1,650 1,650 9,656 392,131 5,083 4a.1.5.31 2085 Auxiliary Feedwater 31 1

7 73 20 133 133 687 27,899 603 4a.1.5.32 2086 Emergency Feedwater 116 4

23 228 67 438 438 2,136 86,740 2,140 4a.1.5.33 3011 Turbine Stator 6

0 2

22 5

36 36 210 8,528 119 4a.1.5.34 3021 Electro-Hydraulic 60 9

69 69 1,210 4a.1.5.35 3022 Gland Steam 123 2

13 132 53 323 323 1,232 50,037 2,152 4a.1.5.36 3023 Lube Oil 32 5

36 36 645 4a.1.5.37 3024 Moisture Separator/Reheaters 229 33 187 1,894 373 2,716 2,716 17,729 720,000 4,584 4a.1.5.38 3025 Turbine Sampling 129 4

21 208 67 428 428 1,945 78,996 2,422 4a.1.5.39 3032 Main Generator Exciter 2

0 2

2 41 4a.1.5.40 3042 Generator Cooling 38 6

44 44 837 4a.1.5.41 3043 Seal Oil 31 5

36 36 661 4a.1.5.42 3052 Condensate Vacuum 42 15 51 294 106 90 600 600 2,756 521 145,025 848 4a.1.5.43 3053 Main Condenser Piping 1

0 2

2 35 4a.1.5.44 3061 Circulating Water 42 6

48 48 839 4a.1.5.45 3062 Circulating Water Vacuum 13 2

15 15 264 4a.1.5.46 3063 Turbine Bldg Plant Additions(86-91) 7 1

8 8

158 4a.1.5.47 5021 Laboratory Equipment 16 2

19 19 330 4a.1.5 Totals 7,681 312 1,739 17,345 106 4,761 31,945 31,026 919 162,402 521 6,628,345 146,211 4a.1.6 Scaffolding in support of decommissioning 669 12 8

63 10 181 943 943 532 47 26,929 15,396 4a.1 Subtotal Period 4a Activity Costs 149 35,023 18,950 10,498 18,911 37,231 575 39,168 160,503 159,585 919 174,477 70,523 876 393 1,773 15,610,750 254,308 9,894 Period 4a Additional Costs 4a.2.1 Remedial Action Surveys 1,377 413 1,790 1,790 28,246 4a.2.2 Retired Reactor Head 194 858 1,777 588 548 3,964 3,964 3,336 406,447 4,828 2,000 4a.2.3 Hot Leg Piping 4

11 36 11 62 62 11,300 191 6

4a.2.4 GTCC SFP Legacy Waste 335 50 385 385 3,900 4a.2 Subtotal Period 4a Additional Costs 194 861 1,788 625 1,712 1,022 6,202 6,202 14,636 410,538 33,080 2,000 Period 4a Collateral Costs 4a.3.1 Process decommissioning water waste 4

7 21 23 12 68 68 65 3,874 13 4a.3.2 Process decommissioning chemical flush waste 4a.3.3 Small tool allowance 258 39 296 267 30 4a.3.4 Annual Fees 132 20 152 152 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 9 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

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

Manhours Manhours 4a.3 Subtotal Period 4a Collateral Costs 4

258 7

21 23 132 70 517 487 30 65 3,874 13 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 122 31 153 153 4a.4.2 Insurance 564 56 620 620 4a.4.3 Property taxes 2

0 3

3 4a.4.4 Health physics supplies 3,850 962 4,812 4,812 4a.4.5 Heavy equipment rental 3,856 578 4,435 4,435 4a.4.6 Disposal of DAW generated 96 56 254 81 487 487 4,825 96,506 157 4a.4.7 Plant energy budget 2,021 303 2,324 2,324 4a.4.8 NRC Fees 927 93 1,020 1,020 4a.4.9 Indirect Overhead 1,031 155 1,186 1,186 4a.4.10 Liquid Radwaste Processing Equipment/Services 705 106 810 810 4a.4.11 Corporate A&G Cost 2,736 410 3,146 3,146 4a.4.12 Environmental Audit 957 144 1,101 1,101 4a.4.13 Security Staff Cost 2,708 406 3,115 3,115 59,357 4a.4.14 DOC Staff Cost 22,587 3,388 25,974 25,974 195,030 4a.4.15 Utility Staff Cost 27,911 4,187 32,098 32,098 353,315 4a.4 Subtotal Period 4a Period-Dependent Costs 122 7,706 96 56 254 62,149 10,901 81,284 81,284 4,825 96,506 157 607,702 4a.0 TOTAL PERIOD 4a COST 275 43,180 19,914 12,363 18,911 38,133 64,568 51,161 248,505 247,557 948 174,477 90,049 876 393 1,773 16,121,670 287,557 619,596 PERIOD 4b - Site Decontamination Period 4b Direct Decommissioning Activities 4b.1.1 Remove spent fuel racks 277 31 105 109 522 304 1,348 1,348 2,561 162,662 705 Disposal of Plant Systems 4b.1.2.1 1010 Site Demolition 3

0 3

3 56 4b.1.2.2 1021 Reactor Bldg Plumbing & Drainage 29 0

2 24 11 68 68 229 9,297 484 4b.1.2.3 1024 Reactor Bldg Fire Protection 44 1

4 37 17 102 102 347 14,098 733 4b.1.2.4 1025 Reactor Bldg Heating & Chilled Watr 44 1

4 40 18 107 107 374 15,208 770 4b.1.2.5 1027 Reactor Bldg Ventilation 101 5

26 264 69 466 466 2,476 100,562 1,871 4b.1.2.6 1028 Reactor Bldg Decontamination 409 9

50 506 187 1,161 1,161 4,741 192,531 8,243 4b.1.2.7 1050 Auxiliary Bldg Structure 4b.1.2.8 1051 Auxiliary Bldg Plumbing/Drainage 4

0 0

2 1

7 7

16 640 66 4b.1.2.9 1053 Auxiliary Bldg Domestic Water 88 1

7 74 34 204 204 690 28,002 1,387 4b.1.2.10 1054 Auxiliary Bldg Fire Protection 436 10 53 536 198 1,234 1,234 5,023 203,968 6,839 4b.1.2.11 1055 Auxiliary Bldg Heating/Chilled Watr 216 7

41 413 123 800 800 3,869 157,111 3,592 4b.1.2.12 1057 Auxiliary Bldg Ventilation 264 20 115 1,161 259 1,820 1,820 10,872 441,498 4,984 4b.1.2.13 1058 Auxiliary Bldg Decontamination 1,302 13 72 726 446 2,558 2,558 6,794 275,905 24,562 4b.1.2.14 1060 Boiler Plant Structure 34 5

39 39 683 4b.1.2.15 1065 Boiler Plant Heating 6

1 7

7 129 4b.1.2.16 1090 Plant Additions (86 - 91) 62 2

12 122 36 234 234 1,144 46,462 1,198 4b.1.2.17 2021 Reactor Coolant 23 4

22 221 43 313 313 2,068 84,000 445 4b.1.2.18 2023 Makeup Purification/Chem Addition 769 27 156 1,573 454 2,980 2,980 14,727 598,068 14,265 4b.1.2.19 2041 Gaseous Radwaste 256 26 62 267 169 158 937 937 2,497 818 154,158 4,441 4b.1.2.20 2042 Clean Liquid Radwaste 579 17 95 962 305 1,958 1,958 9,007 365,791 10,650 4b.1.2.21 2044 Dirty Liquid/Laundry Radwaste 80 9

21 96 53 52 311 311 896 257 53,062 1,401 4b.1.2.22 2051 Reactor Bldg Fuel Handling 12 1

6 66 14 100 100 614 24,941 236 4b.1.2.23 2052 Auxiliary Bldg Fuel Handling 49 4

22 223 49 347 347 2,088 84,793 936 4b.1.2.24 2054 Spent Fuel Cooling 138 3

19 196 67 424 424 1,837 74,603 2,472 4b.1.2.25 2087 Reactor Bldg Plant Additions(86-91) 169 3

19 187 73 451 451 1,751 71,124 2,937 4b.1.2.26 3026 Turbine Drains 155 3

19 192 71 440 440 1,801 73,130 2,624 4b.1.2.27 4021 Station Service Generator Bus/Aux 19 3

22 22 377 4b.1.2.28 4022 Station Start Up Equipment 6

1 7

7 114 4b.1.2.29 4023 Station Unit Auxiliary Equipment 4

1 5

5 80 4b.1.2.30 4024 Station Distribution System 6

1 7

7 118 4b.1.2.31 4025 DC Distribution System 33 5

38 38 679 4b.1.2.32 4041 Electrical Bus Duct 9

1 11 11 186 4b.1.2.33 4042 Electrical Structures, Wiring\\Cont.

914 137 1,051 1,051 18,290 4b.1.2.34 4043 Contaminated Conduit 1,152 13 75 760 415 2,415 2,415 7,115 288,925 19,794 4b.1.2.35 4052 Emergency Generator 33 5

38 38 689 4b.1.2.36 4061 Main Control Room Panels 29 4

34 34 585 4b.1.2.37 4062 Local Panels / Instruments 91 14 105 105 1,948 4b.1.2.38 4063 Plant Computer 4

1 5

5 88 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 10 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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.1.2.39 4064 Radiation Monitoring 63 1

6 59 26 154 154 549 22,287 1,238 4b.1.2.40 4065 Electrical Plant Additions(86-91) 47 1

6 57 21 131 131 529 21,486 907 4b.1.2.41 5011 Instrument Air 181 3

14 144 69 412 412 1,351 54,877 2,919 4b.1.2.42 5012 Service Air 121 1

8 83 44 258 258 778 31,598 1,891 4b.1.2.43 5013 Evacuation Alarm 1

0 2

2 29 4b.1.2.44 5014 Public Address 87 1

5 51 30 175 175 481 19,531 1,583 4b.1.2.45 5015 Security 21 3

24 24 415 4b.1.2.46 5017 Telephone 128 1

8 80 46 264 264 753 30,582 2,236 4b.1.2.47 5025 Health Physics Equipment 67 1

4 44 24 139 139 408 16,550 1,346 4b.1.2.48 5031 Misc. Lab,HP/Shop Furnishings 134 2

14 140 57 347 347 1,310 53,187 2,603 4b.1.2.49 5032 Misc. Test Equipment/Instruments 73 1

7 75 31 188 188 706 28,666 1,441 4b.1.2.50 5033 Misc. Portable Pwr Tool/Misc Equip 52 1

5 49 21 128 128 460 18,688 1,029 4b.1.2.51 5042 Kitchen Equipment 0

0 1

1 10 4b.1.2.52 5043 Laundry Equipment 3

0 0

1 1

5 5

12 507 53 4b.1.2.53 5301 Main Transformers 25 4

29 29 522 4b.1.2.54 Plant Additions(98-02) 23 1

5 48 14 91 91 453 18,393 437 4b.1.2 Totals 8,599 194 985 9,481 223 3,671 23,152 21,727 1,425 88,765 1,075 3,674,229 157,613 4b.1.3 Scaffolding in support of decommissioning 1,003 17 12 94 14 272 1,414 1,414 798 70 40,394 23,094 Decontamination of Site Buildings 4b.1.4.1 Reactor 2,003 2,176 241 2,605 1,717 1,872 2,686 13,300 13,300 16,077 63,180 3,648,158 64,370 4b.1.4.2 Auxiliary Building 754 108 9

97 54 70 445 1,537 1,537 506 2,384 133,466 16,555 4b.1.4.3 Fuel Handling Area 369 419 5

19 146 14 318 1,289 1,289 1,363 160 63,867 14,674 4b.1.4.4 Misc. Site Structures - contaminated 74 26 3

9 91 7

60 270 270 852 35 36,730 1,283 4b.1.4.5 Turbine Building 202 6

1 3

25 2

107 346 346 234 9

10,092 3,935 4b.1.4 Totals 3,401 2,736 258 2,733 2,033 1,965 3,617 16,743 16,743 19,032 65,767 3,892,312 100,816 4b.1.5 Prepare/submit License Termination Plan 677 102 779 779 4,096 4b.1.6 Receive NRC approval of termination plan a

4b.1 Subtotal Period 4b Activity Costs 3,678 12,370 574 3,839 11,608 2,724 677 7,965 43,436 42,010 1,425 108,595 69,473 7,769,597 282,229 4,096 Period 4b Additional Costs 4b.2.1 License Termination Survey Planning 1,503 451 1,954 1,954 6,240 4b.2.2 Operational Tools & Equipment 11 52 385 67 514 514 5,850 146,250 16 4b.2.3 License Termination ISFSI 246 184 1,269 1,921 2,466 1,522 7,609 7,609 12,855 1,641,085 10,687 5,713 4b.2.4 Remedial Action Surveys 2,054 616 2,671 2,671 42,141 4b.2 Subtotal Period 4b Additional Costs 246 195 1,321 385 1,921 6,024 2,656 12,748 12,748 5,850 12,855 1,787,335 52,844 11,953 Period 4b Collateral Costs 4b.3.1 Process decommissioning water waste 10 17 50 54 27 158 158 150 9,001 29 4b.3.2 Process decommissioning chemical flush waste 4b.3.3 Small tool allowance 243 36 280 280 4b.3.4 Decommissioning Equipment Disposition 130 104 710 108 162 1,214 1,214 6,000 529 303,608 147 4b.3.5 Annual Fees 198 30 227 227 4b.3 Subtotal Period 4b Collateral Costs 10 243 147 154 710 162 198 256 1,879 1,879 6,000 679 312,609 176 Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 1,417 354 1,771 1,771 4b.4.2 Insurance 841 84 925 925 4b.4.3 Property taxes 4

0 4

4 4b.4.4 Health physics supplies 4,714 1,179 5,893 5,893 4b.4.5 Heavy equipment rental 5,897 885 6,782 6,782 4b.4.6 Disposal of DAW generated 89 52 235 75 450 450 4,463 89,262 146 4b.4.7 Plant energy budget 2,380 357 2,737 2,737 4b.4.8 NRC Fees 1,383 138 1,522 1,522 4b.4.9 Indirect Overhead 1,085 163 1,248 1,248 4b.4.10 Liquid Radwaste Processing Equipment/Services 1,051 158 1,209 1,209 4b.4.11 Corporate A&G Cost 3,199 480 3,679 3,679 4b.4.12 Environmental Audit 1,428 214 1,642 1,642 4b.4.13 Security Staff Cost 4,041 606 4,647 4,647 88,557 4b.4.14 DOC Staff Cost 21,905 3,286 25,191 25,191 198,198 4b.4.15 Utility Staff Cost 26,633 3,995 30,627 30,627 354,227 4b.4 Subtotal Period 4b Period-Dependent Costs 1,417 10,611 89 52 235 63,951 11,974 88,328 88,328 4,463 89,262 146 640,982 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 11 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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.0 TOTAL PERIOD 4b COST 5,105 23,471 1,004 5,366 12,703 5,042 70,850 22,850 146,390 144,965 1,425 120,445 87,470 9,958,803 335,394 657,031 PERIOD 4e - Delay before License Termination Period 4e Direct Decommissioning Activities Period 4e Collateral Costs 4e.3.1 Annual Fees 82 12 95 95 4e.3 Subtotal Period 4e Collateral Costs 82 12 95 95 Period 4e Period-Dependent Costs 4e.4.1 Insurance 4e.4.2 Property taxes 2

0 3

3 4e.4.3 Health physics supplies 238 59 297 297 4e.4.4 Disposal of DAW generated 3

2 7

2 14 14 137 2,736 4

4e.4.5 Plant energy budget 430 64 494 494 4e.4.6 NRC Fees 496 50 546 546 4e.4.7 Indirect Overhead 159 24 183 183 4e.4.8 Corporate A&G Cost 702 105 807 807 4e.4.9 Environmental Audit 967 145 1,112 1,112 4e.4.10 Security Staff Cost 2

0 3

3 4e.4.11 Utility Staff Cost 1,409 211 1,621 1,621 19,985 4e.4 Subtotal Period 4e Period-Dependent Costs 238 3

2 7

4,168 662 5,080 5,080 137 2,736 4

19,985 4e.0 TOTAL PERIOD 4e COST 238 3

2 7

4,251 674 5,175 5,175 137 2,736 4

19,985 PERIOD 4f - License Termination Period 4f Direct Decommissioning Activities 4f.1.1 ORISE confirmatory survey 176 53 229 229 4f.1.2 Terminate license a

4f.1 Subtotal Period 4f Activity Costs 176 53 229 229 Period 4f Additional Costs 4f.2.1 License Termination Survey 6,449 1,935 8,384 8,384 113,831 3,120 4f.2 Subtotal Period 4f Additional Costs 6,449 1,935 8,384 8,384 113,831 3,120 Period 4f Collateral Costs 4f.3.1 DOC staff relocation expenses 1,465 220 1,685 1,685 4f.3.2 Annual Fees 47 7

54 54 4f.3 Subtotal Period 4f Collateral Costs 1,511 227 1,738 1,738 Period 4f Period-Dependent Costs 4f.4.1 Insurance 4f.4.2 Property taxes 1

0 2

2 4f.4.3 Health physics supplies 1,223 306 1,529 1,529 4f.4.4 Disposal of DAW generated 7

4 18 6

35 35 346 6,917 11 4f.4.5 Plant energy budget 244 37 280 280 4f.4.6 NRC Fees 641 64 705 705 4f.4.7 Indirect Overhead 214 32 246 246 4f.4.8 Corporate A&G Cost 206 31 237 237 4f.4.9 Environmental Audit 548 82 630 630 4f.4.10 Security Staff Cost 589 88 677 677 12,138 4f.4.11 DOC Staff Cost 5,737 861 6,598 6,598 48,148 4f.4.12 Utility Staff Cost 5,327 799 6,126 6,126 58,667 4f.4 Subtotal Period 4f Period-Dependent Costs 1,223 7

4 18 13,507 2,305 17,064 17,064 346 6,917 11 118,953 4f.0 TOTAL PERIOD 4f COST 1,223 7

4 18 21,644 4,520 27,415 27,415 346 6,917 113,843 122,073 PERIOD 4 TOTALS 5,380 68,112 20,928 17,734 31,613 43,200 161,312 79,205 427,485 425,112 2,373 294,922 178,002 876 393 1,773 26,090,130 736,799 1,418,686 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 12 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 2,283 342 2,625 2,625 19,459 5b.1.1.2 Administrative Building 29 4

33 33 319 5b.1.1.3 Auxiliary Building 1,277 192 1,468 1,468 9,936 5b.1.1.4 Circulating Water Tunnels/Pipe 136 20 157 157 2,091 5b.1.1.5 Fuel Handling Area 24 4

27 27 457 5b.1.1.6 Intake 114 17 131 131 1,040 5b.1.1.7 Misc Site Structures -clean 28 4

32 32 213 5b.1.1.8 Site Additions (98-02) 8 1

9 9

120 5b.1.1.9 Turbine Building 1,218 183 1,400 1,400 13,436 5b.1.1.10 Turbine Pedestal 346 52 398 398 2,152 5b.1.1 Totals 5,462 819 6,282 6,282 49,223 Site Closeout Activities 5b.1.2 Grade & landscape site 109 16 125 125 284 5b.1.3 Final report to NRC 258 39 297 297 1,560 5b.1 Subtotal Period 5b Activity Costs 5,571 258 874 6,704 297 6,407 49,507 1,560 Period 5b Additional Costs 5b.2.1 Concrete Crushing 416 7

64 487 487 1,856 5b.2.2 Construction Debris 19 3

22 22 5b.2.3 Demolition and Site Restoration ISFSI 3,610 469 612 4,691 4,691 30,191 80 5b.2 Subtotal Period 5b Additional Costs 4,027 495 678 5,200 5,200 32,047 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 89 13 102 102 5b.3 Subtotal Period 5b Collateral Costs 89 13 102 102 Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property taxes 4

0 4

4 5b.4.3 Heavy equipment rental 8,367 1,255 9,622 9,622 5b.4.4 Plant energy budget 329 49 378 378 5b.4.5 Indirect Overhead 165 25 190 190 5b.4.6 Corporate A&G Cost 509 76 585 585 5b.4.7 Environmental Audit 1,480 222 1,702 1,702 5b.4.8 Security Staff Cost 1,428 214 1,642 1,642 28,957 5b.4.9 DOC Staff Cost 14,481 2,172 16,653 16,653 115,828 5b.4.10 Utility Staff Cost 5,110 766 5,876 5,876 56,821 5b.4 Subtotal Period 5b Period-Dependent Costs 8,367 23,505 4,781 36,652 36,652 201,605 5b.0 TOTAL PERIOD 5b COST 18,053 24,258 6,347 48,658 297 48,361 81,554 203,245 PERIOD 5 TOTALS 18,053 24,258 6,347 48,658 297 48,361 81,554 203,245 TOTAL COST TO DECOMMISSION 11,733 107,535 21,311 19,185 31,613 46,340 854,709 193,126 1,285,554 957,075 275,649 52,830 294,922 217,611 876 393 1,773 26,750,970 937,908 6,771,159 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 13 of 25 Table D-1 Arkansas Nuclear One Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:14:50 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 17.68% CONTINGENCY:

$1,285,554 thousands of 2024 dollars TOTAL NRC LICENSE TERMINATION COST IS 74.45% OR:

$957,075 thousands of 2024 dollars SPENT FUEL MANAGEMENT COST IS 21.44% OR:

$275,649 thousands of 2024 dollars NON-NUCLEAR DEMOLITION COST IS 4.11% OR:

$52,830 thousands of 2024 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

218,880 Cubic Feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

1,773 Cubic Feet TOTAL SCRAP METAL REMOVED:

34,768 Tons TOTAL CRAFT LABOR REQUIREMENTS:

937,908 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, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 14 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 379 114 493 493 1a.1.2 Prepare preliminary decommissioning cost 117 18 135 135 707 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 180 27 207 207 1,088 1a.1.8 Review plant dwgs & specs.

117 18 135 135 707 1a.1.9 Perform detailed rad survey a

1a.1.10 Estimate by-product inventory 90 13 103 103 544 1a.1.11 End product description 90 13 103 103 544 1a.1.12 Detailed by-product inventory 135 20 155 155 816 1a.1.13 Define major work sequence 90 13 103 103 544 1a.1.14 Perform SER and EA 279 42 321 321 1,686 1a.1.15 Perform Site-Specific Cost Study 450 67 517 517 2,720 Activity Specifications 1a.1.16.1 Prepare plant and facilities for SAFSTOR 443 66 509 509 2,676 1a.1.16.2 Plant systems 375 56 431 431 2,267 1a.1.16.3 Plant structures and buildings 281 42 323 323 1,697 1a.1.16.4 Waste management 180 27 207 207 1,088 1a.1.16.5 Facility and site dormancy 180 27 207 207 1,088 1a.1.16 Total 1,458 219 1,677 1,677 8,816 Detailed Work Procedures 1a.1.17.1 Plant systems 106 16 122 122 644 1a.1.17.2 Facility closeout & dormancy 108 16 124 124 653 1a.1.17 Total 214 32 247 247 1,296 1a.1.18 Procure vacuum drying system 9

1 10 10 54 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 3,608 598 4,206 4,206 19,524 Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 9,454 1,418 10,872 10,872 1a.3.2 Annual Fees 187 28 215 215 1a.3 Subtotal Period 1a Collateral Costs 9,641 1,446 11,088 215 10,872 Period 1a Period-Dependent Costs 1a.4.1 Insurance 1,421 142 1,564 1,564 1a.4.2 Property taxes 6

1 7

7 1a.4.3 Health physics supplies 970 242 1,212 1,212 1a.4.4 Heavy equipment rental 908 136 1,045 1,045 1a.4.5 Disposal of DAW generated 12 7

32 10 62 62 616 12,311 20 1a.4.6 Plant energy budget 1,742 261 2,003 2,003 1a.4.7 NRC Fees 773 77 850 850 1a.4.8 Emergency Planning Fees 1,049 105 1,154 1,154 1a.4.9 Indirect Overhead 1,912 287 2,199 2,199 1a.4.10 Spent Fuel Pool O&M 1,029 154 1,183 1,183 1a.4.11 ISFSI Operating Costs 66 10 76 76 1a.4.12 Corporate A&G Cost 15,813 2,372 18,185 18,185 1a.4.13 Environmental Audit 929 139 1,068 1,068 1a.4.14 Security Staff Cost 9,580 1,437 11,017 11,017 150,169 1a.4.15 Utility Staff Cost 34,749 5,212 39,962 39,962 432,640 1a.4 Subtotal Period 1a Period-Dependent Costs 1,878 12 7

32 69,070 10,587 81,587 79,173 2,413 616 12,311 20 582,809 1a.0 TOTAL PERIOD 1a COST 1,878 12 7

32 82,320 12,631 96,881 83,595 13,286 616 12,311 20 602,333 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 15 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 1,131 566 1,697 1,697 21,870 1b.1.1.2 Auxiliary Building 891 446 1,337 1,337 17,924 1b.1.1.3 CA-3 Building 4

2 6

6 76 1b.1.1.4 Fuel Handling Area 416 208 624 624 7,265 1b.1.1.5 Low Level Radwaste Storage 238 119 356 356 4,753 1b.1.1.6 Solid Radwaste Storage Building 32 16 49 49 648 1b.1.1 Totals 2,712 1,356 4,069 4,069 52,537 1b.1 Subtotal Period 1b Activity Costs 2,712 1,356 4,069 4,069 52,537 Period 1b Additional Costs 1b.2.1 Spent Fuel Pool Isolation 10,037 1,505 11,542 11,542 1b.2 Subtotal Period 1b Additional Costs 10,037 1,505 11,542 11,542 Period 1b Collateral Costs 1b.3.1 Decon equipment 1,253 188 1,441 1,441 1b.3.2 Process decommissioning water waste 162 106 306 331 220 1,125 1,125 926 55,571 181 1b.3.3 Process decommissioning chemical flush waste 1b.3.4 Small tool allowance 44 7

51 51 1b.3.5 Spent Fuel Capital and Transfer 4,367 655 5,022 5,022 1b.3.6 Annual Fees 44 7

51 51 1b.3 Subtotal Period 1b Collateral Costs 1,415 44 106 306 331 4,412 1,077 7,690 2,668 5,022 926 55,571 181 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 1,558 390 1,948 1,948 1b.4.2 Insurance 354 35 390 390 1b.4.3 Property taxes 0

0 0

0 1b.4.4 Health physics supplies 712 178 889 889 1b.4.5 Heavy equipment rental 226 34 260 260 1b.4.6 Disposal of DAW generated 14 8

37 12 72 72 712 14,245 23 1b.4.7 Plant energy budget 434 65 499 499 1b.4.8 NRC Fees 158 16 173 173 1b.4.9 Emergency Planning Fees 262 26 288 288 1b.4.10 Indirect Overhead 477 71 548 548 1b.4.11 Spent Fuel Pool O&M 256 38 295 295 1b.4.12 ISFSI Operating Costs 17 2

19 19 1b.4.13 Corporate A&G Cost 3,937 591 4,528 4,528 1b.4.14 Environmental Audit 232 35 266 266 1b.4.15 Security Staff Cost 2,363 354 2,717 2,717 37,077 1b.4.16 Utility Staff Cost 8,552 1,283 9,834 9,834 107,864 1b.4 Subtotal Period 1b Period-Dependent Costs 1,558 938 14 8

37 17,041 3,131 22,729 22,127 602 712 14,245 23 144,941 1b.0 TOTAL PERIOD 1b COST 5,686 982 120 314 369 31,490 7,069 46,030 40,406 5,624 1,638 69,816 52,740 144,941 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 536 80 616 616 3,000 1c.1.2 Install containment pressure equal. lines 41 6

47 47 700 1c.1.3 Interim survey prior to dormancy 733 220 953 953 14,150 1c.1.4 Secure building accesses a

1c.1.5 Prepare & submit interim report 52 8

60 60 317 1c.1 Subtotal Period 1c Activity Costs 577 785 314 1,676 1,676 17,850 317 Period 1c Collateral Costs 1c.3.1 Process decommissioning water waste 187 123 354 384 255 1,302 1,302 1,073 64,354 209 1c.3.2 Process decommissioning chemical flush waste 1c.3.3 Small tool allowance 4

1 4

4 1c.3.4 Spent Fuel Capital and Transfer 4,174 626 4,800 4,800 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 16 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 (continued) 1c.3.5 Annual Fees 44 7

50 50 1c.3 Subtotal Period 1c Collateral Costs 187 4

123 354 384 4,217 888 6,157 1,357 4,800 1,073 64,354 209 Period 1c Period-Dependent Costs 1c.4.1 Insurance 354 35 390 390 1c.4.2 Property taxes 0

0 0

0 1c.4.3 Health physics supplies 403 101 503 503 1c.4.4 Heavy equipment rental 226 34 260 260 1c.4.5 Disposal of DAW generated 3

2 8

3 15 15 153 3,069 5

1c.4.6 Plant energy budget 434 65 499 499 1c.4.7 NRC Fees 158 16 173 173 1c.4.8 Emergency Planning Fees 262 26 288 288 1c.4.9 Indirect Overhead 477 71 548 548 1c.4.10 Spent Fuel Pool O&M 256 38 295 295 1c.4.11 ISFSI Operating Costs 17 2

19 19 1c.4.12 Corporate A&G Cost 3,625 544 4,169 4,169 1c.4.13 Environmental Audit 232 35 266 266 1c.4.14 Security Staff Cost 2,363 354 2,717 2,717 37,077 1c.4.15 Utility Staff Cost 8,541 1,281 9,822 9,822 107,864 1c.4 Subtotal Period 1c Period-Dependent Costs 629 3

2 8

16,719 2,606 19,967 19,365 602 153 3,069 5

144,941 1c.0 TOTAL PERIOD 1c COST 187 1,210 126 356 392 21,721 3,809 27,800 22,398 5,402 1,226 67,423 18,065 145,258 PERIOD 1 TOTALS 5,873 4,070 258 677 793 135,531 23,509 170,710 146,399 24,311 3,480 149,550 70,825 892,532 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 155 23 179 179 2a.1.5 Maintenance supplies 608 152 760 760 2a.1 Subtotal Period 2a Activity Costs 763 175 939 939 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 58,547 8,782 67,329 67,329 2a.3.2 Annual Fees 470 71 541 264 276 2a.3 Subtotal Period 2a Collateral Costs 59,017 8,853 67,870 264 67,606 Period 2a Period-Dependent Costs 2a.4.1 Insurance 1,662 166 1,828 1,828 2a.4.2 Property taxes 7

1 8

8 2a.4.3 Health physics supplies 1,546 386 1,932 1,932 2a.4.4 Disposal of DAW generated 18 11 48 16 93 93 922 18,431 30 2a.4.5 Plant energy budget 1,395 209 1,605 1,605 2a.4.6 NRC Fees 1,466 147 1,612 1,612 2a.4.7 Emergency Planning Fees 3,050 305 3,355 3,355 2a.4.8 Indirect Overhead 3,982 597 4,580 4,136 444 2a.4.9 Spent Fuel Pool O&M 4,120 618 4,738 4,738 2a.4.10 ISFSI Operating Costs 266 40 306 306 2a.4.11 Corporate A&G Cost 16,485 2,473 18,957 17,119 1,839 2a.4.12 Environmental Audit 3,720 558 4,278 4,278 2a.4.13 Security Staff Cost 37,964 5,695 43,658 37,328 6,330 595,679 2a.4.14 Utility Staff Cost 27,683 4,152 31,835 28,747 3,088 329,090 2a.4 Subtotal Period 2a Period-Dependent Costs 1,546 18 11 48 101,800 15,363 118,785 98,685 20,101 922 18,431 30 924,769 2a.0 TOTAL PERIOD 2a COST 1,546 18 11 48 161,580 24,391 187,594 99,888 87,706 922 18,431 30 924,769 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

TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 17 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 Direct Decommissioning Activities (continued) 2b.1.4 Bituminous roof replacement 1,550 232 1,782 1,782 2b.1.5 Maintenance supplies 6,071 1,518 7,588 7,588 2b.1 Subtotal Period 2b Activity Costs 7,620 1,750 9,371 9,371 Period 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 23,651 3,548 27,198 27,198 2b.3.2 Annual Fees 4,695 704 5,399 2,640 2,759 2b.3 Subtotal Period 2b Collateral Costs 28,346 4,252 32,598 2,640 29,958 Period 2b Period-Dependent Costs 2b.4.1 Insurance 16,588 1,659 18,247 18,247 2b.4.2 Property taxes 72 7

79 79 2b.4.3 Health physics supplies 7,117 1,779 8,896 8,896 2b.4.4 Disposal of DAW generated 82 48 217 70 417 417 4,130 82,608 135 2b.4.5 Plant energy budget 6,965 1,045 8,010 8,010 2b.4.6 NRC Fees 14,380 1,438 15,818 15,818 2b.4.7 Indirect Overhead 3,735 560 4,296 2,526 1,770 2b.4.8 ISFSI Operating Costs 2,658 399 3,057 3,057 2b.4.9 Corporate A&G Cost 12,041 1,806 13,847 8,142 5,705 2b.4.10 Security Staff Cost 84,561 12,684 97,245 34,036 63,209 1,621,800 2b.4.11 Utility Staff Cost 61,232 9,185 70,417 41,405 29,012 831,715 2b.4 Subtotal Period 2b Period-Dependent Costs 7,117 82 48 217 202,232 30,632 240,328 137,575 102,753 4,130 82,608 135 2,453,515 2b.0 TOTAL PERIOD 2b COST 7,117 82 48 217 238,199 36,634 282,296 149,586 132,710 4,130 82,608 135 2,453,515 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 182 27 210 210 2c.1.5 Maintenance supplies 715 179 893 893 2c.1 Subtotal Period 2c Activity Costs 897 206 1,103 1,103 Period 2c Collateral Costs 2c.3.1 Annual Fees 553 83 636 636 2c.3 Subtotal Period 2c Collateral Costs 553 83 636 636 Period 2c Period-Dependent Costs 2c.4.1 Insurance 1,158 116 1,274 1,274 2c.4.2 Property taxes 8

1 9

9 2c.4.3 Health physics supplies 807 202 1,008 1,008 2c.4.4 Disposal of DAW generated 9

5 24 8

47 47 462 9,235 15 2c.4.5 Plant energy budget 820 123 943 943 2c.4.6 NRC Fees 1,627 163 1,790 1,790 2c.4.7 Indirect Overhead 329 49 379 379 2c.4.8 Corporate A&G Cost 999 150 1,149 1,149 2c.4.9 Security Staff Cost 3,762 564 4,326 4,326 73,427 2c.4.10 Utility Staff Cost 3,718 558 4,276 4,276 55,700 2c.4 Subtotal Period 2c Period-Dependent Costs 807 9

5 24 12,421 1,933 15,199 15,199 462 9,235 15 129,127 2c.0 TOTAL PERIOD 2c COST 807 9

5 24 13,871 2,222 16,938 16,938 462 9,235 15 129,127 PERIOD 2 TOTALS 9,469 109 64 290 413,650 63,246 486,828 266,412 220,417 5,514 110,274 180 3,507,411 PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy Period 3a Direct Decommissioning Activities 3a.1.1 Prepare preliminary decommissioning cost 117 18 135 135 707 3a.1.2 Review plant dwgs & specs.

414 62 476 476 2,502 3a.1.3 Perform detailed rad survey a

3a.1.4 End product description 90 13 103 103 544 3a.1.5 Detailed by-product inventory 117 18 135 135 707 3a.1.6 Define major work sequence 675 101 776 776 4,080 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 18 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 Direct Decommissioning Activities (continued) 3a.1.7 Perform SER and EA 279 42 321 321 1,686 3a.1.8 Prepare/submit Defueled Technical Specifications 675 101 776 776 4,080 3a.1.9 Perform Site-Specific Cost Study 450 67 517 517 2,720 3a.1.10 Prepare/submit Irradiated Fuel Management Plan 90 13 103 103 544 Activity Specifications 3a.1.11.1 Re-activate plant & temporary facilities 663 99 763 686 76 4,009 3a.1.11.2 Plant systems 375 56 431 388 43 2,267 3a.1.11.3 Reactor internals 639 96 735 735 3,862 3a.1.11.4 Reactor vessel 585 88 673 673 3,536 3a.1.11.5 Biological shield 45 7

52 52 272 3a.1.11.6 Steam generators 281 42 323 323 1,697 3a.1.11.7 Reinforced concrete 144 22 166 83 83 870 3a.1.11.8 Main Turbine 36 5

41 41 218 3a.1.11.9 Main Condensers 36 5

41 41 218 3a.1.11.10 Plant structures & buildings 281 42 323 161 161 1,697 3a.1.11.11 Waste management 414 62 476 476 2,502 3a.1.11.12 Facility & site closeout 81 12 93 47 47 490 3a.1.11 Total 3,579 537 4,115 3,623 493 21,639 Planning & Site Preparations 3a.1.12 Prepare dismantling sequence 216 32 248 248 1,306 3a.1.13 Plant prep. & temp. svces 4,200 630 4,830 4,830 3a.1.14 Design water clean-up system 126 19 145 145 762 3a.1.15 Rigging/Cont. Cntrl Envlps/tooling/etc.

2,900 435 3,335 3,335 3a.1.16 Procure casks/liners & containers 111 17 127 127 669 3a.1 Subtotal Period 3a Activity Costs 14,037 2,106 16,143 15,650 493 41,946 Period 3a Additional Costs 3a.2.1 Site Characterization 3,307 992 4,299 4,299 17,559 5,876 3a.2 Subtotal Period 3a Additional Costs 3,307 992 4,299 4,299 17,559 5,876 Period 3a Collateral Costs 3a.3.1 Annual Fees 109 16 125 125 3a.3 Subtotal Period 3a Collateral Costs 109 16 125 125 Period 3a Period-Dependent Costs 3a.4.1 Insurance 246 25 271 271 3a.4.2 Property taxes 2

0 2

2 3a.4.3 Health physics supplies 806 202 1,008 1,008 3a.4.4 Heavy equipment rental 908 136 1,045 1,045 3a.4.5 Disposal of DAW generated 10 6

25 8

48 48 481 9,613 16 3a.4.6 Plant energy budget 1,742 261 2,003 2,003 3a.4.7 NRC Fees 436 44 480 480 3a.4.8 Indirect Overhead 1,302 195 1,497 1,497 3a.4.9 Corporate A&G Cost 1,504 226 1,730 1,730 3a.4.10 Environmental Audit 929 139 1,068 1,068 3a.4.11 Security Staff Cost 1,650 248 1,898 1,898 35,620 3a.4.12 Utility Staff Cost 14,883 2,233 17,116 17,116 199,680 3a.4 Subtotal Period 3a Period-Dependent Costs 1,715 10 6

25 22,695 3,716 28,165 28,165 481 9,613 16 235,300 3a.0 TOTAL PERIOD 3a COST 1,715 10 6

25 40,147 6,830 48,732 48,239 493 481 9,613 17,574 283,122 PERIOD 3b - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 426 64 490 441 49 2,575 3b.1.1.2 Reactor internals 225 34 259 259 1,360 3b.1.1.3 Remaining buildings 121 18 140 35 105 734 3b.1.1.4 CRD cooling assembly 90 13 103 103 544 3b.1.1.5 CRD housings & ICI tubes 90 13 103 103 544 3b.1.1.6 Incore instrumentation 90 13 103 103 544 3b.1.1.7 Reactor vessel 327 49 376 376 1,975 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 19 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 Detailed Work Procedures (continued) 3b.1.1.8 Facility closeout 108 16 124 62 62 653 3b.1.1.9 Missile shields 40 6

47 47 245 3b.1.1.10 Biological shield 108 16 124 124 653 3b.1.1.11 Steam generators 414 62 476 476 2,502 3b.1.1.12 Reinforced concrete 90 13 103 52 52 544 3b.1.1.13 Main Turbine 140 21 161 161 849 3b.1.1.14 Main Condensers 140 21 161 161 849 3b.1.1.15 Auxiliary building 246 37 282 254 28 1,485 3b.1.1.16 Reactor building 246 37 282 254 28 1,485 3b.1.1 Total 2,901 435 3,336 2,689 647 17,540 3b.1 Subtotal Period 3b Activity Costs 2,901 435 3,336 2,689 647 17,540 Period 3b Collateral Costs 3b.3.1 Decon equipment 1,253 188 1,441 1,441 3b.3.2 DOC staff relocation expenses 1,465 220 1,685 1,685 3b.3.3 Pipe cutting equipment 1,500 225 1,725 1,725 3b.3.4 Annual Fees 53 8

61 61 3b.3 Subtotal Period 3b Collateral Costs 1,253 1,500 1,518 641 4,912 4,912 Period 3b Period-Dependent Costs 3b.4.1 Decon supplies 45 11 57 57 3b.4.2 Insurance 209 21 230 230 3b.4.3 Property taxes 1

0 1

1 3b.4.4 Health physics supplies 434 108 542 542 3b.4.5 Heavy equipment rental 458 69 527 527 3b.4.6 Disposal of DAW generated 5

3 14 5

27 27 267 5,344 9

3b.4.7 Plant energy budget 878 132 1,010 1,010 3b.4.8 NRC Fees 220 22 242 242 3b.4.9 Indirect Overhead 656 98 755 755 3b.4.10 Corporate A&G Cost 975 146 1,121 1,121 3b.4.11 Environmental Audit 468 70 538 538 3b.4.12 Security Staff Cost 832 125 957 957 17,956 3b.4.13 DOC Staff Cost 4,969 745 5,715 5,715 42,990 3b.4.14 Utility Staff Cost 7,503 1,125 8,628 8,628 100,661 3b.4 Subtotal Period 3b Period-Dependent Costs 45 892 5

3 14 16,712 2,678 20,350 20,350 267 5,344 9

161,608 3b.0 TOTAL PERIOD 3b COST 1,298 2,392 5

3 14 21,131 3,754 28,597 27,951 647 267 5,344 9

179,148 PERIOD 3 TOTALS 1,298 4,106 15 9

39 61,278 10,584 77,329 76,190 1,140 748 14,956 17,583 462,270 PERIOD 4a - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Reactor Coolant Piping 23 110 28 59 125 169 112 626 626 713 755 100,197 2,443 4a.1.1.2 Pressurizer Quench Tank 2

7 3

7 14 19 11 61 61 79 83 11,058 173 4a.1.1.3 Reactor Coolant Pumps & Motors 24 85 87 350 1,012 347 1,905 1,905 7,124 1,117,939 2,545 100 4a.1.1.4 Pressurizer 58 555 188 592 246 1,639 1,639 2,388 193,729 1,346 1,875 4a.1.1.5 Steam Generators 7,916 3,034 2,789 2,662 3,870 4,067 24,338 24,338 33,353 15,614 2,861,244 10,317 3,500 4a.1.1.6 Retired Steam Generator Units 3,034 2,789 2,662 3,870 2,088 14,443 14,443 33,353 15,614 2,861,244 5,463 2,250 4a.1.1.7 CRDMs/ICIs/Service Structure Removal 41 320 340 166 209 543 326 1,945 1,945 2,147 3,372 248,777 6,637 4a.1.1.8 Reactor Vessel Internals 39 7,342 14,097 777 11,492 298 15,035 49,080 49,080 1,906 626 337 212,600 24,107 1,123 4a.1.1.9 Vessel & Internals GTCC Disposal 7,778 1,167 8,945 8,945 1,773 353,913 4a.1.1.10 Reactor Vessel 9,074 2,075 1,859 4,139 298 9,903 27,348 27,348 19,824 1,239,243 24,107 1,123 4a.1.1 Totals 128 24,912 23,253 8,984 5,671 33,483 595 33,303 130,330 130,330 69,646 66,680 626 337 1,773 9,199,944 77,138 9,970 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 319 172 74 525 187 1,277 1,277 3,327 199,647 6,105 4a.1.3 Main Condensers 1,618 130 77 777 545 3,147 3,147 6,561 295,257 31,055 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor 425 64 489 489 3,619 4a.1.4.2 Auxiliary Building 181 27 208 208 1,323 4a.1.4 Totals 606 91 697 697 4,942 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 20 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

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

Manhours Manhours Disposal of Plant Systems 4a.1.5.1 1010 Site Improvements 312 47 359 359 6,281 4a.1.5.2 1026 Hydrogen Purge/Particulate Monitor 83 8

44 449 96 681 681 4,208 170,904 1,393 4a.1.5.3 1030 Turbine Bldg Structure 290 43 333 333 5,947 4a.1.5.4 1031 Turbine Bldg Plumbing/Drainage 47 2

11 111 30 202 202 1,039 42,211 934 4a.1.5.5 1033 Turbine Bldg Domestic Water 11 2

12 12 242 4a.1.5.6 1034 Turbine Bldg Fire Protection 284 43 327 327 6,312 4a.1.5.7 1035 Turbine Bldg Heating/Chilled Water 101 15 117 117 2,229 4a.1.5.8 1037 Turbine Bldg Ventilation 258 39 296 296 5,105 4a.1.5.9 1038 Turbine Bldg Decontamination 2

0 0

1 1

4 4

13 548 31 4a.1.5.10 1039 Turbine Bldg Maintenance Facility 11 2

13 13 222 4a.1.5.11 1040 Intake Structure 7

1 8

8 136 4a.1.5.12 1042 Intake Structure Screens 17 3

20 20 345 4a.1.5.13 1046 Intake Structure Chlorination 16 2

18 18 327 4a.1.5.14 1047 Intake Structure Ventilation 5

1 6

6 107 4a.1.5.15 1081 Yard Structures 5

1 5

5 94 4a.1.5.16 1089 Other Facilites 2

0 3

3 45 4a.1.5.17 1091 Start-UP Boiler(92-97) 73 11 84 84 1,544 4a.1.5.18 1093 Central Support Bldg (92-97) 30 5

35 35 598 4a.1.5.19 2011 Reactor Vessel Equipment 24 1

6 62 16 110 110 584 23,708 476 4a.1.5.20 2012 Reactor Instrumentation 25 1

8 82 20 137 137 770 31,253 488 4a.1.5.21 2013 Reactor Control Rods 32 7

32 271 23 60 424 424 2,539 112 110,252 607 4a.1.5.22 2022 Pressurizer 163 11 60 606 142 982 982 5,676 230,488 3,145 4a.1.5.23 2031 Component Cooling Water 350 10 58 584 185 1,188 1,188 5,471 222,192 6,093 4a.1.5.24 2032 Safety Injection 365 26 144 1,456 334 2,326 2,326 13,636 553,775 6,569 4a.1.5.25 2033 Containment Spray 257 11 59 594 163 1,083 1,083 5,561 225,832 4,350 4a.1.5.26 2042 Boron Management 389 34 103 701 159 261 1,647 1,647 6,560 768 316,087 6,997 4a.1.5.27 2043 Boric Acid Concentrator 106 3

18 177 56 360 360 1,661 67,459 1,815 4a.1.5.28 2061 Primary Sampling 81 1

7 69 32 189 189 644 26,157 1,483 4a.1.5.29 2062 Nitrogen/High Purity Hydrogen 79 1

6 62 30 178 178 584 23,706 1,157 4a.1.5.30 2063 Start-Up Boiler 106 16 122 122 2,209 4a.1.5.31 2071 Condensate 1,468 76 423 4,268 1,078 7,314 7,314 39,964 1,622,965 27,271 4a.1.5.32 2073 Feedwater Htrs/Moisture Sep Drains 134 6

35 349 92 616 616 3,271 132,832 2,467 4a.1.5.33 2074 Plant Makeup Water 646 16 91 917 314 1,984 1,984 8,583 348,546 11,100 4a.1.5.34 2081 Main Steam 422 34 191 1,926 427 3,000 3,000 18,033 732,348 8,029 4a.1.5.35 2082 Reheat Steam 291 21 119 1,199 273 1,903 1,903 11,228 455,964 5,194 4a.1.5.36 2083 Extraction Steam 700 29 158 1,600 441 2,928 2,928 14,976 608,184 12,576 4a.1.5.37 2084 Main Feedwater 606 41 225 2,275 531 3,677 3,677 21,298 864,940 11,385 4a.1.5.38 2086 Emergency Feedwater 118 3

19 195 62 397 397 1,823 74,016 2,073 4a.1.5.39 3011 Turbine Stator 11 1

4 38 9

64 64 360 14,634 224 4a.1.5.40 3021 Electro-Hydraulic 83 12 95 95 1,807 4a.1.5.41 3022 Gland Steam 94 3

15 147 48 306 306 1,379 56,005 1,594 4a.1.5.42 3023 Lube Oil 148 22 170 170 3,043 4a.1.5.43 3024 Moisture Separator/Reheaters 94 17 95 959 183 1,349 1,349 8,983 364,815 1,861 4a.1.5.44 3025 Turbine Sampling 73 2

13 130 40 258 258 1,214 49,298 1,411 4a.1.5.45 3032 Main Generator Exciter 25 4

29 29 502 4a.1.5.46 3042 Generator Cooling 91 14 104 104 1,908 4a.1.5.47 3043 Seal Oil 48 7

56 56 997 4a.1.5.48 3052 Condensate Vacuum 26 6

31 316 59 438 438 2,957 120,103 522 4a.1.5.49 3053 Main Condenser Pumps 25 4

28 28 500 4a.1.5.50 3054 Condenser Tube Cleaning 26 4

30 30 560 4a.1.5.51 3061 Circulating Water 150 23 173 173 3,136 4a.1.5.52 3071 Cooling Tower Structure 52 8

60 60 1,112 4a.1.5.53 3072 Cooling Tower Pumphouse Structure 2

0 2

2 39 4a.1.5.54 3073 Cooling Tower Chemical Traetment 13 2

15 15 258 4a.1.5.55 3074 Plant Additions (86-91) 19 3

22 22 399 4a.1.5.56 5021 Laboratory Equipment 9

1 11 11 188 4a.1.5.57 5026 Service Equipment 1

0 1

1 18 4a.1.5 Totals 8,906 374 1,973 19,547 182 5,316 36,299 33,745 2,553 183,017 880 7,489,220 167,450 4a.1.6 Scaffolding in support of decommissioning 724 12 9

68 10 196 1,020 1,020 572 50 28,969 16,678 4a.1 Subtotal Period 4a Activity Costs 128 37,086 23,942 11,116 26,588 33,676 595 39,638 172,770 170,216 2,553 263,124 67,611 626 337 1,773 17,213,040 303,369 9,970 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 21 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 Additional Costs 4a.2.1 Remedial Action Surveys 1,399 420 1,819 1,819 28,701 4a.2.2 GTCC SFP Legacy Waste 652 98 750 750 7,600 4a.2 Subtotal Period 4a Additional Costs 2,051 518 2,569 2,569 7,600 28,701 Period 4a Collateral Costs 4a.3.1 Process decommissioning water waste 5

8 22 24 13 72 72 68 4,071 13 4a.3.2 Process decommissioning chemical flush waste 4a.3.3 Small tool allowance 289 43 332 299 33 4a.3.4 Annual Fees 135 20 155 155 4a.3 Subtotal Period 4a Collateral Costs 5

289 8

22 24 135 76 559 525 33 68 4,071 13 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 124 31 155 155 4a.4.2 Insurance 573 57 630 630 4a.4.3 Property taxes 2

0 3

3 4a.4.4 Health physics supplies 4,269 1,067 5,336 5,336 4a.4.5 Heavy equipment rental 3,918 588 4,506 4,506 4a.4.6 Disposal of DAW generated 101 59 269 86 516 516 5,114 102,271 167 4a.4.7 Plant energy budget 2,285 343 2,628 2,628 4a.4.8 NRC Fees 718 72 790 790 4a.4.9 Indirect Overhead 1,048 157 1,205 1,205 4a.4.10 Liquid Radwaste Processing Equipment/Services 716 107 823 823 4a.4.11 Corporate A&G Cost 2,756 413 3,169 3,169 4a.4.12 Environmental Audit 1,282 192 1,475 1,475 4a.4.13 Security Staff Cost 2,752 413 3,165 3,165 60,314 4a.4.14 DOC Staff Cost 22,951 3,443 26,393 26,393 198,176 4a.4.15 Utility Staff Cost 28,362 4,254 32,616 32,616 359,014 4a.4 Subtotal Period 4a Period-Dependent Costs 124 8,187 101 59 269 63,445 11,224 83,410 83,410 5,114 102,271 167 617,504 4a.0 TOTAL PERIOD 4a COST 257 45,562 24,051 11,198 26,588 33,969 66,225 51,456 259,307 256,721 2,587 263,124 72,792 626 337 1,773 17,326,980 332,250 627,474 PERIOD 4b - Site Decontamination Period 4b Direct Decommissioning Activities 4b.1.1 Remove spent fuel racks 283 32 107 111 533 310 1,375 1,375 2,613 166,023 720 Disposal of Plant Systems 4b.1.2.1 1011 Site Drainage/ Storm Sewer 2

0 2

2 39 4b.1.2.2 1012 Site Sanitary Sewer 11 2

13 13 220 4b.1.2.3 1013 Site Raw Water 46 7

53 53 917 4b.1.2.4 1014 Site Fire Protection 216 32 249 249 4,801 4b.1.2.5 1016 Site Fuel Oil 85 13 98 98 1,654 4b.1.2.6 1021 Reactor Bldg Plumbing/Drainage 32 1

6 60 18 117 117 561 22,773 506 4b.1.2.7 1024 Reactor Bldg Fire Protection 53 1

7 68 24 153 153 636 25,832 862 4b.1.2.8 1025 Reactor Bldg Heating/Chilled Water 58 1

7 68 26 160 160 637 25,887 942 4b.1.2.9 1027 Reactor Bldg Ventilation 106 7

40 407 94 655 655 3,813 154,855 1,950 4b.1.2.10 1028 Reactor Bldg Decontamination 266 5

28 287 114 701 701 2,687 109,137 4,886 4b.1.2.11 1050 Auxiliary Bldg Structure 471 71 541 541 9,658 4b.1.2.12 1051 Auxiliary Bldg Plumbing/Drainage 7

0 1

5 3

15 15 48 1,959 122 4b.1.2.13 1053 Auxiliary Bldg Domestic Water 77 1

8 78 32 196 196 729 29,600 1,260 4b.1.2.14 1054 Auxiliary Bldg Fire Protection 459 9

51 511 200 1,230 1,230 4,785 194,309 7,142 4b.1.2.15 1055 Auxiliary Bldg Heating/Chilled Watr 507 18 102 1,033 299 1,959 1,959 9,668 392,623 8,875 4b.1.2.16 1057 Auxiliary Bldg Ventilation 344 31 173 1,748 377 2,673 2,673 16,362 664,464 6,438 4b.1.2.17 1058 Auxiliary Bldg Decontamination 751 11 58 588 286 1,694 1,694 5,508 223,684 13,750 4b.1.2.18 1060 Boiler Plant Structure 3

0 3

3 61 4b.1.2.19 1065 Boiler Plant Heating 54 8

62 62 1,114 4b.1.2.20 1070 Administrative Bldg 56 8

65 65 1,145 4b.1.2.21 1090 Plant Additions (86-91) 78 12 90 90 1,646 4b.1.2.22 1092 Station Black-Out Boiler(92-97) 90 13 103 103 1,804 4b.1.2.23 1094 Control Room Extension (92-97) 95 14 109 109 1,952 4b.1.2.24 1095 Hazardous WasteStorage Bldg(92-97) 6 1

7 7

117 4b.1.2.25 2021 Reactor Coolant 35 2

9 90 24 159 159 842 34,193 681 4b.1.2.26 2023 Chemical/Volume Control 656 25 136 1,373 393 2,583 2,583 12,859 522,217 11,779 4b.1.2.27 2034 Service/Auxiliary Cooling Water 2,172 163 903 9,121 2,063 14,423 14,423 85,396 3,467,988 40,796 4b.1.2.28 2041 Gaseous Radwaste 110 17 38 199 89 87 540 540 1,859 427 103,261 1,797 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 22 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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.1.2.29 2044 Liquid Radwaste 152 15 37 195 84 95 578 578 1,826 403 100,302 2,605 4b.1.2.30 2045 Liquid Radwaste Concentrator 74 10 19 43 71 47 264 264 400 342 38,374 1,197 4b.1.2.31 2045 Liquid Radwaste Electrical 9

2 11 110 21 153 153 1,034 42,000 171 4b.1.2.32 2046 Solid Radwaste 85 13 42 292 60 88 579 579 2,738 292 129,948 1,505 4b.1.2.33 2051 Reactor Bldg Fuel Handling 14 1

5 49 12 80 80 457 18,563 269 4b.1.2.34 2052 Auxiliary Bldg Fuel Handling 7

1 3

33 7

52 52 309 12,553 145 4b.1.2.35 2054 Fuel Pool Cooling 136 9

49 495 117 806 806 4,634 188,182 2,355 4b.1.2.36 2064 Regenerative Waste 328 34 97 493 230 231 1,412 1,412 4,612 1,119 258,830 5,702 4b.1.2.37 2065 Regenerative Waste Evaporator 56 10 36 264 49 72 487 487 2,469 237 115,446 1,009 4b.1.2.38 2072 Startup/Blowdown Demineralizer 228 34 262 262 4,868 4b.1.2.39 2087 Reactor Bldg Additions (86-91) 45 3

15 151 37 251 251 1,416 57,517 853 4b.1.2.40 3026 Turbine Drains 59 1

6 62 25 154 154 585 23,756 886 4b.1.2.41 4011 Station Switchgear 119 18 137 137 2,339 4b.1.2.42 4021 Station Service Generator Bus/Aux 14 2

16 16 282 4b.1.2.43 4022 Station Startup Equipment 13 2

15 15 260 4b.1.2.44 4023 StationUnit Auxiliary Equipment 13 2

15 15 259 4b.1.2.45 4024 Station Distribution System 8

1 9

9 154 4b.1.2.46 4025 DC Distribution System 46 7

53 53 948 4b.1.2.47 4041 Electrical Bus Duct 6

1 7

7 125 4b.1.2.48 4042 Elect Structures/Wiring/Contners 1,122 168 1,291 1,291 22,469 4b.1.2.49 4043 Contaminated Conduit 1,706 26 150 1,513 678 4,073 4,073 14,167 575,341 31,434 4b.1.2.50 4051 Emergency Diesel Engines 40 6

46 46 824 4b.1.2.51 4061 Main Control Room Panels 33 5

38 38 666 4b.1.2.52 4062 Local Panels/Instruments 125 19 144 144 2,721 4b.1.2.53 4063 Plant Computer 11 2

13 13 225 4b.1.2.54 4064 Radiation Monitoring 80 2

11 110 38 241 241 1,030 41,823 1,544 4b.1.2.55 4065 Plant Additions (86-91) 10 1

11 11 197 4b.1.2.56 4065 Plant Additions (86-91)Contaminated 18 0

2 19 8

46 46 174 7,049 345 4b.1.2.57 5011 Instrument Air 183 3

15 156 72 429 429 1,457 59,182 2,978 4b.1.2.58 5012 Service Air 166 2

13 129 63 373 373 1,210 49,153 2,691 4b.1.2.59 5014 Public Address 51 8

59 59 1,024 4b.1.2.60 5016 Site Environment Monitoring 24 4

28 28 467 4b.1.2.61 5017 Telephone 69 10 80 80 1,389 4b.1.2.62 5031 Lab/Health Physics/Shop Equipment 55 8

63 63 1,110 4b.1.2.63 5042 Kitchen Equipment 0

0 1

1 9

4b.1.2.64 5051 Machine Shop Equipment 1

0 1

1 18 4b.1.2.65 5301 Main Transformers 12 2

13 13 225 4b.1.2.66 Plant Additions(98-02) 70 1

8 82 31 193 193 765 31,078 1,314 4b.1.2 Totals 12,035 427 2,085 19,831 583 6,163 41,124 37,426 3,697 185,675 2,819 7,721,879 224,492 4b.1.3 Scaffolding in support of decommissioning 1,087 19 13 102 15 295 1,530 1,530 859 76 43,454 25,017 Decontamination of Site Buildings 4b.1.4.1 Reactor 2,445 2,809 317 3,468 2,075 2,492 3,411 17,017 17,017 19,428 84,576 4,797,339 80,311 4b.1.4.2 Administrative Building 21 75 952 683 326 2,056 2,056 24,492 1,156,952 244 4b.1.4.3 Auxiliary Building 814 84 6

55 89 39 460 1,549 1,549 837 1,212 91,765 17,443 4b.1.4.4 CA-3 Building 3

2 5

5 68 4b.1.4.5 Fuel Handling Area 373 417 5

17 147 13 319 1,291 1,291 1,374 111 62,022 14,737 4b.1.4.6 Low Level Radwaste Storage 215 12 1

2 24 2

115 369 369 221 8

9,497 4,413 4b.1.4.7 Solid Radwaste Storage Building 30 4

0 2

3 1

17 57 57 32 37 3,060 642 4b.1.4 Totals 3,880 3,347 403 4,495 2,338 3,230 4,650 22,344 22,344 21,891 110,437 6,120,634 117,857 4b.1.5 Prepare/submit License Termination Plan 369 55 424 424 2,228 4b.1.6 Receive NRC approval of termination plan a

4b.1 Subtotal Period 4b Activity Costs 4,163 16,500 956 6,705 22,271 4,361 369 11,472 66,797 63,099 3,697 208,425 115,946 14,051,990 368,086 2,228 Period 4b Additional Costs 4b.2.1 License Termination Survey Planning 1,503 451 1,954 1,954 6,240 4b.2.2 Operational Tools & Equipment 11 52 385 67 514 514 5,850 146,250 16 4b.2.3 Excavation of Underground Services 1,184 403 356 1,943 1,943 10,264 4b.2.4 License Termination ISFSI 246 184 1,269 1,921 2,466 1,522 7,609 7,609 12,855 1,641,085 10,687 5,713 4b.2.5 Remedial Action Surveys 2,046 614 2,660 2,660 41,970 4b.2.6 Cooling Tower Remediation 7,306 973 1,242 9,522 9,522 105,927 4b.2.7 Chemical Waste Pond Closure 493 67 84 644 644 2,233 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 23 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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.2 Subtotal Period 4b Additional Costs 9,230 195 1,321 385 1,921 7,459 4,336 24,846 24,846 5,850 12,855 1,787,335 171,097 11,953 Period 4b Collateral Costs 4b.3.1 Process decommissioning water waste 11 19 54 58 30 172 172 164 9,811 32 4b.3.2 Process decommissioning chemical flush waste 4b.3.3 Small tool allowance 416 62 479 479 4b.3.4 Decommissioning Equipment Disposition 130 104 710 108 162 1,214 1,214 6,000 529 303,608 147 4b.3.5 Annual Fees 197 30 226 226 4b.3 Subtotal Period 4b Collateral Costs 11 416 149 158 710 166 197 284 2,091 2,091 6,000 693 313,419 179 Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 1,718 429 2,147 2,147 4b.4.2 Insurance 838 84 921 921 4b.4.3 Property taxes 4

0 4

4 4b.4.4 Health physics supplies 6,647 1,662 8,309 8,309 4b.4.5 Heavy equipment rental 5,873 881 6,754 6,754 4b.4.6 Disposal of DAW generated 103 60 272 87 522 522 5,171 103,430 169 4b.4.7 Plant energy budget 2,638 396 3,034 3,034 4b.4.8 NRC Fees 1,050 105 1,156 1,156 4b.4.9 Indirect Overhead 1,455 218 1,673 1,673 4b.4.10 Liquid Radwaste Processing Equipment/Services 1,047 157 1,204 1,204 4b.4.11 Corporate A&G Cost 3,642 546 4,188 4,188 4b.4.12 Environmental Audit 1,875 281 2,157 2,157 4b.4.13 Security Staff Cost 4,024 604 4,628 4,628 88,198 4b.4.14 DOC Staff Cost 32,753 4,913 37,666 37,666 281,393 4b.4.15 Utility Staff Cost 39,485 5,923 45,408 45,408 495,587 4b.4 Subtotal Period 4b Period-Dependent Costs 1,718 12,521 103 60 272 88,811 16,287 119,771 119,771 5,171 103,430 169 865,178 4b.0 TOTAL PERIOD 4b COST 5,892 38,667 1,402 8,244 23,366 6,721 96,835 32,379 213,505 209,808 3,697 220,275 134,665 16,256,170 539,531 879,359 PERIOD 4f - License Termination Period 4f Direct Decommissioning Activities 4f.1.1 ORISE confirmatory survey 176 53 229 229 4f.1.2 Terminate license a

4f.1 Subtotal Period 4f Activity Costs 176 53 229 229 Period 4f Additional Costs 4f.2.1 License Termination Survey 6,800 2,040 8,840 8,840 121,022 3,120 4f.2 Subtotal Period 4f Additional Costs 6,800 2,040 8,840 8,840 121,022 3,120 Period 4f Collateral Costs 4f.3.1 DOC staff relocation expenses 1,465 220 1,685 1,685 4f.3.2 Annual Fees 47 7

54 54 4f.3 Subtotal Period 4f Collateral Costs 1,511 227 1,738 1,738 Period 4f Period-Dependent Costs 4f.4.1 Insurance 4f.4.2 Property taxes 1

0 2

2 4f.4.3 Health physics supplies 1,263 316 1,579 1,579 4f.4.4 Disposal of DAW generated 7

4 18 6

35 35 346 6,917 11 4f.4.5 Plant energy budget 271 41 312 312 4f.4.6 NRC Fees 462 46 508 508 4f.4.7 Indirect Overhead 214 32 246 246 4f.4.8 Corporate A&G Cost 673 101 774 774 4f.4.9 Environmental Audit 723 108 831 831 4f.4.10 Security Staff Cost 589 88 677 677 12,138 4f.4.11 DOC Staff Cost 5,737 861 6,598 6,598 48,148 4f.4.12 Utility Staff Cost 5,327 799 6,126 6,126 58,667 4f.4 Subtotal Period 4f Period-Dependent Costs 1,263 7

4 18 13,997 2,398 17,687 17,687 346 6,917 11 118,953 4f.0 TOTAL PERIOD 4f COST 1,263 7

4 18 22,485 4,718 28,495 28,495 346 6,917 121,033 122,073 PERIOD 4 TOTALS 6,149 85,492 25,460 19,446 49,953 40,708 185,546 88,553 501,307 495,023 6,284 483,399 207,803 626 337 1,773 33,590,070 992,814 1,628,906 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 24 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d 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 2,531 380 2,911 2,911 21,126 5b.1.1.2 AAC Generator Building 18 3

21 21 187 5b.1.1.3 Administrative Building 54 8

62 62 327 5b.1.1.4 Auxiliary Building 1,663 250 1,913 1,913 12,716 5b.1.1.5 CA-3 Building 16 2

18 18 158 5b.1.1.6 Circulating Water Tunnels/Pipe 285 43 327 327 4,380 5b.1.1.7 Cooling Tower Concrete Removal 22 3

26 26 137 5b.1.1.8 Cooling Tower Pump House 66 10 76 76 696 5b.1.1.9 Degasifier Building 9

1 10 10 89 5b.1.1.10 Diesel Fuel Storage Vault 139 21 160 160 1,393 5b.1.1.11 Flex Buildings 2 (2019) 160 24 184 184 1,250 5b.1.1.12 Intake Structure 42 6

48 48 290 5b.1.1.13 Low Level Radwaste Office 8

1 10 10 163 5b.1.1.14 Low Level Radwaste Storage 339 51 390 390 2,055 5b.1.1.15 Maintenance Facility 369 55 425 425 4,283 5b.1.1.16 Misc Site Structures 1,357 204 1,561 1,561 11,587 5b.1.1.17 Oily Water Seperator 6

1 7

7 37 5b.1.1.18 Old Steam Gen. Storage Facility 164 25 189 189 1,002 5b.1.1.19 Site Additions (02-08) 383 57 440 440 3,132 5b.1.1.20 Site Additions (98-02) 239 36 275 275 2,426 5b.1.1.21 Site Drainage & Storm Sewers 124 19 143 143 1,906 5b.1.1.22 Site Manholes 61 9

71 71 673 5b.1.1.23 Site Paving,Rail & Fencing 633 95 728 728 6,070 5b.1.1.24 Solid Radwaste Storage Building 39 6

45 45 437 5b.1.1.25 Start-Up Boiler 44 7

51 51 612 5b.1.1.26 Tank Foundations 29 4

34 34 208 5b.1.1.27 Turbine Building 1,032 155 1,187 1,187 11,874 5b.1.1.28 Turbine Pedestal 464 70 533 533 2,881 5b.1.1 Totals 10,298 1,545 11,843 11,843 92,097 Site Closeout Activities 5b.1.2 BackFill Site 21,946 3,292 25,238 25,238 51,296 5b.1.3 Grade & landscape site 168 25 194 194 559 5b.1.4 Final report to NRC 140 21 161 161 849 5b.1 Subtotal Period 5b Activity Costs 32,413 140 4,883 37,436 161 37,274 143,952 849 Period 5b Additional Costs 5b.2.1 Concrete Crushing 691 12 105 808 808 3,079 5b.2.2 Construction Debris 1,438 216 1,654 1,654 5b.2.3 Demolition and Site Restoration ISFSI 3,610 469 612 4,691 4,691 30,191 80 5b.2.4 Cooling Tower Removal 4,762 714 5,476 5,476 17,913 5b.2.5 Mobile Barrier Removal 183 267 68 518 518 1,200 5b.2.6 Intake and Discharge Cofferdam 653 98 751 751 5,226 5b.2 Subtotal Period 5b Additional Costs 9,899 2,187 1,813 13,898 13,898 57,610 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 213 32 245 245 5b.3 Subtotal Period 5b Collateral Costs 213 32 245 245 Period 5b Period-Dependent Costs 5b.4.1 Insurance 5b.4.2 Property taxes 4

0 4

4 5b.4.3 Heavy equipment rental 8,367 1,255 9,622 9,622 5b.4.4 Plant energy budget 366 55 421 421 5b.4.5 Indirect Overhead 165 25 190 190 5b.4.6 Corporate A&G Cost 506 76 581 581 5b.4.7 Environmental Audit 1,952 293 2,244 2,244 5b.4.8 Security Staff Cost 1,428 214 1,642 1,642 28,957 5b.4.9 DOC Staff Cost 14,481 2,172 16,653 16,653 115,828 5b.4.10 Utility Staff Cost 5,110 766 5,876 5,876 56,821 5b.4 Subtotal Period 5b Period-Dependent Costs 8,367 24,010 4,856 37,233 37,233 201,605 TLG Services, LLC

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix D, Page 25 of 25 Table D-2 Arkansas Nuclear One Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2024 Dollars)

Costs run: Wed, Mar 6, 2024 at 13:51:34 Off-Site LLRW NRC Spent Fuel Site Processed Burial Volumes Burial /

Utility and Activity DECCER Version 2016.08.16d Decon Removal Packaging Transport Processing Disposal Other Total Total Lic. Term.

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

Manhours Manhours 5b.0 TOTAL PERIOD 5b COST 50,891 26,337 11,584 88,812 161 88,651 201,561 202,534 PERIOD 5 TOTALS 50,891 26,337 11,584 88,812 161 88,651 201,561 202,534 TOTAL COST TO DECOMMISSION 13,320 154,029 25,842 20,195 49,953 41,830 822,342 197,476 1,324,988 984,185 244,728 96,074 483,399 217,545 626 337 1,773 33,864,850 1,282,963 6,693,652 TOTAL COST TO DECOMMISSION WITH 17.51% CONTINGENCY:

$1,324,988 thousands of 2024 dollars TOTAL NRC LICENSE TERMINATION COST IS 74.28% OR:

$984,185 thousands of 2024 dollars SPENT FUEL MANAGEMENT COST IS 18.47% OR:

$244,728 thousands of 2024 dollars NON-NUCLEAR DEMOLITION COST IS 7.25% OR:

$96,074 thousands of 2024 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):

218,508 Cubic Feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:

1,773 Cubic Feet TOTAL SCRAP METAL REMOVED:

50,326 Tons TOTAL CRAFT LABOR REQUIREMENTS:

1,282,963 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, LLC

Arkansas Nuclear One Document E11-1828-001, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 1 of 2 TLG Services, LLC APPENDIX E DETAILED COST ANALYSIS ISFSI

Arkansas Nuclear One Decommissioning Cost Analysis Document E11-1828-001, Rev. 0 Appendix E, Page 2 of 2 Activity Description Removal Costs Packaging Costs Transport Costs LLRW Disposal Costs Other Costs Total Costs Burial Volume Class A (cubic feet)

Craft Manhours Oversight and Contractor Manhours Decommissioning Contractor Planning (characterization, specs and procedures) 622 622 1,336 Decontamination (activated disposition) 493 369 2,538 3,842 7,242 25,711 3,492 License Termination (radiological surveys) 2,802 2,802 17,882 Subtotal 493 369 2,538 3,842 3,424 10,666 25,711 21,374 1,336 Supporting Costs NRC and NRC Contractor Fees and Costs 689 689 1,153 Insurance 100 100 Property taxes 1

1 Annual Fees 40 40 Plant energy budget 11 11 Indirect Overhead 15 15 Corporate A&G Cost 80 80 Security Staff Cost 236 236 5,082 Utility Staff Cost 335 335 3,855 Subtotal 1,508 1,508 10,090 Total (w/o contingency) 493 369 2,538 3,842 4,932 12,174 25,711 21,374 11,426 Total (w/25% contingency) 616 461 3,173 4,803 6,164 15,217 The application of contingency (25%) is consistent with the evaluation criteria referenced by the NRC in NUREG-1757 ("Consolidated Decommissioning Guidance, Financial Assurance, Recordkeeping, and Timeliness," U.S. NRC's Office of Nuclear Material Safety and Safeguards, NUREG-1757, Vol. 3, Rev. 1, February 2012)

Table E-1 Arkansas Nuclear One ISFSI Decommissioning Cost Estimate DECON Decommissioning Alternative (thousands of 2024 dollars)

TLG Services, LLC

Enclosure, Attachment 2 CNRO2024-00026 Arkansas Nuclear One Unit 1 - DECON Methodology, Annual Cash Flow Analysis - Total License Termination Costs

CNRO2024-00026 Enclosure, Attachment 2 Page 1 of 2 Arkansas Nuclear One Unit 1 - DECON Methodology Annual Cash Flow Analysis - Total License Termination Costs (In thousands of 2024 Dollars)

Year Column 1 50.75 License Termination Cost (thousands)

Column 2 Beginning of Year Trust Fund Balance (thousands)

Column 3 Withdraw (thousands)

Column 4 Contribute (thousands)

Balance for Earnings Calculation (thousands)

Column 5 Trust Fund Earnings (thousands)

Column 6 Year Ending Trust Fund Balance (thousands) 2024 0

833,935 0

0 833,935 8,339 842,274 2025 20,000 842,274 20,000 0

822,274 16,445 838,720 2026 0

838,720 0

0 838,720 16,774 855,494 2027 0

855,494 0

0 855,494 17,110 872,604 2028 0

872,604 0

0 872,604 17,452 890,056 2029 0

890,056 0

0 890,056 17,801 907,857 2030 0

907,857 0

0 907,857 18,157 926,014 2031 0

926,014 0

0 926,014 18,520 944,535 2032 0

944,535 0

0 944,535 18,891 963,425 2033 0

963,425 0

0 963,425 19,269 982,694 2034 63,198 982,694 63,198 0

919,496 18,390 937,886 2035 161,106 937,886 161,106 0

776,780 15,536 792,315 2036 185,418 792,315 185,418 0

606,897 12,138 619,035 2037 139,719 619,035 139,719 0

479,316 9,586 488,903 2038 89,008 488,903 89,008 0

399,894 7,998 407,892 2039 85,726 407,892 85,726 0

322,166 6,443 328,609 2040 19,250 328,609 19,250 0

309,359 6,187 315,547 2041 6,893 315,547 6,893 0

308,654 6,173 314,827 2042 6,893 314,827 6,893 0

307,935 6,159 314,093 2043 6,893 314,093 6,893 0

307,201 6,144 313,345 2044 26,979 313,345 26,979 0

286,366 5,727 292,093 2045 6,345 292,093 6,345 0

285,748 5,715 291,463 2046 324 291,463 324 0

291,139 5,823 296,962 2047 84 296,962 84 0

296,878 5,938 302,816 2048 0

302,816 0

0 302,816 6,056 308,872 2049 0

308,872 0

0 308,872 6,177 315,050 2050 0

315,050 0

0 315,050 6,301 321,351 2051 0

321,351 0

0 321,351 6,427 327,778 2052 0

327,778 0

0 327,778 6,556 334,333 2053 0

334,333 0

0 334,333 6,687 341,020 2054 0

341,020 0

0 341,020 6,820 347,840 2055 0

347,840 0

0 347,840 6,957 354,797 2056 0

354,797 0

0 354,797 7,096 361,893 2057 0

361,893 0

0 361,893 7,238 369,131 2058 0

369,131 0

0 369,131 7,383 376,513 2059 0

376,513 0

0 376,513 7,530 384,044

CNRO2024-00026 Enclosure, Attachment 2 Page 2 of 2 Arkansas Nuclear One Unit 1 - DECON Methodology Annual Cash Flow Analysis - Total License Termination Costs (In thousands of 2024 Dollars)

Year Column 1 50.75 License Termination Cost (thousands)

Column 2 Beginning of Year Trust Fund Balance (thousands)

Column 3 Withdraw (thousands)

Column 4 Contribute (thousands)

Balance for Earnings Calculation (thousands)

Column 5 Trust Fund Earnings (thousands)

Column 6 Year Ending Trust Fund Balance (thousands) 2060 0

384,044 0

0 384,044 7,681 391,725 2061 0

391,725 0

0 391,725 7,834 399,559 2062 0

399,559 0

0 399,559 7,991 407,550 2063 0

407,550 0

0 407,550 8,151 415,701 2064 0

415,701 0

0 415,701 8,314 424,015 2065 0

424,015 0

0 424,015 8,480 432,496 2066 0

432,496 0

0 432,496 8,650 441,145 2067 0

441,145 0

0 441,145 8,823 449,968 2068 0

449,968 0

0 449,968 8,999 458,968 2069 0

458,968 0

0 458,968 9,179 468,147 2070 0

468,147 0

0 468,147 9,363 477,510 2071 0

477,510 0

0 477,510 9,550 487,060 2072 0

487,060 0

0 487,060 9,741 496,801 2073 0

496,801 0

0 496,801 9,936 506,737 2074 0

506,737 0

0 506,737 10,135 516,872 2075 0

516,872 0

0 516,872 10,337 527,210 2076 0

527,210 0

0 527,210 10,544 537,754 2077 0

537,754 0

0 537,754 10,755 548,509 2078 0

548,509 0

0 548,509 10,970 559,479 2079 0

559,479 0

0 559,479 11,190 570,669 2080 0

570,669 0

0 570,669 11,413 582,082 2081 0

582,082 0

0 582,082 11,642 593,724 2082 0

593,724 0

0 593,724 11,874 605,598 2083 9,697 605,598 9,697 0

595,901 11,918 607,819 2084 7,608 607,819 7,608 0

600,211 12,004 612,215 Total 835,140 835,140 0 31,087,976 613,420 612,215

Enclosure, Attachment 3 CNRO2024-00026 Arkansas Nuclear One Unit 2 - DECON Methodology, Annual Cash Flow Analysis - Total License Termination Costs

CNRO2024-00026 Enclosure, Attachment 3 Page 1 of 2 Arkansas Nuclear One Unit 2 - DECON Methodology Annual Cash Flow Analysis - Total License Termination Costs (In thousands of 2024 Dollars)

Year Column 1 50.75 License Termination Cost (thousands)

Column 2 Beginning of Year Trust Fund Balance (thousands)

Column 3 Withdraw (thousands)

Column 4 Contribute (thousands)

Balance for Earnings Calculation (thousands)

Column 5 Trust Fund Earnings (thousands)

Column 6 Year Ending Trust Fund Balance (thousands) 2024 0

688,573 0

0 688,573 6,886 695,459 2025 20,000 695,459 20,000 0

675,459 13,509 688,968 2026 0

688,968 0

0 688,968 13,779 702,748 2027 0

702,748 0

0 702,748 14,055 716,803 2028 0

716,803 0

0 716,803 14,336 731,139 2029 0

731,139 0

0 731,139 14,623 745,762 2030 0

745,762 0

0 745,762 14,915 760,677 2031 0

760,677 0

0 760,677 15,214 775,890 2032 0

775,890 0

0 775,890 15,518 791,408 2033 0

791,408 0

0 791,408 15,828 807,236 2034 0

807,236 0

0 807,236 16,145 823,381 2035 0

823,381 0

0 823,381 16,468 839,849 2036 0

839,849 0

0 839,849 16,797 856,646 2037 0

856,646 0

0 856,646 17,133 873,779 2038 43,949 873,779 43,949 0

829,829 16,597 846,426 2039 125,503 846,426 125,503 0

720,923 14,418 735,342 2040 178,726 735,342 178,726 0

556,615 11,132 567,748 2041 159,629 567,748 159,629 0

408,119 8,162 416,281 2042 111,823 416,281 111,823 0

304,458 6,089 310,547 2043 111,823 310,547 111,823 0

198,724 3,974 202,699 2044 56,866 202,699 56,866 0

145,833 2,917 148,750 2045 6,662 148,750 6,662 0

142,088 2,842 144,929 2046 434 144,929 434 0

144,496 2,890 147,386 2047 112 147,386 112 0

147,274 2,945 150,219 2048 0

150,219 0

0 150,219 3,004 153,224 2049 0

153,224 0

0 153,224 3,064 156,288 2050 0

156,288 0

0 156,288 3,126 159,414 2051 0

159,414 0

0 159,414 3,188 162,602 2052 0

162,602 0

0 162,602 3,252 165,854 2053 0

165,854 0

0 165,854 3,317 169,172 2054 0

169,172 0

0 169,172 3,383 172,555 2055 0

172,555 0

0 172,555 3,451 176,006 2056 0

176,006 0

0 176,006 3,520 179,526 2057 0

179,526 0

0 179,526 3,591 183,117 2058 0

183,117 0

0 183,117 3,662 186,779 2059 0

186,779 0

0 186,779 3,736 190,515

CNRO2024-00026 Enclosure, Attachment 3 Page 2 of 2 Arkansas Nuclear One Unit 2 - DECON Methodology Annual Cash Flow Analysis - Total License Termination Costs (In thousands of 2024 Dollars)

Year Column 1 50.75 License Termination Cost (thousands)

Column 2 Beginning of Year Trust Fund Balance (thousands)

Column 3 Withdraw (thousands)

Column 4 Contribute (thousands)

Balance for Earnings Calculation (thousands)

Column 5 Trust Fund Earnings (thousands)

Column 6 Year Ending Trust Fund Balance (thousands) 2060 0

190,515 0

0 190,515 3,810 194,325 2061 0

194,325 0

0 194,325 3,886 198,211 2062 0

198,211 0

0 198,211 3,964 202,176 2063 0

202,176 0

0 202,176 4,044 206,219 2064 0

206,219 0

0 206,219 4,124 210,344 2065 0

210,344 0

0 210,344 4,207 214,550 2066 0

214,550 0

0 214,550 4,291 218,841 2067 0

218,841 0

0 218,841 4,377 223,218 2068 0

223,218 0

0 223,218 4,464 227,683 2069 0

227,683 0

0 227,683 4,554 232,236 2070 0

232,236 0

0 232,236 4,645 236,881 2071 0

236,881 0

0 236,881 4,738 241,619 2072 0

241,619 0

0 241,619 4,832 246,451 2073 0

246,451 0

0 246,451 4,929 251,380 2074 0

251,380 0

0 251,380 5,028 256,408 2075 0

256,408 0

0 256,408 5,128 261,536 2076 0

261,536 0

0 261,536 5,231 266,766 2077 0

266,766 0

0 266,766 5,335 272,102 2078 0

272,102 0

0 272,102 5,442 277,544 2079 0

277,544 0

0 277,544 5,551 283,095 2080 0

283,095 0

0 283,095 5,662 288,757 2081 0

288,757 0

0 288,757 5,775 294,532 2082 0

294,532 0

0 294,532 5,891 300,422 2083 10,554 300,422 10,554 0

289,869 5,797 295,666 2084 7,609 295,666 7,609 0

288,057 5,761 293,818 Total 833,689 833,689 0 22,290,968 438,934 293,818