ML24150A004
| ML24150A004 | |
| Person / Time | |
|---|---|
| Site: | Peach Bottom, Salem, Hope Creek  |
| Issue date: | 12/31/2021 |
| From: | Public Service Enterprise Group, TLG Services |
| To: | Office of Nuclear Material Safety and Safeguards, Office of Nuclear Reactor Regulation |
| Shared Package | |
| ML24150A002 | List: |
| References | |
| LR-N24-0040 | |
| Download: ML24150A004 (1) | |
Text
Document P07-1794-002, Rev. 0 DECOMMISSIONING COST ANALYSIS for the SALEM GENERATING STATION prepared for PSEG Nuclear LLC prepared by TLG Services, LLC Bridgewater, Connecticut December 2021 LR-N24-0040 Attachment 1 Page 1 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Page iii of xxii TLG Services, LLC TABLE OF CONTENTS SECTION PAGE 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 Disposal.............................................. 1-9 1.3.3 Radiological Criteria for License Termination................................. 1-10 2.
DECOMMISSIONING ALTERNATIVES......................................................... 2-1 2.1 DECON............................................................................................................ 2-2 2.1.1 Period 1 - Preparations........................................................................ 2-2 2.1.2 Period 2 - Decommissioning Operations............................................. 2-4 2.1.3 Period 3 - Site Restoration.................................................................. 2-8 2.1.4 ISFSI Operations and Decommissioning........................................... 2-9 2.2 SAFSTOR........................................................................................................ 2-9 2.2.1 Period 1 - Preparations...................................................................... 2-10 2.2.2 Period 2 - Dormancy.......................................................................... 2-11 2.2.3 Periods 3 and 4 - Delayed Decommissioning.................................... 2-12 2.2.4 Period 5 - Site Restoration................................................................ 2-13 3.
COST 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...................................................................................... 3-7 3.5 Site-Specific Considerations........................................................................... 3-8 3.5.1 Spent Fuel Management..................................................................... 3-8 3.5.2 Reactor Vessel and Internal Components........................................ 3-11 3.5.3 Primary System Components........................................................... 3-12 3.5.4 Main Turbine and Condenser........................................................... 3-14 3.5.5 Transportation Methods.................................................................... 3-14 3.5.6 Low-Level Radioactive Waste Disposal............................................ 3-15 3.5.7 Site Conditions Following Decommissioning................................... 3-16 LR-N24-0040 Attachment 1 Page 2 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Page iv of xxii TLG Services, LLC TABLE OF CONTENTS (continued)
SECTION PAGE 3.6 Assumptions.................................................................................................. 3-17 3.6.1 Estimating Basis................................................................................ 3-17 3.6.2 Labor Costs......................................................................................... 3-17 3.6.3 Design Conditions.............................................................................. 3-18 3.6.4 General............................................................................................... 3-19 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 SAFSTOR Alternative, Decommissioning Cost Elements............................ xxii 3.3 Unit 1, SAFSTOR, Total Annual Expenditures........................................... 3-35 3.3a Unit 1, SAFSTOR, License Termination Expenditures............................... 3-38 3.3b Unit 1, SAFSTOR, Spent Fuel Management Expenditures........................ 3-41 3.3c Unit 1, SAFSTOR, Site Restoration Expenditures....................................... 3-44 3.4 Unit 2, SAFSTOR, Total Annual Expenditures........................................... 3-45 3.4a Unit 2, SAFSTOR, License Termination Expenditures............................... 3-47 3.4b Unit 2, SAFSTOR, Spent Fuel Management Expenditures........................ 3-50 3.4c Unit 2, SAFSTOR, Site Restoration Expenditures....................................... 3-52 LR-N24-0040 Attachment 1 Page 3 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Page v of xxii TLG Services, LLC TABLE OF CONTENTS (continued)
SECTION PAGE TABLES (continued) 5.2 SAFSTOR Alternative, Decommissioning Waste Summary.......................... 5-6 6.2 SAFSTOR Alternative, Decommissioning Cost Elements............................. 6-5 FIGURES 3.2 Manpower Levels, SAFSTOR........................................................................ 3-54 4.1 DECON Activity Schedule................................................................................ 4-3 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 D.
SAFSTOR, Detailed Cost Analysis..................................................................... D-1 E.
ISFSI Decommissioning...................................................................................... E-1 LR-N24-0040 Attachment 1 Page 4 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Page xxii of xxii TLG Services, LLC SAFSTOR ALTERNATIVE DECOMMISSIONING COST ELEMENTS (thousands of 2021 dollars)
Cost Element Unit 1 Unit 2 Total Decontamination 18,330 18,822 37,152 Removal 143,315 165,352 308,667 Packaging 21,079 22,357 43,435 Transportation 16,236 16,279 32,514 Waste Disposal 52,751 52,482 105,233 Off-site Waste Processing 21,254 21,674 42,928 Program Management [1]
409,871 404,327 814,198 Severance 14,836 14,836 29,672 NEI Fees 9,497 8,803 18,300 Security 144,722 131,608 276,330 Spent Fuel Pool Equipment Modifications 1,483 988 2,471 Spent Fuel Storage (Direct Costs) [2]
135,160 136,148 271,308 Insurance and Regulatory Fees 66,579 61,176 127,755 Energy 29,109 28,713 57,821 Characterization and Licensing Surveys 28,740 26,365 55,105 Property Taxes 3,093 3,093 6,185 Miscellaneous Equipment 18,575 19,666 38,242 Total [3]
1,134,629 1,132,688 2,267,317 Cost Element Unit 1 Unit 2 Total NRC License Termination 795,721 784,483 1,580,204 Spent Fuel Management [4]
274,309 265,019 539,327 Site Restoration 64,599 83,187 147,786 Total [3]
1,134,629 1,132,688 2,267,317
[1]
Includes engineering costs
[2]
Includes costs for the dry storage system components, spent fuel loading and transfer, spent fuel pool O&M and EP fees
[3]
Columns may not add due to rounding
[4]
Reflects savings in ISFSI operations with the adjacent Hope Creek Generating Station LR-N24-0040 Attachment 1 Page 5 / 123
Salem Generating Station Document P07-1794-002, 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 the Salem Generating Station (Salem), for the selected decommissioning scenarios following the scheduled cessation of plant operations. The estimates are designed to provide the Owners with the information to assess their current decommissioning liability, as it relates to Salem.
Salem is jointly owned by PSEG Power, LLC (57.41%) and Exelon Generation Corporation LLC (42.59%). However, for purposes of this study, only the undivided decommissioning costs (100%) are presented, since the division of ownership has no effect on the total expenditures required. PSEG Nuclear, LLC is the licensed operator of the station. The two station owners will be collectively referred to as the Owners.
The analysis relies upon site-specific, technical information from an earlier evaluation prepared in 2018,[1]* updated to reflect current assumptions pertaining to the disposition of the nuclear plant and relevant industry experience in undertaking such projects. The costs are based on several key assumptions in areas of regulation, component characterization, high-level radioactive waste management, low-level radioactive waste disposal, performance uncertainties (contingency) and site restoration requirements.
The analysis is not a detailed engineering evaluation, but an estimate 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 Salem; the plan may differ from the assumptions made in this analysis based on facts that exist at the time of decommissioning.
The 2018 plant inventory serves as the basis for the decontamination and dismantling requirements and cost, and the decommissioning waste streams.
1.1 OBJECTIVES OF STUDY The objectives of this study are to prepare comprehensive estimates of the cost to decommission Salem, to provide a sequence or schedule for the associated activities, and to develop waste stream projections from the decontamination and dismantling activities.
- Annotated references for citations in Sections 1-6 are provided in Section 7.
LR-N24-0040 Attachment 1 Page 6 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 1, Page 2 of 11 TLG Services, LLC The station is comprised of two identical units, constructed concurrently, with construction permits being issued on the same date. The original 40-year licenses were extended by the NRC on June 30, 2011. As such, the current operating license for Unit 1 (Facility Operating License No. DPR-70) expires at midnight on August 13, 2036 and the current operating license for Unit 2 (Facility Operating License No. DPR-75) expires at midnight on April 18, 2040.
This study assumes that the nuclear units will operate for the full 60 years.
1.2 SITE DESCRIPTION The Salem nuclear units are located on the southern part of Artificial Island on the east bank of the Delaware River in Lower Alloways Creek Township, Salem County, New Jersey. The site is 15 miles south of the Delaware Memorial Bridge, 18 miles south of Wilmington, Delaware, 30 miles southwest of Philadelphia, Pennsylvania, and 71/2 miles southwest of Salem, New Jersey.
The Nuclear Steam Supply System (NSSS) consists of a pressurized water reactor and a four-loop Reactor Coolant System (RCS). The system was supplied by the Westinghouse Electric Corporation. The licensed rating for the units was originally 3,411 megawatts-thermal (MWt). Amendment Nos. 243 (Salem Unit
- 1) and 224 (Salem Unit 2), dated May 25, 2001, authorized a 1.4 percent increase in the licensed rated power level to 3,459 MWt. The corresponding net summer capacity is 1,174 megawatts-electric (MWe) for Unit 1 and 1,130 MWe for Unit
- 2.
The NSSS is housed within a containment structure, a seismic Category I, reinforced-concrete, dry structure. The containment is a cylinder with a hemispherical dome and a flat, reinforced-concrete foundation mat. A welded steel liner plate anchored to the inside face of the containment serves as a leak-tight membrane.
Heat produced in the reactor is converted to electrical energy by the steam and power conversion system. A turbine-generator system converts the thermal energy of steam produced in the steam generators into mechanical shaft power and then into electrical energy. The plants turbine-generators are each tandem-compound, four-element units. They consist of one high-pressure, double-flow, and three low-pressure, double-flow elements driving a direct-coupled generator at 1,800 rpm. The turbines are operated in a closed feedwater cycle that condenses the steam; the heated feedwater is returned to the steam generators.
Heat rejected in the main condensers is removed by the circulating water system.
LR-N24-0040 Attachment 1 Page 7 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 1, Page 3 of 11 TLG Services, LLC The circulating water system provides the heat sink required for removal of waste heat in the power plants thermal cycle. The system has the principal function of removing heat by absorbing this energy in the main condenser. Water is withdrawn from the Delaware River by the circulating water pumps located at the intake structure. After passing through the plant condensers, the discharge is routed back into the Delaware estuary.
1.3 REGULATORY GUIDANCE The Nuclear Regulatory Commission (NRC or Commission) provided initial decommissioning requirements in its rule "General Requirements for Decommissioning Nuclear Facilities," issued in June 1988.[2] This rule set forth financial criteria for decommissioning licensed nuclear power facilities. The regulation addressed decommissioning planning needs, timing, funding methods, and environmental review requirements. The intent of the rule was to ensure that decommissioning would be accomplished in a safe and timely manner and that adequate funds would be available for this purpose.
Subsequent to the rule, the NRC issued Regulatory Guide 1.159, Assuring the Availability of Funds for Decommissioning Nuclear Reactors,[3] which provided additional guidance to the licensees of nuclear facilities on the financial methods acceptable to the NRC staff for complying with the requirements of the rule. The regulatory guide addressed the funding requirements and provided guidance on the content and form of the financial assurance mechanisms indicated in the rule.
The rule defined three decommissioning alternatives as being acceptable to the NRC: DECON, SAFSTOR, and ENTOMB. The DECON alternative assumes that any contaminated or activated portion of the plants systems, structures, and facilities are removed or decontaminated to levels that permit the site to be released for unrestricted use shortly after the cessation of plant operations.
The rule also placed limits on the time allowed to complete the decommissioning process. For the SAFSTOR alternative, the process is restricted in overall duration to 60 years, unless it can be shown that a longer duration is necessary to protect public health and safety. The guidelines for ENTOMB are similar, providing the NRC with both sufficient leverage and flexibility to ensure that these deferred options are only used in situations where it is reasonable and consistent with the definition of decommissioning. At the conclusion of a 60-year dormancy period (or longer for ENTOMB if the NRC approves such a case), the site would still require significant remediation to meet the unrestricted release limits for license termination.
LR-N24-0040 Attachment 1 Page 8 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 1, Page 4 of 11 TLG Services, LLC The ENTOMB alternative has not been viewed as a viable option for power reactors due to the significant time required to isolate the long-lived radionuclides for decay to permissible levels. However, with rulemaking permitting the controlled release of a site,[4] the NRC did re-evaluate the alternative. The resulting feasibility study, based upon an assessment by Pacific Northwest National Laboratory, concluded that the method did have conditional merit for some, if not most reactors. The staff also found that additional rulemaking would be needed before this option could be treated as a generic alternative.
The NRC had considered rulemaking to alter the 60-year time for completing decommissioning and to clarify the use of engineered barriers for reactor entombments.[5] However, the NRCs staff has recommended that rulemaking be deferred, based upon several factors, e.g., no licensee has committed to pursuing the entombment option, the unresolved issues associated with the disposition of greater-than-Class C material (GTCC), and the NRCs current priorities, at least until after the additional research studies are complete. The Commission concurred with the staffs recommendation.
In 1996, the NRC published revisions to the general requirements for decommissioning nuclear power plants.[6] When the regulations were originally adopted in 1988, it was assumed that the majority of licensees would decommission at the end of the facilitys operating licensed life. Since that time, several licensees permanently and prematurely ceased operations. Exemptions from certain operating requirements were required once the reactor was defueled to facilitate the decommissioning. Each case was handled individually, without clearly defined generic requirements. The NRC amended the decommissioning regulations in 1996 to clarify ambiguities and codify procedures and terminology as a means of enhancing efficiency and uniformity in the decommissioning process. The new amendments allow for greater public participation and better define the transition process from operations to decommissioning.
Under the revised regulations, licensees will submit written certification to the NRC within 30 days after the decision to cease operations. Certification will also be required once the fuel is permanently removed from the reactor vessel.
Submittal of these notices will entitle the licensee to a fee reduction and eliminate the obligation to follow certain requirements needed only during operation of the reactor. Prior to or within 2 years following 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, LR-N24-0040 Attachment 1 Page 9 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 1, Page 5 of 11 TLG Services, LLC and an estimate of expected costs. Prior to completing decommissioning, the licensee is required to submit applications to the NRC to terminate the license, which will include a License Termination Plan (LTP).
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.[7] 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 (NWPA) in 1982,[8]
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 NWPA Amendments Act of 1987[9] designated Yucca Mountain as the sole site to be considered for a permanent geologic repository. The DOE was to begin accepting spent fuel by January 31, 1998; however, to date no progress in the removal of spent fuel from commercial generating sites has been made.
Today, the country is at an impasse on high-level waste disposal, 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. 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.[10]
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 LR-N24-0040 Attachment 1 Page 10 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 1, Page 6 of 11 TLG Services, LLC
[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.[11]
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...[12]
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)[13] 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 was completed with the publication of a 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.
LR-N24-0040 Attachment 1 Page 11 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 1, Page 7 of 11 TLG Services, LLC 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 is currently under NRC review.
Waste Control Specialists 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. The joint venture has stated that they will request that the NRC resume its review of the original CISF license application.
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.
PSEGs current spent fuel management plan for Artificial Island assumes just-in-time acceptance, i.e., the DOE will be able to complete the transfer of spent fuel so as not to impede a deferred decommissioning scenario (SAFSTOR) and the termination of the earliest operating license (Salem, Unit 1) within the required 60-year period (from the cessation of operations). To achieve this objective, based upon the oldest fuel receiving the highest priority and an annual maximum rate of transfer of 3,000 metric tons of uranium, DOE would commence pickup of spent fuel from Salem no later than 2038, with Salem fuel completely removed from Artificial Island by 2088 (one year prior to the latest assumed start date for the decommissioning of Salem). Different DOE acceptance schedules result in different completion dates.
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 Secretary of Energy, pursuant LR-N24-0040 Attachment 1 Page 12 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 1, Page 8 of 11 TLG Services, LLC to 10 CFR Part 50.54(bb).[14] This requirement is prepared for through inclusion of certain cost elements in the decommissioning estimates, for example, associated with the isolation and continued operation of the spent fuel pools and the ISFSI.
The spent fuel pools are expected to contain freshly discharged assemblies (from the most recent refueling cycles) as well as the final reactor cores at shutdown. Over the following three and one-half years, the assemblies are packaged into multi-purpose canisters (MPCs) for transfer to the DOE or to an ISFSI for interim storage. It is assumed that this period provides the necessary cooling for the final cores to meet the transport and/or storage requirements for decay heat.
An ISFSI, operated under a Part 50 General License (in accordance with 10 CFR 72, Subpart K[15]), has been constructed to support continued plant operations. The facility is assumed to be expanded to support decommissioning. This will allow decommissioning activities to proceed within the fuel handling buildings.
Since the ISFSI is used by both Salem and the adjacent Hope Creek Generating Station (Hope Creek), costs to operate and maintain the ISFSI are shared between the stations. ISFSI operations will continue until 2089 when the last fuel from Hope Creek and Salem is removed.
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 Owners have 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.
If this assumption is incorrect, it is assumed that DOE will have liability for costs incurred to transfer the fuel to DOE-supplied containers.
LR-N24-0040 Attachment 1 Page 13 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 1, Page 9 of 11 TLG Services, LLC The Owners position is that the DOE has a contractual obligation to accept Salems 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, including the cost of storing spent fuel in this study is appropriate to ensure the availability of sufficient decommissioning funds at the end of the stations life if the DOE has not met its obligation. The cost for the interim storage of spent fuel has been calculated and is separately presented as "Spent Fuel Management expenditures in this report.
1.3.2 Low-Level Radioactive Waste Disposal The contaminated and activated material generated in the decontamination and dismantling of a commercial nuclear reactor is classified as low-level (radioactive) waste, although not all of the material is suitable for shallow-land disposal. With the passage of the Low-Level Radioactive Waste Policy Act in 1980,[16] and its Amendments of 1985,[17]
the states became ultimately responsible for the disposition of low-level radioactive waste generated within their own borders. It was expected that groups of states would combine together to jointly deal with their radioactive wastes; these organizations are referred to as waste disposal compacts.
New Jersey is a member of the three-state Atlantic Interstate Low-Level Radioactive Waste Management Compact, formed after South Carolina formally joined the Northeast Regional Compact. The Barnwell Low-Level Radioactive Waste Management Facility, located in South Carolina, is expected to be available to support the decommissioning of Salem. As such, the rate schedule for the Barnwell facility is used to generate disposal costs for the higher activity waste forms waste (Class A containerized waste, large components and Class B and C material[18]). It is also assumed that the Owners can access other disposal sites, should it prove cost-effective. Low activity waste forms and suspected material are routed to a Tennessee-based radioactive waste processor.
The dismantling of the components residing closest to the reactor core generates radioactive waste considered unsuitable for shallow-land disposal (i.e., low-level radioactive waste with concentrations of radionuclides that exceed the limits established by the NRC for Class C radioactive waste (GTCC)). The Low-Level Radioactive Waste Policy Amendments Act of 1985 assigned the federal government the responsibility for the disposal of this material. The Act also stated that LR-N24-0040 Attachment 1 Page 14 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 1, Page 10 of 11 TLG Services, LLC the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste.
The DOE issued its final Environmental Impact Statement for the disposal of GTCC on January 2016.[19 ] The study evaluated the potential environmental impacts associated with constructing and operating a new facility or using an existing facility, disposal methods, and locations. DOE is awaiting Congressional action on the report and its recommendations.
At this time, the federal government has not identified a specific cost for disposing of GTCC 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 irradiated spent fuel 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 licensed 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 metallic waste material generated during decommissioning may only be potentially contaminated by radioactive materials. This waste can be surveyed on site or shipped off site to licensed facilities for further analysis, for processing and/or for conditioning/recovery. Reduction in the volume of low-level radioactive waste requiring disposal in a licensed low-level radioactive waste disposal facility can be accomplished through a variety of methods, including analyses and surveys or decontamination to isolate 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,[20] amending 10 CFR §20. This subpart provides radiological criteria for releasing a facility for unrestricted use. The regulation states that the site can be released for unrestricted use if radioactivity levels are such that the average member of a critical group would not receive a Total Effective Dose Equivalent (TEDE) in excess of 25 millirem per year, and provided that residual radioactivity has been reduced to levels that are As Low As Reasonably Achievable (ALARA).
LR-N24-0040 Attachment 1 Page 15 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 1, Page 11 of 11 TLG Services, LLC The decommissioning estimates for Salem assume that the site will be remediated to a residual level consistent with the NRC-prescribed level as well as the State of New Jerseys remedial action levels for radioactive material.
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).[21] An additional limit of 4 millirem per year, as defined in 40 CFR §141.16, is applied to drinking water.[22]
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)[23] 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.
LR-N24-0040 Attachment 1 Page 16 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 1 of 13 TLG Services, LLC
- 2. DECOMMISSIONING ALTERNATIVES Detailed cost estimates were developed to decommission Salem based upon the approved decommissioning alternatives: DECON and SAFSTOR. Although the alternatives differ with respect to technique, process, cost, and schedule, they attain the same result: the ultimate release of the site for unrestricted use.
Two decommissioning scenarios were evaluated for the Salem nuclear units. The scenarios selected are representative of alternatives available to the Owners and are defined as follows:
- 1.
DECON: The first scenario assumes that the station would be promptly decommissioned (DECON alternative) upon the expiration of the current operating licenses, i.e., August 2036 and April 2040 for Units 1 and 2, respectively, after 60 years of operation. The spent fuel in the plants spent fuel storage pools is transferred to the ISFSI within three and one-half years of the cessation of operations at each unit. The equipment, structures, and portions of the plant containing radioactive contaminants are removed or decontaminated to a level that permits the facility to be released for unrestricted use. Non-essential structures are then demolished. Spent fuel storage operations continue at the site (ISFSI) until the transfer of the fuel to the DOE is complete in 2088.
At that time, the ISFSI is decommissioned and the site released for alternative use.
- 2.
SAFSTOR: The units are placed into safe-storage in the second scenario.
However, decommissioning is deferred beyond the fuel storage period to the maximum extent permitted by the current regulations. Similar to the DECON alternative, the spent fuel in the wet storage pools is relocated to the ISFSI for interim storage. The units remain in protective storage following the removal of spent fuel from the site. Decommissioning operations commence such that license termination is completed within the required 60-year period for Unit 1.
As with the first two scenarios, decommissioning activities at the two units are sequenced and integrated so as to minimize the total duration of the physical dismantling process.
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).
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 2 of 13 TLG Services, LLC The conceptual approach that the NRC has described in its regulations divides decommissioning into three phases. The initial phase commences with the effective date of permanent cessation of operations and involves the transition of both plant and licensee from reactor operations (i.e., power production) to facilitate de-activation and closure. During the first phase, notification is to be provided to the NRC certifying the permanent cessation of operations and the removal of fuel from the reactor vessel. The licensee would then be prohibited from reactor operation.
The second phase encompasses activities during the storage period or during major decommissioning activities, or a combination of the two. The third phase pertains to the activities involved in license termination. The decommissioning estimates developed for Salem are also divided into phases or periods; however, demarcation of the phases is based upon major milestones within the project or significant changes in the projected expenditures.
2.1 DECON The DECON alternative, as defined by the NRC, is "the alternative in which the equipment, structures, and portions of a facility and site containing radioactive contaminants are removed or decontaminated to a level that permits the property to be released for unrestricted use shortly after cessation of operations."
This study does not address the cost to dispose of the spent fuel residing at the site; such costs are funded through a surcharge on electrical generation.
However, the study does estimate the costs incurred with the interim on-site storage of the fuel pending shipment by the DOE to an off-site disposal facility.
Those costs are separately presented as "Spent Fuel Management Expenditures" in this report.
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.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 3 of 13 TLG Services, LLC 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 meeting to be held in the vicinity of the reactor site. Ninety days following submittal and NRC receipt of the PSDAR, the licensee may begin to perform major decommissioning activities under a modified 10 CFR
§50.59 procedure, (10 CFR §50.59 establishes the conditions under which licensees may make changes to the facility or procedures and conduct test or experiments, i.e., 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. Major components are further defined as comprising the reactor vessel and internals, large bore reactor coolant system piping, and other large components that are radioactive. The NRC includes the following additional criteria for use of the §50.59 process in decommissioning. The proposed activity must not:
foreclose release of the site for possible unrestricted use, significantly increase decommissioning costs, cause any significant environmental impact, or violate the terms of the licensees existing license Existing operational technical specifications are reviewed and modified to reflect plant conditions and the safety concerns associated with permanent cessation of operations. The environmental impact associated with the planned decommissioning activities is also considered. Typically, a licensee will not be allowed to proceed if the consequences of a particular decommissioning activity are greater than that bounded by previously evaluated environmental assessments or impact statements. In this instance, the licensee would have to submit a license amendment for the specific activity and update the environmental report.
The decommissioning program outlined in the PSDAR will be designed to accomplish the required tasks within the ALARA guidelines (as defined in 10 CFR §20) for protection of personnel from exposure to radiation LR-N24-0040 Attachment 1 Page 19 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 4 of 13 TLG Services, LLC hazards. It will also address the continued protection of the health and safety of the public and the environment during the dismantling activity.
Consequently, with the development of the
- PSDAR, activity specifications, cost-benefit and safety analyses, and work packages and procedures, would be assembled to support the proposed decontamination and dismantling activities.
Site Preparations Following final plant shutdown, and in preparation for actual decommissioning activities, the following activities are initiated:
Characterization of the site and surrounding environs. This includes radiation surveys of work areas, major components (including the reactor vessel and its internals), internal piping, and biological shield cores.
Modifications to the spent fuel storage pools and fuel handling systems, such that decommissioning operations can commence on the balance of the plant. Decommissioning operations are scheduled around the fuel handling areas to optimize the overall project schedule.
The fuel is transferred to the ISFSI as it decays to the point that it meets the definition of standard fuel. Consequently, it is assumed that each units fuel pool remains operational for approximately three and one-half years following the cessation of operations.
Specification of transport and disposal requirements for activated materials and/or hazardous materials, including shielding and waste stabilization.
Development of procedures for occupational exposure control, control and release of liquid and gaseous effluent, processing of radwaste (including dry-active waste, resins, filter media, metallic and non-metallic components generated in decommissioning), site security and emergency programs, and industrial safety.
2.1.2 Period 2 - Decommissioning Operations This period includes the physical decommissioning activities associated with the removal and disposal of contaminated and activated components and structures, including the successful amendment of the 10 CFR §50 operating license (releasing the site, exclusive of the ISFSI). Significant decommissioning activities in this phase include:
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 5 of 13 TLG Services, LLC Construction of temporary facilities and/or modification of existing facilities to support dismantling activities. This may include a centralized processing area to facilitate equipment removal and component preparations for off-site disposal.
Reconfiguration and modification of site structures and facilities as needed to support decommissioning operations. This may include the upgrading of roads (on and off site) to facilitate hauling and transport.
Modifications may be required to the containment structure to facilitate access of large/heavy equipment. Modifications may also be required to the refueling area of the Reactor Containment to support the segmentation of the reactor vessel internals and component extraction.
Design and fabrication of temporary and permanent shielding to support removal and transportation activities, construction of contamination control envelopes, and the procurement of specialty tooling.
Procurement (lease or purchase) of shipping canisters, cask liners, and industrial packages.
Decontamination of components and piping systems as required to control (minimize) worker exposure.
Removal of piping and components no longer essential to support decommissioning operations.
Removal of control rod drive housings and the head service structure from reactor vessel head. Segmentation of the vessel closure head.
Removal and segmentation of the upper internals assemblies.
Segmentation will maximize the loading of the shielded transport casks (i.e., by weight and activity). The operations are conducted under water using remotely operated tooling and contamination controls.
Disassembly and segmentation of the remaining reactor internals, including the core former and lower core support assembly. Some material is expected to exceed Class C disposal requirements. As such, the segments will be packaged in modified fuel storage canisters for geologic disposal.
Segmentation of the reactor vessel. A shielded platform is installed for segmentation as cutting operations are performed in-air using remotely operated equipment within a contamination control envelope. The water level is maintained just below the cut to minimize the working area dose rates. Segments are transferred in-air to LR-N24-0040 Attachment 1 Page 21 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 6 of 13 TLG Services, LLC containers that are stored under water, for example, in an isolated area of the refueling canal.
Removal of the activated portions of the concrete biological shield and accessible contaminated concrete surfaces. If dictated by the steam generator and pressurizer removal scenarios, those portions of the associated steam generator cubicles necessary for access and component extraction are removed.
Removal of the steam generators and pressurizer for material recovery and controlled disposal. These components can serve as their own burial containers provided that all penetrations are properly sealed and the internal contaminants are stabilized (e.g., with lightweight grout). Steel shielding is added, as necessary, to those external areas of the package to meet transportation limits and regulations.
Spent fuel storage operations continue throughout the active decommissioning period. Fuel transfer is expected to begin in 2038 and to be completed by the end of the year 2088.
At least two years prior to the anticipated date of license termination, an LTP is required. Submitted as a supplement to the Final Safety Analysis Report (FSAR) or its equivalent, the plan must include: a site characterization, description of the remaining dismantling activities, plans for site remediation, procedures for the final radiation survey, designation of the end use of the site, an updated cost estimate to complete the decommissioning, and any associated environmental concerns. The NRC will notice the receipt of the plan, make the plan available for public comment, and schedule a local meeting. LTP approval will be subject to any conditions and limitations as deemed appropriate by the Commission.
The licensee may then commence with the final remediation of site facilities and services, including:
Removal of remaining plant systems and associated components as they become nonessential to the decommissioning program or worker health and safety (e.g., waste collection and treatment systems, electrical power and ventilation systems).
Removal of the steel liners from the refueling canal, disposing of the activated and contaminated sections as radioactive waste. Removal of any activated/ contaminated concrete.
Surveys of the decontaminated areas of the containment structures.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 7 of 13 TLG Services, LLC Removal of the contaminated equipment and material from the auxiliary and fuel handling buildings, and any other contaminated facility. Use radiation and contamination control techniques until radiation surveys indicate that the structures can be released for unrestricted access and conventional demolition. This activity may necessitate the dismantling and disposition of most of the systems and components (both clean and contaminated) located within these buildings. This activity will facilitate surface decontamination and subsequent verification surveys required prior to obtaining release for demolition.
Removal of the remaining components, equipment, and plant services in support of the area release survey(s).
Routing of material removed in the decontamination and dismantling to a central processing area. Material certified to be free of contamination is released for unrestricted disposition, e.g., as scrap, recycle, or general disposal. Contaminated material is characterized and segregated for additional off-site processing (disassembly, chemical cleaning, volume reduction, and waste treatment), and/or packaged for controlled disposal at a low-level radioactive waste disposal facility.
Incorporated into the LTP is the Final Survey Plan. This plan identifies the radiological surveys to be performed once the decontamination activities are completed and is developed using the guidance provided in the Multi-Agency Radiation Survey and Site Investigation Manual (MARSSIM).[24] This document incorporates the statistical approaches to survey design and data interpretation used by the EPA. It also identifies commercially available instrumentation and procedures for conducting radiological surveys. Use of this guidance ensures that the surveys are conducted in a manner that provides a high degree of confidence that applicable NRC criteria are satisfied. Once the survey is complete, the results are provided to the NRC in a format that can be verified. The NRC then reviews and evaluates the information, performs an independent confirmation of radiological site conditions, and makes a determination on the requested change to the operating license (that would release the property, exclusive of the ISFSI, for unrestricted use).
The NRC will amend the operating license if it determines that site remediation has been performed in accordance with the LTP, and that the terminal radiation survey and associated documentation demonstrate that the facility is suitable for release.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 8 of 13 TLG Services, LLC 2.1.3 Period 3 - Site Restoration Following completion of decommissioning operations, site restoration activities will begin. Efficient removal of the contaminated materials and verification that residual radionuclide concentrations are below the NRC limits will result in substantial damage to many of the structures.
Although performed in a controlled and safe manner, blasting, coring, drilling, scarification (surface removal), and the other decontamination activities will substantially degrade power block structures including the reactor, auxiliary and turbine buildings. Under certain circumstances, verifying that subsurface radionuclide concentrations meet NRC site release requirements will require removal of grade slabs and lower floors, potentially weakening footings and structural supports. This removal activity will be necessary for those facilities and plant areas where historical records, when available, indicate the potential for radionuclides having been present in the soil, where system failures have been recorded, or where it is required to confirm that subsurface process and drain lines were not breached over the operating life of the station.
Dismantling of site structures following decommissioning is clearly the most appropriate and cost-effective option. It is unreasonable to anticipate that these structures would be repaired and preserved after the radiological contamination is removed. The effort to dismantle site structures with a work force already mobilized on site is more efficient than if the process were deferred. Site facilities quickly degrade without maintenance, adding additional expense and creating potential hazards to the public as well as to future workers. Abandonment creates a breeding ground for vermin infestation as well as other biological hazards.
This cost study presumes that non-essential structures and site facilities are dismantled as a continuation of the decommissioning activity.
Foundations and exterior walls are removed to a nominal depth of three feet below grade. The three-foot depth allows for the placement of gravel for drainage, as well as topsoil, so that vegetation can be established for erosion control. Site areas affected by the dismantling activities are restored and the plant area graded as required to prevent ponding and inhibit the refloating of subsurface materials.
Non-contaminated concrete rubble produced by demolition activities is processed to remove reinforcing steel and miscellaneous embedments.
The processed material is then used on site to backfill foundation voids.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 9 of 13 TLG Services, LLC Excess non-contaminated materials are trucked to an off-site area for disposal as construction debris.
2.1.4 ISFSI Operations and Decommissioning The ISFSI will continue to operate under a general license (10 CFR §50) following the amendment of the operating license(s) to release the adjacent (power block) property. Assuming the DOE starts accepting fuel from Salem fuel in 2038 (based upon the oldest fuel receiving the highest priority and an annual maximum rate of transfer of 3,000 metric tons of uranium), transfer of spent fuel from the ISFSI is anticipated to continue through the year 2088. Throughout this period cost for operating and maintaining the ISFSI are shared with the adjacent Hope Creek unit.
At the conclusion of the spent fuel transfer process, the ISFSI will be decommissioned. The Commission will terminate the §50 license(s) 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. Costs for demolishing the ISFSI are shared with the adjacent Hope Creek unit.
Spent fuel is stored on the ISFSI in multi-purpose canisters, each with a concrete overpack. For purposes of this cost analysis, it is assumed that once the inner canisters containing the spent fuel assemblies have been removed, any required decontamination performed on the storage overpack (some minor neutron-induced activation is assumed), and the license(s) for the facility terminated, the concrete overpacks can be dismantled using conventional techniques for the demolition of reinforced concrete. The concrete storage pad is then removed and the area regraded.
This topic is discussed in greater detail in section 3.5.1.
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 not required to operate in support of the spent fuel pools or site surveillance and security are drained, de-energized, and secured. Minimal cleaning/removal of LR-N24-0040 Attachment 1 Page 25 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 10 of 13 TLG Services, LLC 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:
Modifications to the spent fuel storage services and fuel handling systems located in the fuel handling buildings so that safe-storage operations may commence on the balance of the plant. This activity may be carried out by plant personnel in accordance with existing operating technical specifications. Activities are scheduled around the fuel handling systems to the greatest extent possible.
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.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 11 of 13 TLG Services, LLC Cleaning of the loose surface contamination from building access pathways.
Performing an interim radiation survey of plant, posting warning signs where appropriate.
Erecting physical barriers and/or securing all access to radioactive or contaminated areas, except as required for inspection and maintenance.
Installing security and surveillance monitoring equipment and relocating security fence around secured structures, as required.
2.2.2 Period 2 - Dormancy The second phase identified by the NRC in its rule addresses licensed activities during a storage period and is applicable to the dormancy phases of the deferred decommissioning alternatives. Dormancy activities include a 24-hour security force, preventive and corrective maintenance on security systems, area lighting, general building maintenance, heating and ventilation of buildings, routine radiological inspections of contaminated structures, maintenance of structural integrity, and a site environmental and radiation monitoring program. Resident maintenance personnel perform equipment maintenance, inspection activities, routine services to maintain safe conditions, adequate lighting, heating, and ventilation, and periodic preventive maintenance on essential site services.
An environmental surveillance program is carried out during the dormancy period to ensure that releases of radioactive material to the environment are prevented and/or detected and controlled. Appropriate emergency procedures are established and initiated for potential releases that exceed prescribed limits. The environmental surveillance program constitutes an abbreviated version of the program in effect during normal plant operations.
Security during the dormancy period is conducted primarily to prevent unauthorized entry and to protect the public from the consequences of their own actions. The security fence, sensors, alarms, and other surveillance equipment provide security. Fire and radiation alarms are also monitored and maintained. While remote surveillance is an option, it does not offer the immediate response time of a physical presence.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 12 of 13 TLG Services, LLC The transfer of the spent fuel to a DOE facility continues during this period until complete. Whenever possible, costs for maintaining the ISFSI are shared between Salem and the adjacent Hope Creek unit.
The length of the dormancy period is such that decommissioning (license termination) of the oldest unit on site (Salem Unit 1) is accomplished within 60 years of final shutdown. Decommissioning operations at two Salem units are synchronized and optimized so as to coordinate the termination of the operating licenses.
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 for activities and the writing of activity specifications and detailed procedures are also initiated at this time.
Much of the work in developing a termination plan is relevant to the development of the detailed engineering plans and procedures. The activities associated with this phase and the follow-on decontamination and dismantling processes are detailed in Sections 2.1.1 and 2.1.2. The primary difference between the sequences anticipated for the DECON and deferred scenarios is the absence, in the latter, of any constraint on the availability of the fuel storage pool located within the fuel handling buildings for decommissioning.
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. However, given the levels of radioactivity and spectrum of radionuclides expected from sixty years of plant operation, no plant process system identified as being contaminated upon final shutdown will become releasable due to the decay period alone.
(i.e., there is no significant reduction in the waste generated from the decommissioning activities). Due to the lower activity levels, a greater LR-N24-0040 Attachment 1 Page 28 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 2, Page 13 of 13 TLG Services, LLC 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 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 sacrificial shield will still be radioactive due to the presence of activated trace elements with long half-lives (152Eu and 154Eu). Decontamination will require controlled removal and disposal. It is assumed that radioactive corrosion products on inner surfaces of piping and components will not have decayed to levels that will permit unrestricted use or allow conventional removal. These systems and components will be surveyed as they are removed and disposed of in accordance with the existing radioactive release criteria.
2.2.4 Period 5 - Site Restoration Following completion of decommissioning operations, site-restoration activities can begin.
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 in this scenario 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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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 1 of 55 TLG Services, LLC
- 3. COST ESTIMATES The cost estimates prepared for decommissioning Salem consider the unique features of the site, including the NSSS, power generation systems, support services, site buildings, and ancillary facilities. The basis of the estimates, including the sources of information relied upon, the estimating methodology employed, site-specific considerations, and other pertinent assumptions, is described in this section.
3.1 BASIS OF ESTIMATES The estimates were developed using the site-specific, technical information from the 2018 analysis. This information was reviewed for the current analysis. The review confirmed that there were no substantive changes over the three year period to the configuration of the plant or site facilities. The site-specific considerations and assumptions used in the previous evaluation were also revisited. Modifications were incorporated where 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,"[25] and the DOE "Decommissioning Handbook."[26] These documents present a unit factor method for estimating decommissioning activity costs, which simplifies the estimating calculations. Unit factors for concrete removal
($/cubic yard), steel removal ($/ton), and cutting costs ($/inch) were developed using local labor rates. The activity-dependent costs were estimated with the item quantities (cubic yards and tons), developed from plant drawings and inventory documents. Removal rates and material costs for the conventional disposition of components and structures relied upon information available in the industry publication, 2021 "Building Construction Cost Data," published by RSMeans.[27]
The unit factor method provides a demonstrable basis for establishing reliable cost estimates. The detail provided in the unit factors, including activity duration, labor costs (by craft), and equipment and consumable costs, ensures that essential elements have not been omitted. Appendix A presents the detailed development of a typical unit factor. Appendix B provides the values contained within one set of factors developed for this analysis.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 2 of 55 TLG Services, LLC 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 and Fort Calhoun 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 were assigned to each unique set of unit factors, commensurate with the inefficiencies associated with working in confined, hazardous environments.
The ranges used for the WDFs are as follows:
Access Factor 10% to 20%
Respiratory Protection Factor 10% to 50%
Radiation/ALARA Factor 10% to 40%
Protective Clothing Factor 10% to 30%
Work Break Factor 8.33%
The factors and their associated range of values were developed in conjunction with the AIF/NESP-036 study. The application of the factors is discussed in more detail in that publication.
Scheduling Program Durations The unit factors, adjusted by the WDFs as described above, are applied against the inventory of materials to be removed in the radiologically controlled areas.
The resulting man-hours, or crew-hours, are used in the development of the decommissioning program schedule, using resource loading and event sequencing considerations. The scheduling of conventional removal and dismantling activities are based upon productivity information available from the RSMeans "Building Construction Cost Data" publication.
An activity duration critical path is used to determine the total decommissioning program schedule. The schedule is relied upon in calculating the carrying costs, which include program management, administration, field engineering, equipment rental, and support services such as quality control and security. This LR-N24-0040 Attachment 1 Page 31 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 3 of 55 TLG Services, LLC systematic approach for assembling decommissioning estimates ensures a high degree of confidence in the reliability of the resulting cost estimate.
3.3 IMPACT OF DECOMMISSIONING MULTIPLE REACTOR UNITS In estimating the near simultaneous decommissioning of two co-located reactor units there can be opportunities to achieve economies of scale, by sharing costs between units, and coordinating the sequence of work activities. There will also be schedule constraints, particularly where there are requirements for specialty equipment and staff, or practical limitations on when final status surveys can take place. For purposes of the estimate, Units 1 and 2 are assumed to be essentially identical. Common facilities have been assigned to Unit 2. A summary of the principal impacts are listed below.
The sequence of work generally follows the principal that the work is done at Unit 1 first, followed by similar work at Unit 2. This permits the experience gained at Unit 1 to be applied by the workforce at the second unit. It should be noted however, that the estimates do not consider productivity improvements at the second unit, since there is little documented experience with decommissioning two units simultaneously The work associated with developing activity specifications and procedures can be considered essentially identical between the two units, therefore the second unit costs are assumed to be a fraction of the first unit (~ 43%).
Segmenting the reactor vessel and internals will require the use of special equipment. The decommissioning project will be scheduled such that Unit 2s reactor internals and vessel are segmented after the activities at Unit 1 have been completed, thereby enabling sharing of this specialized equipment between the units.
Some program management and support costs, particularly costs associated with the more senior positions, can be avoided with two reactors undergoing decommissioning simultaneously. As a result, the estimate is based on a lead unit that includes these senior positions, and a second unit that excludes these positions. The designation as lead is based on the unit undertaking the most complex tasks (for instance vessel segmentation) or performing tasks for the first time.
The final radiological survey schedule is also affected by a two-unit decommissioning schedule. It would be considered impractical to try to complete the final status survey of Unit 1, while Unit 2 still has ongoing radiological remediation work and waste handling in process. As such, the transfer of the spent fuel from the storage pools and subsequent LR-N24-0040 Attachment 1 Page 32 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 4 of 55 TLG Services, LLC decontamination of the fuel handling buildings is coordinated so as to synchronize the final status survey for the station.
The final demolition of buildings at Units 1 and 2 is considered to take place concurrently. Shared systems and structures are generally assigned to Unit
- 2.
Unit 1, as the first unit to enter decommissioning, incurs the majority of site characterization costs.
Station costs such as emergency response fees, regulatory agency fees, corporate overhead, and insurance are generally allocated on an equal basis between the two units.
3.4 FINANCIAL COMPONENTS OF THE COST MODEL TLGs proprietary decommissioning cost model, DECCER, produces a number of distinct cost elements. These direct expenditures, however, do not comprise the total cost to accomplish the project goal, i.e., license termination and site restoration.
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, consistent with industry practice, a contingency factor has been applied.
In the AIF/NESP-036 study, the types of unforeseeable events that are LR-N24-0040 Attachment 1 Page 33 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 5 of 55 TLG Services, LLC likely to occur in decommissioning are discussed and guidelines are provided for percentage contingency in each category. It should be noted that contingency, as used in this analysis, does not account for price escalation and inflation in the cost of decommissioning over the remaining operating life of the station.
The use and role of contingency within decommissioning estimates is not a safety factor issue. Safety factors provide additional security and address situations that may never occur. Contingency funds are expected to be fully expended throughout the program. They also provide assurance that sufficient funding is available to accomplish the intended tasks. An estimate without contingency, or from which contingency has been removed, can disrupt the orderly progression of events and jeopardize a successful conclusion to the decommissioning process.
For
- example, the most technologically challenging task in decommissioning a commercial nuclear plant is the disposition of the reactor vessel and internal components, now highly radioactive after a lifetime of exposure to core activity. The disposition of these components forms the basis of the critical path (schedule) for decommissioning operations. Cost and schedule are interdependent, and any deviation in schedule has a significant impact on cost for performing a specific activity.
Disposition of the reactor vessel internals involves the underwater cutting of complex components that are highly radioactive. Costs are based upon optimum segmentation, handling, and packaging scenarios. The schedule is primarily dependent upon the turnaround time for the heavily shielded shipping casks, including preparation, loading, and decontamination of the containers for transport. The number of casks required is a function of the pieces generated in the segmentation activity, a value calculated on optimum performance of the tooling employed in cutting the various subassemblies. The expected optimization, however, may not be achieved, resulting in delays and additional program costs. For this reason, contingency must be included to mitigate the consequences of the expected inefficiencies inherent in this complex activity, along with related concerns associated with the operation of highly specialized tooling, field conditions, and water clarity.
Contingency funds are an integral part of the total cost to complete the decommissioning process. Exclusion of this component puts at risk a successful completion of the intended tasks and, potentially, subsequent related activities. For this study, TLG examined the major activity-LR-N24-0040 Attachment 1 Page 34 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 6 of 55 TLG Services, LLC 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%
Spent Fuel Management 15%
Non-Radioactive Component Removal 15%
Heavy Equipment and Tooling 15%
Supplies 25%
Engineering 15%
Energy 15%
Insurance and Fees 10%
Characterization and Termination Surveys 30%
Operations and Maintenance Expense 15%
Construction 15%
Property Taxes 10%
ISFSI Decommissioning 25%
The contingency values are applied to the appropriate components of the estimate on a line item basis. A composite value is then reported at the end of the detailed estimate provided in Appendices C and D. A contingency of 25% is applied to the subtotal of the ISFSI decommissioning costs, reported in Appendix E.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 7 of 55 TLG Services, LLC 3.4.2 Financial Risk In addition to the routine uncertainties addressed by contingency, another cost element that is sometimes necessary to consider when bounding decommissioning costs relates to uncertainty, or risk. Examples can include changes in work scope, pricing, job performance, and other variations that could conceivably, but not necessarily, occur.
Consideration is sometimes necessary to generate a level of confidence in the estimate, within a range of probabilities. TLG considers these types of costs under the broad term financial risk. Included within the category of financial risk are:
Transition activities and costs: ancillary expenses associated with eliminating 50% to 80% of the site labor force shortly after the cessation of plant operations, added cost for worker separation packages throughout the decommissioning program, national or company-mandated retraining, and retention incentives for key personnel.
Delays in approval of the decommissioning plan due to intervention, public participation in local community meetings, legal challenges, and national and local hearings.
Changes in the project work scope from the baseline estimate, involving the discovery of unexpected levels of contaminants, contamination in places not previously expected, contaminated soil previously undiscovered (either radioactive or hazardous material contamination), variations in plant inventory or configuration not indicated by the as-built drawings.
Regulatory changes (e.g., affecting worker health and safety, site release criteria, waste transportation, and disposal).
Policy decisions altering national commitments (e.g., in the ability to accommodate certain waste forms for disposition) or in the timetable for such, for example, the start and rate of acceptance of spent fuel by the DOE.
Pricing changes for basic inputs such as labor, energy, materials, and disposal. Items subject to widespread price competition (such as materials) may not show significant variation; however, others such as waste disposal could exhibit large pricing uncertainties, particularly in markets where limited access to services is available.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 8 of 55 TLG Services, LLC 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 impacts of the considerations identified below are included in this cost study.
3.5.1 Spent Fuel Management The cost to dispose of spent fuel generated from plant operations is not reflected within the estimates to decommission Salem. 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 was financed by a 1 mill/kWhr 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, require 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. PSEGs current spent fuel management plan for Artificial Island assumes just-in-time acceptance, i.e., the DOE will be able to complete the transfer of spent fuel so as not to impede a deferred decommissioning scenario (SAFSTOR) and the termination of the earliest operating license (Salem, Unit 1) within the required 60 year period (from the cessation of operations). To achieve this objective, based upon the oldest fuel receiving the highest priority and an annual maximum rate of transfer of 3,000 metric tons of uranium, DOE would commence pickup of spent fuel from Salem no later than 2038, LR-N24-0040 Attachment 1 Page 37 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 9 of 55 TLG Services, LLC with Salem fuel completely removed from Artificial Island by 2088 (one year prior to the latest assumed start date for the decommissioning of Salem). The current DOE spent fuel acceptance schedule for Artificial Island includes early transfer of Salem fuel which is stored in the respective spent fuel pools and then later transfer of spent fuel from the Site ISFSI to the DOE.
ISFSI An ISFSI has been constructed to support continued plant operations. The ISFSI will continue 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. 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 deferred 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. As a contingency based on DOE history of non-performance, PSEG has included an ISFSI design and the associated costs sufficient to house all spent fuel through the currently defined operating periods for the Salem and Hope Creek Units. Costs are also provided for the final disposition of the facilities once the transfer is complete. Whenever appropriate, costs for maintaining the ISFSI are shared between Salem and the adjacent Hope Creek unit. The sharing on the Salem - Hope Creek site is established by a census split of personnel; Salem pays for 57.0% of the shared ISFSI costs.
Storage Canister Design The Holtec HI-STORM system (with a 32 fuel assembly capacity) is assumed for future cask acquisitions. For fuel transferred directly from the pool to the DOE, for purposes of this estimate only, the DOE was assumed to provide Transport, Aging and Disposal (TAD) canisters with a 21 assembly capacity. DOE has not identified any cask systems it may use.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 10 of 55 TLG Services, LLC Canister Loading and Transfer The estimates include the cost for the labor and equipment to transfer and load each spent fuel canister into the DOE transport cask or to the ISFSI from the wet storage pools. For estimating purposes, an allowance is used to estimate the cost to transfer the fuel from the ISFSI into the DOE transport cask.
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 three and one half years after the cessation of operations. ISFSI operation costs are shared over that time period that both Salem and Hope Creek spent fuel is present on 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, steel and reinforced concrete storage overpack is used as a basis for the cost analyses. The overpack steel is assumed to have some level of neutron-induced activation, as a result of the long-term storage of the fuel, i.e., to levels exceeding free-release limits. As an allowance, 14 overpacks are assumed to require remediation, equivalent to the number of overpacks required to accommodate the final core offload for both Salem units. 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 reported in Appendix E.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 11 of 55 TLG Services, LLC 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 stated that the beneficiaries of the activities resulting in the generation of such radioactive waste bear all reasonable costs of disposing of such waste.[29]
Although the material is not classified as high-level waste, federal regulations under the Act designate that disposal of this material is a federal responsibility under Section 3(b)(1)(D). However, the DOE has not been forthcoming with an acceptance criteria or disposition schedule for this material, and numerous questions remain as to the ultimate disposal cost and waste form requirements.
It is assumed that the DOE would not accept this waste prior to completing the transfer of spent fuel. Therefore, until such time the DOE is ready to accept GTCC waste, it is reasonable to assume that this material would remain in storage at Artificial Island (for the DECON alternative). In the SAFSTOR scenario, the GTCC material is shipped directly to a DOE facility as it is generated, since the fuel has been removed from the site prior to the start of delayed dismantling.
3.5.2 Reactor Vessel and Internal Components The NSSS (reactor vessel and reactor coolant system components) will be decontaminated using chemical agents prior to the start of cutting operations (for DECON alternative only). A decontamination factor (average reduction) of 10 is assumed for the process.
The reactor pressure vessel and internal components are segmented and segregated for disposal based on radionuclide analysis. The higher-acitivity componenents are placed 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 well. Transportation cask specifications and transportation regulations dictate the segmentation and packaging methodology.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 12 of 55 TLG Services, LLC 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 Salem ceases operation. Future viability of this option will depend upon the ultimate location of the disposal site, as well as the disposal site licensees ability to accept highly radioactive packages and effectively isolate them from the environment. Consequently, the study assumes the reactor vessel will require segmentation, as a bounding condition.
3.5.3 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 LR-N24-0040 Attachment 1 Page 41 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 13 of 55 TLG Services, LLC (average reduction) of 10 is assumed for the process. Disposal of the decontamination solution effluent is included within the estimate as a liquid waste processing charge. In the SAFSTOR scenario, radionuclide decay over the dormancy period 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 will be set up for the removal of the generators. It can also be used to move portions of the steam generator cubicle walls and floor slabs from the reactor building to a location where they can be decontaminated and transported to the material handling area.
Interferences within the work area, such as grating, piping and other components, will be removed to create sufficient laydown space for processing these large components.
The generators will be rigged for removal, disconnected from the surrounding piping and supports, and maneuvered into the open area where they will be lowered onto a dolly. Once each steam generator has been placed in the horizontal position, nozzles and other openings will be welded closed. The lower shell will have a carbon steel membrane welded to its outside surface for shielding, if required, during transport. The interior volume will be filled with low-density cellular concrete for stabilization of the internal contamination and to satisfy burial ground packaging requirements. When this stage has been completed, each generator will be moved out of containment and lowered onto a multi-wheeled transporter to be staged at an on-site storage area and await transport to the disposal facility. The pressurizer will be removed using the same technique. The components will then be loaded onto a barge 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 by barge to the disposal facility.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 14 of 55 TLG Services, LLC 3.5.4 Main Turbine and Condenser The main turbine will be dismantled using conventional maintenance procedures. The turbine rotors and shafts will be removed to a laydown area. The lower turbine casings will be removed from their anchors by controlled demolition. The main condensers will also be disassembled and moved to a laydown area. Material is then prepared for transportation to an off-site recycling facility where it will be surveyed and designated for either conventional disposal as scrap metal, decontamination or volume reduction, or controlled disposal. Components will be packaged and readied for transport in accordance with the intended disposition.
3.5.5 Transportation Methods Contaminated piping, components, and structural material other than the highly activated reactor vessel and internal components will qualify as LSA-I, II or III or Surface Contaminated Object, SCO-I or II, as described in Title 49.[30] The contaminated material will be packaged in Industrial Packages (IP-1, IP-2, or IP-3, as defined in subpart 173.411) for transport unless they are demonstrated to qualify as their own shipping containers. The reactor vessel and internal components are expected to be transported in accordance with Part 71, as Type B. It is conceivable that the reactor, due to its limited specific activity, could qualify as LSA II or III. However, the high radiation levels on the outer surface would require that additional shielding be incorporated within the packaging so as to attenuate the dose to levels acceptable for transport.
Any fuel cladding failure that occurred during the lifetime of the plant is assumed to have released fission products at sufficiently low levels that the buildup of quantities of long-lived isotopes (e.g., 137Cs, 90Sr, or transuranics) has been prevented from reaching levels exceeding those that permit the major reactor components to be shipped under current transportation regulations and disposal requirements.
Transport of the highly activated metal, produced in the segmentation of the reactor vessel and internal components, will be by shielded truck cask.
Cask shipments may exceed 95,000 pounds, including vessel segment(s),
supplementary shielding, cask tie-downs, and tractor-trailer. The maximum level of activity per shipment assumed permissible was based upon the license limits of the available shielded transport casks. The LR-N24-0040 Attachment 1 Page 43 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 15 of 55 TLG Services, LLC 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, barge, rail, and/or multi-wheeled transporter. Truck transport costs were estimated using published tariffs from Tri-State Motor Transit.[31] The disposal cost for the GTCC material is assumed to be inclusive of the transportation cost.
3.5.6 Low-Level Radioactive Waste Disposal To the greatest extent practical, metallic material generated in the decontamination and dismantling processes is processed to reduce the total cost of controlled disposal. Material meeting the regulatory and/or site release criterion, is released as scrap, requiring no further cost consideration. Conditioning (preparing the material to meet the waste acceptance criteria of the disposal site) and recovery of the waste stream is performed off site at a licensed processing center. Any material leaving the site is subject to a survey and release charge, at a minimum.
The mass of radioactive waste generated during the various decommissioning activities at the site is shown on a line-item basis in 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, with surcharges added for the special handling requirements and the radiological characteristics of the payload. Packaging efficiencies are lower for the highly activated materials (greater than Type A quantity waste), where high concentrations of gamma-emitting radionuclides limit the capacity of the shipping canisters.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 16 of 55 TLG Services, LLC Disposal fees are calculated using the current disposal agreement for the Atlantic Compact, with surcharges added for the highly activated components, for example, generated in the segmentation of the reactor vessel internals. Low-level radioactive material, or material suspected to be contaminated, is either routed to EnergySolutions facility in Clive, Utah or to a waste processor for conditioning and treatment, including volume reduction and disposal.
Material exceeding Class C limits (limited to material closest to the reactor core and comprising less than 1% of the total waste volume) is generally not suitable for shallow-land disposal. This material is packaged in the same multipurpose canisters used for spent fuel storage/transport.
3.5.7 Site Conditions Following Decommissioning The NRC will amend or terminate the unit licenses 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.
Building codes and environmental regulations will dictate the next step in the decommissioning process, as well as the Owners own future plans for the site, e.g., the electrical switchyard will remain in support of the electrical transmission and distribution system. The new switchyard for AI Transmission line is assumed to remain functional in support of the regional electrical distribution system. The existing shoreline and site access road will be left intact along with the Salem aux guardhouse (NERC/CIP equipment) and the Wind port which will be located north of the cooling tower.
The large underground tunnels between the cooling water intake, turbine building, and discharge structure will be abandoned in place. Site utility and service piping are abandoned in place. Electrical manholes are backfilled with suitable earthen material and abandoned.
The estimate does not assume the remediation of any significant volume of contaminated soil. This assumption may be affected by continued plant operations.
Structures will be removed to a nominal depth of three feet below grade.
Concrete rubble generated from demolition activities will be processed and made available as clean fill. The site will be graded following the LR-N24-0040 Attachment 1 Page 45 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 17 of 55 TLG Services, LLC removal of non-essential structures to conform to the adjacent landscape, and vegetation will be established to inhibit erosion.
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 2021 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 2018 analysis (updated to reflect any material changes to the plant over the past three years).
The study follows the principles of ALARA through the use of work duration adjustment factors. These factors address the impact of activities such as radiological protection instruction, mock-up training, and the use of respiratory protection and protective clothing. The factors lengthen a task's duration, increasing costs and lengthening the overall schedule.
ALARA planning is considered in the costs for engineering and planning, and in the development of activity specifications and detailed procedures.
Changes to worker exposure limits may impact the decommissioning cost and project schedule.
3.6.2 Labor Costs For purposes of this analysis, it is assumed that the Owners will hire a Decommissioning Operations Contractor (DOC) to manage the decommissioning. PSEG 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, neutron activation, and structural analyses) under the direction of PSEG.
Plant personnel labor costs were provided by PSEG. Average costs were provided by department or work group and included payroll overheads.
Decommissioning Operations Contractor (DOC) labor costs were based on LR-N24-0040 Attachment 1 Page 46 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 18 of 55 TLG Services, LLC utility labor costs with modified markups to account for employee benefits, DOC overhead and profit.
The craft labor required to decontaminate and dismantle the nuclear station will be acquired through standard site contracting practices. Craft labor costs were based upon information from PSEG. Craft labor costs include applicable overheads and profit.
A profile of the staffing level for decommissioning, including contractors and craft, is provided in Figures 3.1 and 3.2 for the DECON and SAFSTOR scenarios, respectively. Utility staffing levels will gradually decrease after completing the removal of physical systems at each of the units. 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 delay period and the license termination survey period. However, for the SAFSTOR alternative craft staff levels increase again during the site restoration period due to the work associated with structures demolition.
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). Once the fuel has been transferred to the DOE in 2088, 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 Salem 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.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 19 of 55 TLG Services, LLC The control elements are disposed of along with the spent fuel (i.e., there is no additional cost provided for their disposal).
Neutron activation of the reactor building structure is confined to the biological shield.
3.6.4 General Transition Activities Existing warehouses will be cleared of non-essential material and remain for use by the Owners and its subcontractors. The plants operating staff will perform the following activities at no additional cost or credit to the project during the transition period:
Drain and collect fuel oils, lubricating oils, and transformer oils for recycle and/or sale.
Drain and collect acids, caustics, and other chemical stores for recycle and/or sale.
Processes operating waste inventories, i.e., the estimates do not address the disposition of any legacy wastes; the disposal of operating wastes during this initial period is not considered a decommissioning expense.
Scrap and Salvage The existing plant equipment is considered obsolete and suitable for scrap as deadweight quantities only. The Owners will make economically reasonable efforts to salvage equipment following final plant shutdown.
However, dismantling techniques assumed by TLG for equipment in this analysis are not consistent with removal techniques required for salvage (resale) of equipment. Experience has indicated that some buyers wanted equipment stripped down to very specific requirements before they would consider purchase. This required expensive rework after the equipment had been removed from its installed location. Since placing a salvage value on this machinery and equipment would be speculative, and the value would be small in comparison to the overall decommissioning expenses, this analysis does not attempt to quantify the possible salvage value that the Owners may realize based upon those efforts.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 20 of 55 TLG Services, LLC It is assumed, for purposes of this analysis, that any value received from the sale of scrap generated in the dismantling process would be offset by the on-site processing costs. The dismantling techniques assumed in the decommissioning estimates do not include the additional cost for size reduction and preparation to meet furnace ready conditions. For example, the recovery of copper from electrical cabling may require the removal and disposition of any contaminated insulation, an added expense. With a volatile market, the potential profit margin in scrap recovery is highly speculative, regardless of the ability to free release this material. This assumption is an implicit recognition of scrap value in the disposal of clean metallic waste at no additional cost to the project.
Furniture, tools, mobile equipment such as forklifts, trucks, bulldozers, and other property will be removed at no cost or credit to the decommissioning project. Disposition may include relocation to other facilities. Spare parts will also be made available for alternative use.
The concrete debris resulting from building demolition activities is crushed on site to reduce the size of the debris. The resulting crushed concrete is used to backfill below grade voids. The rebar removed from the concrete crushing process is disposed of as scrap steel in a similar fashion as other scrap metal as discussed previously.
Energy For estimating purposes, the plant is assumed to be de-energized, with the exception of those facilities associated with spent fuel storage.
Replacement power costs are used for the cost of energy consumption during decommissioning for tooling, lighting, ventilation, and essential services.
Emergency Planning FEMA emergency planning fees are included for approximately 18 months after the cessation of plant operations. At that 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 emergency planning fees are included until all fuel has been moved from the pool into dry storage (approximately three and one-half years following the cessation of operations).
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 21 of 55 TLG Services, LLC 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 for all decommissioning periods. PSEG provided a property tax payment for the entire Artificial Island site of
$87,125 (land value only, in 2021 dollars) per year. Approximately 59%
percent of this payment is assigned to Salem and is maintained for the entire decommissioning program.
Site Modifications The perimeter fence and in-plant security barriers will be moved, as appropriate, to conform to the Site Security Plan in force during the various stages of the project.
3.7 COST ESTIMATE
SUMMARY
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).
Additional tables in Appendices C and D provide detailed costs elements. The cost elements are also assigned to one of three subcategories: License Termination, Spent Fuel Management, and Site Restoration. The subcategory License Termination is used to accumulate costs that are consistent with decommissioning as defined by the NRC in its financial assurance regulations (i.e., 10 CFR §50.75). The cost reported for this subcategory is generally sufficient to terminate the each units operating license, recognizing that there may be some additional cost impact from spent fuel management.
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Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 22 of 55 TLG Services, LLC The Spent Fuel Management subcategory contains costs associated with the containerization and transfer of spent fuel from the pools to the DOE or to the ISFSI for interim storage, and the transfer of the multipurpose canisters from the ISFSI to the DOE. Costs are also included for the operations of the pools and management of the ISFSI until such time that the transfer of all fuel from this facility to an off-site location (e.g., interim storage facility) is complete.
Site Restoration is used to capture costs associated with the dismantling and demolition of buildings and facilities demonstrated to be free from contamination. This includes structures never exposed to radioactive materials, as well as those facilities that have been decontaminated to appropriate levels.
Structures are removed to a depth of three feet and backfilled to conform to local grade.
As discussed in Section 3.5.1, 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, included as a License Termination expense.
At the direction of PSEG Nuclear, TLG has assigned the ISFSI license termination and demolition costs as spent fuel management costs. These costs are assumed by PSEG Nuclear to be recoverable from the DOE.
Decommissioning costs are reported in 2021 dollars. Costs are not inflated, escalated, or discounted over the period of expenditure (or projected lifetime of the plant). The schedules are based upon the detailed activity costs reported in Appendices C and D, along with the timelines presented in Section 4.
LR-N24-0040 Attachment 1 Page 51 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 35 of 54 UNIT 1, SAFSTOR ALTERNATIVE TOTAL ANNUAL EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2034 1,990 0
0 0
364 2,354 2035 5,189 0
0 0
949 6,138 2036 25,059 5,121 942 17 4,050 35,189 2037 61,170 20,150 2,439 1,509 22,505 107,774 2038 29,135 26,133 712 514 6,405 62,899 2039 25,344 26,138 488 17 6,192 58,180 2040 6,326 3,319 273 9
5,009 14,935 2041 3,841 350 244 8
4,762 9,205 2042 3,841 350 244 8
1,795 6,237 2043 3,841 350 244 8
1,680 6,122 2044 3,959 675 245 8
1,683 6,569 2045 3,927 609 244 8
1,105 5,892 2046 3,948 674 244 8
1,835 6,709 2047 3,841 350 244 8
1,694 6,136 2048 3,851 351 245 8
1,513 5,968 2049 3,927 609 244 8
1,387 6,175 2050 3,905 544 244 8
1,166 5,867 2051 3,948 674 244 8
1,166 6,039 2052 3,894 481 245 8
1,169 5,796 2053 3,884 480 244 8
1,166 5,781 2054 3,927 609 244 8
1,166 5,953 2055 3,927 609 244 8
1,166 5,953 2056 3,916 545 245 8
1,169 5,882 2057 3,927 609 244 8
1,166 5,953 2058 3,927 609 244 8
1,166 5,953 2059 3,905 544 244 8
1,166 5,867 2060 3,937 610 245 8
1,169 5,968 2061 3,927 609 244 8
1,166 5,953 2062 3,905 544 244 8
1,166 5,867 2063 3,927 609 244 8
1,166 5,953 TABLE 3.3 TLG Services, LLC LR-N24-0040 Attachment 1 Page 52 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 36 of 54 UNIT 1, SAFSTOR ALTERNATIVE TOTAL ANNUAL EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2064 3,937 610 245 8
1,169 5,968 2065 3,905 544 244 8
1,166 5,867 2066 3,927 609 244 8
1,166 5,953 2067 3,927 609 244 8
1,166 5,953 2068 3,916 545 245 8
1,169 5,882 2069 3,927 609 244 8
1,166 5,953 2070 3,927 609 244 8
1,166 5,953 2071 3,905 544 244 8
1,166 5,867 2072 3,937 610 245 8
1,169 5,968 2073 3,927 609 244 8
1,166 5,953 2074 3,905 544 244 8
1,166 5,867 2075 3,927 609 244 8
1,166 5,953 2076 3,937 610 245 8
1,169 5,968 2077 3,905 544 244 8
1,166 5,867 2078 3,927 609 244 8
1,166 5,953 2079 3,927 609 244 8
1,166 5,953 2080 3,916 545 245 8
1,169 5,882 2081 3,927 609 244 8
1,166 5,953 2082 3,927 609 244 8
1,166 5,953 2083 3,905 544 244 8
1,166 5,867 2084 3,937 610 245 8
1,169 5,968 2085 3,927 609 244 8
1,166 5,953 2086 3,905 544 244 8
1,166 5,867 2087 3,927 609 244 8
1,166 5,953 2088 4,024 869 245 8
1,169 6,313 2089 28,242 1,507 1,597 26 1,550 32,922 2090 55,203 9,569 2,426 2,863 4,539 74,599 2091 67,061 27,600 2,317 25,797 23,461 146,236 2092 51,908 13,454 1,983 12,358 12,209 91,912 2093 45,108 7,244 1,829 6,460 7,264 67,904 TABLE 3.3 (continued)
TLG Services, LLC LR-N24-0040 Attachment 1 Page 53 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 37 of 54 UNIT 1, SAFSTOR ALTERNATIVE TOTAL ANNUAL EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2094 38,006 6,096 1,534 5,417 6,330 57,382 2095 5,855 345 67 11 1,547 7,824 2096 28,827 4,146 395 20 1,277 34,665 2097 18,207 8,125 244 0
272 26,847 2098 11,174 4,986 150 0
167 16,476 Total 691,795 191,308 29,109 55,379 167,038 1,134,629 TABLE 3.3 (continued)
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Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 38 of 54 UNIT 1, SAFSTOR ALTERNATIVE LICENSE TERMINATION EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2034 1,990 0
0 0
33 2,023 2035 5,189 0
0 0
86 5,275 2036 23,513 694 942 17 1,781 26,948 2037 56,223 5,641 2,439 1,509 8,974 74,785 2038 8,538 1,073 496 514 5,375 15,996 2039 2,962 498 244 17 5,161 8,882 2040 2,127 350 245 9
3,990 6,721 2041 2,012 330 244 8
3,835 6,429 2042 2,012 330 244 8
868 3,462 2043 2,012 330 244 8
868 3,462 2044 2,018 331 245 8
871 3,472 2045 2,012 330 244 8
868 3,462 2046 2,012 330 244 8
1,093 3,687 2047 2,012 330 244 8
1,093 3,687 2048 2,018 331 245 8
1,022 3,623 2049 2,012 330 244 8
969 3,563 2050 2,012 330 244 8
880 3,474 2051 2,012 330 244 8
880 3,474 2052 2,018 331 245 8
882 3,483 2053 2,012 330 244 8
880 3,474 2054 2,012 330 244 8
880 3,474 2055 2,012 330 244 8
880 3,474 2056 2,018 331 245 8
882 3,483 2057 2,012 330 244 8
880 3,474 2058 2,012 330 244 8
880 3,474 2059 2,012 330 244 8
880 3,474 2060 2,018 331 245 8
882 3,483 2061 2,012 330 244 8
880 3,474 2062 2,012 330 244 8
880 3,474 2063 2,012 330 244 8
880 3,474 TABLE 3.3a TLG Services, LLC LR-N24-0040 Attachment 1 Page 55 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 39 of 54 UNIT 1, SAFSTOR ALTERNATIVE LICENSE TERMINATION EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2064 2,018 331 245 8
882 3,483 2065 2,012 330 244 8
880 3,474 2066 2,012 330 244 8
880 3,474 2067 2,012 330 244 8
880 3,474 2068 2,018 331 245 8
882 3,483 2069 2,012 330 244 8
880 3,474 2070 2,012 330 244 8
880 3,474 2071 2,012 330 244 8
880 3,474 2072 2,018 331 245 8
882 3,483 2073 2,012 330 244 8
880 3,474 2074 2,012 330 244 8
880 3,474 2075 2,012 330 244 8
880 3,474 2076 2,018 331 245 8
882 3,483 2077 2,012 330 244 8
880 3,474 2078 2,012 330 244 8
880 3,474 2079 2,012 330 244 8
880 3,474 2080 2,018 331 245 8
882 3,483 2081 2,012 330 244 8
880 3,474 2082 2,012 330 244 8
880 3,474 2083 2,012 330 244 8
880 3,474 2084 2,018 331 245 8
882 3,483 2085 2,012 330 244 8
880 3,474 2086 2,012 330 244 8
880 3,474 2087 2,012 330 244 8
880 3,474 2088 2,018 331 245 8
882 3,483 2089 27,710 1,507 1,597 26 1,550 32,390 2090*
53,522 9,561 2,426 2,863 4,539 72,911 2091*
65,070 27,527 2,317 25,797 23,461 144,172 2092*
49,036 13,333 1,983 11,875 11,267 87,493 2093 41,864 7,102 1,829 5,769 5,915 62,479 TABLE 3.3a (continued)
TLG Services, LLC LR-N24-0040 Attachment 1 Page 56 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 40 of 54 UNIT 1, SAFSTOR ALTERNATIVE LICENSE TERMINATION EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2094 35,286 5,977 1,534 4,838 5,199 52,834 2095 5,855 345 67 11 1,547 7,824 2096 21,848 1,007 301 20 1,172 24,348 2097 141 0
0 0
0 141 2098 87 0
0 0
0 87 Total 497,619 90,476 28,133 53,626 125,868 795,721 for Disposal of GTCC included in Table 3.3a (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2090 0
0 0
0 965 965 2091 0
0 0
0 8,809 8,809 2092 0
0 0
0 2,679 2,679 Total 0
0 0
0 12,453 12,453
- Schedule of Expenditures TABLE 3.3a (continued)
TLG Services, LLC LR-N24-0040 Attachment 1 Page 57 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 41 of 54 UNIT 1, SAFSTOR ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2034 0
0 0
0 331 331 2035 0
0 0
0 863 863 2036 1,546 4,427 0
0 2,269 8,241 2037 4,948 14,510 0
0 13,532 32,989 2038 20,597 25,060 216 0
1,030 46,903 2039 22,382 25,641 244 0
1,031 49,298 2040 4,198 2,968 28 0
329 7,524 2041 1,828 20 0
0 237 2,085 2042 1,828 20 0
0 237 2,085 2043 1,828 20 0
0 237 2,085 2044 1,941 344 0
0 237 2,522 2045 1,915 279 0
0 237 2,430 2046 1,936 344 0
0 742 3,021 2047 1,828 20 0
0 600 2,449 2048 1,833 20 0
0 492 2,345 2049 1,915 279 0
0 418 2,611 2050 1,893 214 0
0 286 2,393 2051 1,936 344 0
0 286 2,566 2052 1,877 150 0
0 287 2,313 2053 1,871 150 0
0 286 2,307 2054 1,915 279 0
0 286 2,480 2055 1,915 279 0
0 286 2,480 2056 1,898 214 0
0 287 2,399 2057 1,915 279 0
0 286 2,480 2058 1,915 279 0
0 286 2,480 2059 1,893 214 0
0 286 2,393 2060 1,920 279 0
0 287 2,485 2061 1,915 279 0
0 286 2,480 2062 1,893 214 0
0 286 2,393 2063 1,915 279 0
0 286 2,480 TABLE 3.3b TLG Services, LLC LR-N24-0040 Attachment 1 Page 58 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 42 of 54 UNIT 1, SAFSTOR ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2064 1,920 279 0
0 287 2,485 2065 1,893 214 0
0 286 2,393 2066 1,915 279 0
0 286 2,480 2067 1,915 279 0
0 286 2,480 2068 1,898 214 0
0 287 2,399 2069 1,915 279 0
0 286 2,480 2070 1,915 279 0
0 286 2,480 2071 1,893 214 0
0 286 2,393 2072 1,920 279 0
0 287 2,485 2073 1,915 279 0
0 286 2,480 2074 1,893 214 0
0 286 2,393 2075 1,915 279 0
0 286 2,480 2076 1,920 279 0
0 287 2,485 2077 1,893 214 0
0 286 2,393 2078 1,915 279 0
0 286 2,480 2079 1,915 279 0
0 286 2,480 2080 1,898 214 0
0 287 2,399 2081 1,915 279 0
0 286 2,480 2082 1,915 279 0
0 286 2,480 2083 1,893 214 0
0 286 2,393 2084 1,920 279 0
0 287 2,485 2085 1,915 279 0
0 286 2,480 2086 1,893 214 0
0 286 2,393 2087 1,915 279 0
0 286 2,480 2088 2,006 538 0
0 287 2,830 2089 0
0 0
0 0
0 2090 0
0 0
0 0
0 2091 0
0 0
0 0
0 2092 76 55 0
483 943 1,556 2093 108 79 0
691 1,349 2,228 TABLE 3.3b (continued)
TLG Services, LLC LR-N24-0040 Attachment 1 Page 59 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 43 of 54 UNIT 1, SAFSTOR ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2094 91 67 0
579 1,131 1,868 2095 0
0 0
0 0
0 2096 670 213 0
0 95 977 2097 1,733 551 0
0 245 2,529 2098 1,064 338 0
0 150 1,552 Total 148,748 85,422 488 1,753 37,897 274,309 TABLE 3.3b (continued)
TLG Services, LLC LR-N24-0040 Attachment 1 Page 60 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 44 of 54 UNIT 1, SAFSTOR ALTERNATIVE SITE RESTORATION EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2034-39 0
0 0
0 0
0 2040 0
0 0
0 690 690 2041 0
0 0
0 690 690 2042 0
0 0
0 690 690 2043 0
0 0
0 575 575 2044 0
0 0
0 575 575 2045-88 0
0 0
0 0
0 2089 532 0
0 0
0 532 2090 1,680 8
0 0
0 1,688 2091 1,991 73 0
0 0
2,064 2092 2,796 66 0
0 0
2,862 2093 3,136 63 0
0 0
3,198 2094 2,629 52 0
0 0
2,681 2095 0
0 0
0 0
0 2096 6,309 2,926 94 0
10 9,340 2097 16,332 7,574 244 0
27 24,177 2098 10,023 4,648 150 0
16 14,837 Total 45,429 15,410 488 0
3,273 64,599 TABLE 3.3c TLG Services, LLC LR-N24-0040 Attachment 1 Page 61 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 45 of 54 UNIT 2, SAFSTOR ALTERNATIVE TOTAL ANNUAL EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2040 35,953 5,664 1,724 31 7,031 50,403 2041 52,208 24,149 2,038 2,003 21,074 101,473 2042 23,953 28,797 488 17 6,886 60,141 2043 19,825 22,954 438 15 6,331 49,561 2044 3,980 683 245 8
4,630 9,546 2045 3,948 618 244 8
4,052 8,869 2046 3,970 682 244 8
1,815 6,719 2047 3,862 359 244 8
1,674 6,146 2048 3,873 360 245 8
1,493 5,978 2049 3,948 618 244 8
1,367 6,184 2050 3,927 553 244 8
1,146 5,877 2051 3,970 682 244 8
1,146 6,049 2052 3,916 489 245 8
1,149 5,806 2053 3,905 488 244 8
1,146 5,790 2054 3,948 618 244 8
1,146 5,963 2055 3,948 618 244 8
1,146 5,963 2056 3,937 554 245 8
1,149 5,892 2057 3,948 618 244 8
1,146 5,963 2058 3,948 618 244 8
1,146 5,963 2059 3,927 553 244 8
1,146 5,877 2060 3,959 619 245 8
1,149 5,978 2061 3,948 618 244 8
1,146 5,963 2062 3,927 553 244 8
1,146 5,877 2063 3,948 618 244 8
1,146 5,963 2064 3,959 619 245 8
1,149 5,978 2065 3,927 553 244 8
1,146 5,877 2066 3,948 618 244 8
1,146 5,963 2067 3,948 618 244 8
1,146 5,963 2068 3,937 554 245 8
1,149 5,892 2069 3,948 618 244 8
1,146 5,963 TABLE 3.4 TLG Services, LLC LR-N24-0040 Attachment 1 Page 62 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 46 of 54 UNIT 2, SAFSTOR ALTERNATIVE TOTAL ANNUAL EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2070 3,948 618 244 8
1,146 5,963 2071 3,927 553 244 8
1,146 5,877 2072 3,959 619 245 8
1,149 5,978 2073 3,948 618 244 8
1,146 5,963 2074 3,927 553 244 8
1,146 5,877 2075 3,948 618 244 8
1,146 5,963 2076 3,959 619 245 8
1,149 5,978 2077 3,927 553 244 8
1,146 5,877 2078 3,948 618 244 8
1,146 5,963 2079 3,948 618 244 8
1,146 5,963 2080 3,937 554 245 8
1,149 5,892 2081 3,948 618 244 8
1,146 5,963 2082 3,948 618 244 8
1,146 5,963 2083 3,927 553 244 8
1,146 5,877 2084 3,959 619 245 8
1,149 5,978 2085 3,948 618 244 8
1,146 5,963 2086 3,927 553 244 8
1,146 5,877 2087 3,948 618 244 8
1,146 5,963 2088 4,045 877 245 8
1,149 6,323 2089 1,852 329 244 7
762 3,194 2090 23,710 1,743 1,898 28 1,659 29,037 2091 44,705 12,013 2,409 6,411 7,433 72,971 2092 67,003 28,758 2,323 25,958 23,621 147,663 2093 60,843 10,792 1,905 9,307 9,547 92,394 2094 59,737 7,482 1,829 6,238 6,954 82,241 2095 56,397 6,681 1,645 5,388 6,229 76,340 2096 30,045 5,217 395 20 1,588 37,264 2097 21,359 10,897 244 0
1,462 33,962 2098 13,108 6,687 150 0
897 20,842 Total 688,130 198,871 28,713 55,763 161,212 1,132,688 TABLE 3.4 (continued)
TLG Services, LLC LR-N24-0040 Attachment 1 Page 63 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 47 of 54 UNIT 2, SAFSTOR ALTERNATIVE LICENSE TERMINATION EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2040 34,434 1,270 1,724 31 3,162 40,622 2041 43,343 5,883 1,988 2,003 7,965 61,182 2042 1,126 505 244 17 5,165 7,057 2043 1,313 470 244 15 4,888 6,929 2044 2,039 338 245 8
3,818 6,446 2045 2,033 337 244 8
3,815 6,437 2046 2,033 337 244 8
1,098 3,720 2047 2,033 337 244 8
1,098 3,720 2048 2,039 338 245 8
1,018 3,647 2049 2,033 337 244 8
960 3,582 2050 2,033 337 244 8
861 3,482 2051 2,033 337 244 8
861 3,482 2052 2,039 338 245 8
863 3,492 2053 2,033 337 244 8
861 3,482 2054 2,033 337 244 8
861 3,482 2055 2,033 337 244 8
861 3,482 2056 2,039 338 245 8
863 3,492 2057 2,033 337 244 8
861 3,482 2058 2,033 337 244 8
861 3,482 2059 2,033 337 244 8
861 3,482 2060 2,039 338 245 8
863 3,492 2061 2,033 337 244 8
861 3,482 2062 2,033 337 244 8
861 3,482 2063 2,033 337 244 8
861 3,482 2064 2,039 338 245 8
863 3,492 2065 2,033 337 244 8
861 3,482 2066 2,033 337 244 8
861 3,482 2067 2,033 337 244 8
861 3,482 2068 2,039 338 245 8
863 3,492 2069 2,033 337 244 8
861 3,482 TABLE 3.4a TLG Services, LLC LR-N24-0040 Attachment 1 Page 64 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 48 of 54 UNIT 2, SAFSTOR ALTERNATIVE LICENSE TERMINATION EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2070 2,033 337 244 8
861 3,482 2071 2,033 337 244 8
861 3,482 2072 2,039 338 245 8
863 3,492 2073 2,033 337 244 8
861 3,482 2074 2,033 337 244 8
861 3,482 2075 2,033 337 244 8
861 3,482 2076 2,039 338 245 8
863 3,492 2077 2,033 337 244 8
861 3,482 2078 2,033 337 244 8
861 3,482 2079 2,033 337 244 8
861 3,482 2080 2,039 338 245 8
863 3,492 2081 2,033 337 244 8
861 3,482 2082 2,033 337 244 8
861 3,482 2083 2,033 337 244 8
861 3,482 2084 2,039 338 245 8
863 3,492 2085 2,033 337 244 8
861 3,482 2086 2,033 337 244 8
861 3,482 2087 2,033 337 244 8
861 3,482 2088 2,039 338 245 8
863 3,492 2089 1,852 329 244 7
762 3,194 2090 23,432 1,743 1,898 28 1,659 28,759 2091*
43,611 11,995 2,409 6,411 7,433 71,859 2092*
64,893 28,682 2,323 25,958 23,621 145,478 2093*
56,367 10,632 1,905 8,760 8,480 86,144 2094 54,822 7,306 1,829 5,591 5,689 75,237 2095 52,155 6,529 1,645 4,829 5,137 70,296 2096 21,817 1,007 301 20 1,023 24,168 2097 60 0
0 0
0 60 2098 37 0
0 0
0 37 Total 490,817 91,534 27,737 54,010 120,385 784,483 TABLE 3.4a (continued)
TLG Services, LLC LR-N24-0040 Attachment 1 Page 65 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 49 of 54 for Disposal of GTCC included in Table 3.4a (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2091 0
0 0
0 2,231 2,231 2092 0
0 0
0 9,072 9,072 2093 0
0 0
0 1,413 1,413 Total 0
0 0
0 12,716 12,716
- Schedule of Expenditures TLG Services, LLC LR-N24-0040 Attachment 1 Page 66 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 50 of 54 UNIT 2, SAFSTOR ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2040 1,519 4,394 0
0 3,178 9,091 2041 8,864 18,267 50 0
12,419 39,600 2042 22,827 28,292 244 0
1,031 52,394 2043 18,512 22,483 194 0
868 42,057 2044 1,942 345 0
0 237 2,525 2045 1,915 281 0
0 237 2,433 2046 1,937 345 0
0 717 2,999 2047 1,829 22 0
0 575 2,426 2048 1,834 22 0
0 475 2,331 2049 1,915 281 0
0 407 2,602 2050 1,894 216 0
0 285 2,394 2051 1,937 345 0
0 285 2,567 2052 1,877 151 0
0 285 2,314 2053 1,872 151 0
0 285 2,308 2054 1,915 281 0
0 285 2,481 2055 1,915 281 0
0 285 2,481 2056 1,899 216 0
0 285 2,400 2057 1,915 281 0
0 285 2,481 2058 1,915 281 0
0 285 2,481 2059 1,894 216 0
0 285 2,394 2060 1,920 281 0
0 285 2,486 2061 1,915 281 0
0 285 2,481 2062 1,894 216 0
0 285 2,394 2063 1,915 281 0
0 285 2,481 2064 1,920 281 0
0 285 2,486 2065 1,894 216 0
0 285 2,394 2066 1,915 281 0
0 285 2,481 2067 1,915 281 0
0 285 2,481 2068 1,899 216 0
0 285 2,400 2069 1,915 281 0
0 285 2,481 TABLE 3.4b TLG Services, LLC LR-N24-0040 Attachment 1 Page 67 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 51 of 54 UNIT 2, SAFSTOR ALTERNATIVE SPENT FUEL MANAGEMENT EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2070 1,915 281 0
0 285 2,481 2071 1,894 216 0
0 285 2,394 2072 1,920 281 0
0 285 2,486 2073 1,915 281 0
0 285 2,481 2074 1,894 216 0
0 285 2,394 2075 1,915 281 0
0 285 2,481 2076 1,920 281 0
0 285 2,486 2077 1,894 216 0
0 285 2,394 2078 1,915 281 0
0 285 2,481 2079 1,915 281 0
0 285 2,481 2080 1,899 216 0
0 285 2,400 2081 1,915 281 0
0 285 2,481 2082 1,915 281 0
0 285 2,481 2083 1,894 216 0
0 285 2,394 2084 1,920 281 0
0 285 2,486 2085 1,915 281 0
0 285 2,481 2086 1,894 216 0
0 285 2,394 2087 1,915 281 0
0 285 2,481 2088 2,006 539 0
0 285 2,831 2089-92 0
0 0
0 0
0 2093 85 63 0
547 1,067 1,762 2094 101 74 0
648 1,264 2,088 2095 87 64 0
559 1,091 1,802 2096 670 213 0
0 95 977 2097 1,733 551 0
0 245 2,529 2098 1,064 338 0
0 150 1,552 2099 0
0 0
0 0
0 2100 0
0 0
0 0
0 2101 0
0 0
0 0
0 Total 141,339 86,266 488 1,753 35,172 265,019 TABLE 3.4b (continued)
TLG Services, LLC LR-N24-0040 Attachment 1 Page 68 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Page 52 of 54 UNIT 2, SAFSTOR ALTERNATIVE SITE RESTORATION EXPENDITURES (thousands, 2021 Dollars)
Year Labor Equipment
& Materials Energy Burial Other Total 2040 0
0 0
0 690 690 2041 0
0 0
0 690 690 2042 0
0 0
0 690 690 2043 0
0 0
0 575 575 2044 0
0 0
0 575 575 2045-89 0
0 0
0 0
0 2090 278 0
0 0
0 278 2091 1,094 19 0
0 0
1,113 2092 2,110 75 0
0 0
2,185 2093 4,391 97 0
0 0
4,488 2094 4,814 101 0
0 0
4,916 2095 4,155 87 0
0 0
4,242 2096 7,558 3,997 94 0
470 12,119 2097 19,565 10,346 244 0
1,217 31,372 2098 12,007 6,349 150 0
747 19,253 Total 55,973 21,071 488 0
5,654 83,187 TABLE 3.4c TLG Services, LLC LR-N24-0040 Attachment 1 Page 69 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 3, Page 54 of 55 TLG Services, LLC FIGURE 3.2 SAFSTOR SCENARIO SALEM GENERATING STATION MANPOWER LEVELS Note that the labor hour basis of this chart was taken from Appendix D; however not all line items in Appendix D have labor hour values available (e.g. spent fuel canister loading estimates from PSEG)
LR-N24-0040 Attachment 1 Page 70 / 123 600
--Craft
--Utility
--DOC 500
--Security
--Other Staff
--Total 400
~ 300 u..
Year
Salem Generating Station Document P07-1794-002, 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 study follow the sequence presented in the AIF/NESP-036 study, with minor changes to reflect recent experience and site-specific constraints. In addition, the scheduling has been revised to reflect the spent fuel management plans described in Section 3.5.1.
A schedule or sequence of activities for the DECON alternative is presented in Figure 4.1. The schedule is also representative of the work activities identified in the SAFSTOR scenario, absent any spent fuel constraints. The scheduling sequence is based on the fuel being removed from each spent fuel pool within three and one half years of unit shutdown. 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 fuel handling buildings are isolated until such time that all spent fuel has been discharged from the storage pools to the DOE or to the ISFSI.
Decontamination and dismantling of the storage pools are initiated once the transfer of spent fuel is complete (DECON option).
All work (except vessel and internals removal) is performed during an 8-hour workday, 5 days per week, with no overtime. There are eleven paid holidays per year.
Reactor and internals removal activities are performed by using separate crews for different activities working on different shifts, with a corresponding backshift charge for the second shift.
Multiple crews work parallel activities to the maximum extent possible, consistent with optimum efficiency, adequate access for cutting, removal and laydown space, and with the stringent safety measures necessary during demolition of heavy components and structures.
LR-N24-0040 Attachment 1 Page 71 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 4, Page 2 of 7 TLG Services, LLC For plant systems removal, the systems with the longest removal durations in areas on the critical path are considered to determine the duration of the activity.
4.2 PROJECT SCHEDULE The period-dependent costs presented in the detailed cost tables are based upon the durations developed in the schedules for decommissioning Salem. Durations are established between several milestones in each project period; these durations are used to establish a critical path for the entire project. In turn, the critical path duration for each period is used as the basis for determining the period-dependent costs. A second critical path is also shown for the spent fuel cooling period, which determines the release of the reactor buildings for final decontamination.
Project timelines are provided in Figures 4.2 and 4.3, with milestone dates based on the 2036 and 2040 shutdown dates for Units 1 and 2, respectively. The fuel pool at each unit is emptied approximately three and one half years after shutdown, while ISFSI operations continue until the DOE can complete the transfer of assemblies. Deferred decommissioning in the SAFSTOR scenario is assumed to commence so that the operating licenses are terminated within a 60-year period from the cessation of Unit 1 operations.
LR-N24-0040 Attachment 1 Page 72 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 4, Page 3 of 7 TLG Services, LLC FIGURE 4.1 DECON ACTIVITY SCHEDULE LR-N24-0040 Attachment 1 Page 73 / 123 Task Name Salem Unit I & 2 schedule DECON Shutdown Unit I Period l a Unit I
- Shutdown through transition Cortificot o of porm on ont ccesot-ion of ~orations s ubmitted FucJ storage ~ol o~ations 0-ry fuel storage operations Reconfigure plant Prepare activit~
ifications Perform site characterization PSDAR submitted Written certificate of permanent rcmo'lal of fuel submitted Site ___!Eecific_decommissionin~ cost estimate submitted DOC staff mobilized Period lb Unit 1. Decommissioning preparations Fuel storage pool operations Reconfigure plant (continued)
Dry fuel storage operations Prepare detailed work procedures Decon NSSS Isolate spent fuel pool PMloil 2n 1 Jn it. 1
- T.:.rgA r.nmpon,:mt rtm\\OVA I Fuel storage pool operations Dry fuel storage operations Pre aration for reactor vessel removal Reactor vessel & internals Remaining Jar e NSSS com Non-essential systems Main turbine/generator Main condenser License termination Ian submitted sition Period 2b Unit I
- Decontamination (wet fuel)
FucJ storage pool operations
~
1111 1111 * *..
- 11111111
~
'41
'42 '4
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 4, Page 4 of 7 TLG Services, LLC FIGURE 4.1 (continued)
DECON ACTIVITY SCHEDULE LR-N24-0040 Attachment 1 Page 74 / 123 Task Name
- ~ I **a I *~7 I **~ I *~9 I *40 I *41 I '42 I *4~ I *44 I *45 I *4~ I '47 I '4R I *49 Dry fuel storage operations Remove systems not sup_porting wet fuel storage Oecon bui]dings not supporting wet fuel storage License termination plan approved Fuel stora~e pool available for decommissioning Period 2c Unit 1
- Delay before license termina tion I
Unit 2 Operation_!
Shutdown Unit 2 Period In Unit 2
- Shutdown through transition Certificate of permanent cessation of operations s ubmitted Fuel storage pool operations Dry fuel storage operations Reconfigure plant Prepare activit~ifications Perform site characterization
~
PSDAR submitted W_ritten certificate of permanent removal of fuel submitted Site specific decommissionin~ cost estimate submitted DOC staff mobilized Period lb Unit 2
- Decommissioning preparations Fuel storage pool operations Reconfigure plant (continued)
Dry fuel storage operatio~ _
Prepare detailed work procedures Decon NSSS Isolate spent fuel pool Period 2a Unit 2
- Large component removal Fuel storage pool operations Orv fuel storage onerations Preparation for reactor vessel removal Reactor vessel & internals
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 4, Page 5 of 7 TLG Services, LLC FIGURE 4.1 (continued)
DECON ACTIVITY SCHEDULE LEGEND
- 1. Red scheduling bars indicate critical path activities
- 2. Blue scheduling bars associated with major decommissioning periods, e.g., Period 1a, indicate overall duration of that period
- 3. Diamond symbols indicate major milestones LR-N24-0040 Attachment 1 Page 75 / 123 Task Name Remaining large NSSS C01!!.eQ:nents disposition Non.essential systems
?vlain turbine/generator
?vlain condenser License termination P-lan submitted Period 2b Unit 2. De<:ontamination (wet fuel)
Fuc] storage pool operations Dry fuel storage operations Remove systems not ~rting wet fuel storage Decon buildings not supporting wet fuel storage License termination plan approved Period 2f Unit 1 & 2
- Plant license termination Dry fuel storag~eratfons Final ~itc Survey NRC review ~_proval Part 50 license terminated Period 3b Unit I & 2
- Site restoration Ory ti.tel storage operations Building demolitions, backfill and land~ing Building demolition Landscape Site
'41
'42 *4 l* ' '
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 4, Page 7 of 7 TLG Services, LLC FIGURE 4.3 DECOMMISSIONING TIMELINE SAFSTOR (not to scale)
Period 1 SAFSTOR Preparations Aug-2036 Feb-2038 Period 2 Safe-Storage Period 3 Planning Aug-2098 May-2089 Nov-2090 May-2055 ISFSI Operations and Spent Fuel Transfer to DOE Unit 1 Shutdown END May-2055 Unit 2 Shutdown Aug-2098 END Apr-2040 Period 1 Preparations Oct-2041 Period 2 Safe-Storage Apr-2090 Aug-2096 Period 5 Site Restoration Period 5 Site Restoration Period 4 Decommissioning Operations Aug-2096 Period 3 Planning Period 4 Decommissioning Operations Oct-2091 Dec 2088 Unit 1 Fuel Pool Operations Unit 2 Fuel Pool Operations Oct 2043 Feb 2040 LR-N24-0040 Attachment 1 Page 76 / 123
Salem Generating Station Document P07-1794-002, 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 of radioactive waste generated during the various decommissioning activities at the site are shown on a line-item basis in Appendices C and D and summarized in Tables 5.1 and 5.2. The quantified waste volume summaries shown in these tables are consistent with §61 classifications. The volumes are calculated based on the exterior dimensions for containerized material and on the envelope volume of components serving as their own waste containers.
The higher-activity sections of the reactor vessel and internals are categorized as large quantity shipments and, accordingly, will be shipped in reusable, shielded truck casks with disposable liners. In calculating disposal costs, the burial fees are applied against the liner volume, as well as the special handling requirements of the payload.
Packaging efficiencies are lower for the highly activated materials (greater than Type A quantity waste), where high concentrations of gamma-emitting radionuclides limit the capacity of the shipping canisters.
No process system containing/handling radioactive substances at shutdown is presumed to meet material release criteria by decay alone, i.e., systems radioactive at shutdown will still be radioactive over the time period during which the decommissioning is accomplished, due to the presence of long-lived radionuclides.
LR-N24-0040 Attachment 1 Page 77 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 5, Page 2 of 6 TLG Services, LLC While the dose rates decrease with time, radionuclides such as 137Cs will still control the disposition requirements.
The waste material generated in the decontamination and dismantling of Salem is primarily generated during Period 2 of the DECON alternative and Period 4 of SAFSTOR. Material that is considered potentially contaminated when removed from the radiologically controlled area is sent to processing facilities in Tennessee for conditioning and disposal. Heavily contaminated components, contaminated soil-like materials, and activated materials are routed for controlled disposal at either the Barnwell Low-Level Radioactive Waste Management Facility, located in South Carolina or at EnergySolutions facility in Clive, Utah. The disposal volumes reported in the tables reflect the savings resulting from reprocessing and recycling.
Disposal fees are calculated using current disposal agreements, with surcharges added for the highly activated components, for example, generated in the segmentation of the reactor vessel. This material is sent to either an off-site waste processor or to the Barnwell facility for direct disposal, depending upon the level of activity, concentration of radionuclides or identified isotopes.
A small quantity of material will be generated during the Salem decommissioning will not be considered suitable for near-surface disposal, and is assumed to be disposed of in a geologic repository, in a manner similar to that envisioned for spent fuel disposal. Such material, known as Greater-Than-Class-C or GTCC material, is estimated to require ten spent fuel storage canisters (or the equivalent) to dispose of the most radioactive portions of the reactor vessel internals. The volume and weight reported in Tables 5.1 and 5.2 represent the packaged weight and volume of the spent fuel storage canisters.
LR-N24-0040 Attachment 1 Page 78 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 5, Page 3 of 6 TLG Services, LLC FIGURE 5.1 RADIOACTIVE WASTE DISPOSITION Decommissioning Low-Level Radioactive Waste Streams DAW Resins (Class A, B and C)
Containerized Waste Reactor Waste (Classes A, B, and C)
Bulk Waste (Contaminated Soil and Concrete)
Metal Processing EnergySolutions Oak Ridge, TN Barnwell, SC Reactor Waste (Class GTCC)
Geologic Disposal Federal Facility EnergySolutions Clive, Utah LR-N24-0040 Attachment 1 Page 79 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 5, Page 4 of 6 TLG Services, LLC FIGURE 5.2 DECOMMISSIONING WASTE DESTINATIONS RADIOLOGICAL The figure indicates the destinations for the low-level radioactive waste designated for direct disposal (Containerized Classes A, B and C at the Barnwell Low-Level Radioactive Waste Disposal Facility in South Carolina; Bulk waste at EnergySolutions facility in Clive, Utah) and processing/recovery (at EnergySolutions/Oak Ridge).
Salem Generating Station Barnwell, SC Oak Ridge, TN EnergySolutions Clive, UT LR-N24-0040 Attachment 1 Page 80 / 123
Salem Generating Station Document P07-1794-002, 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)
Mass (pounds)
Low-Level Radioactive Waste (near-surface disposal)
Barnwell A
221,140 15,356,274 B
1,002 100,508 C
1,148 142,435 Greater than Class C (geologic repository)
Spent Fuel Equivalent GTCC 4,123 823,283 Processed/Conditioned (off-site recycling center)
Recycling Vendors A
429,569 17,525,302 DAW and Concrete EnergySolutions A
129,007 5,616,337 Total [2]
785,989 39,564,139
[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 LR-N24-0040 Attachment 1 Page 81 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 6, Page 1 of 5 TLG Services, LLC
- 6. RESULTS This report presents estimates of the cost to decommission Salem for the selected decommissioning scenarios following a scheduled cessation of plant operations. The estimates are based on numerous fundamental assumptions, including regulatory requirements, project contingencies, low-level radioactive waste disposal practices, high-level radioactive waste management options, and site restoration requirements.
While not an engineering study, the estimates provide the owner with sufficient information to assess their financial obligations, as they pertain to the eventual decommissioning of the nuclear station.
The estimates described in this report are based on numerous fundamental assumptions, including regulatory requirements, project contingencies, low-level radioactive waste disposal practices, high-level radioactive waste management options, and site restoration requirements. The decommissioning scenarios assume continued operation of each units spent fuel pool for a minimum of three and one-half years following the cessation of operations for continued cooling of the assemblies.
The cost projected to decommission the station using the DECON scenario, restore the site, and manage the spent fuel is estimated to be $1.912 billion (2021 dollars).
The majority of this cost (approximately 66.5%) is associated with the physical decontamination and dismantling of the nuclear plant so that the operating licenses can be terminated. Another 25.5% is associated with the management, interim storage, and eventual transfer of the spent fuel. The remaining 8.0% is for the demolition of the designated structures and limited restoration of the site.
The cost to place the units in safe-storage with decommissioning deferred approximately 50 years (SAFSTOR) is estimated to be $2.267 billion (2021 dollars).
The majority of this cost (approximately 69.7%) is associated with the physical decontamination and dismantling of the nuclear plant so that the operating licenses can be terminated. Another 23.8% 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 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 the site Owners will hire a contractor to LR-N24-0040 Attachment 1 Page 82 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 6, Page 2 of 5 TLG Services, LLC manage the decommissioning labor force. The size and composition of the management organizations varies with the decommissioning phase and associated site activities. However, once the operating licenses are 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).
As described in this report, the spent fuel pools will remain operational for a minimum of three and one half years following the cessation of operations. An allowance is included to reflect modifications to the spent fuel systems to facilitate their independent operations where achievable. This will allow decommissioning operations to proceed in nearby areas that do not impact the spent fuel pools. Over the three-and-one-half-year period, the spent fuel will be packaged into transportable canisters for future loading into a DOE-provided transport cask or relocation to the ISFSI. The canisters will be stored in vertical storage casks at the ISFSI until the DOE is able to receive them. Dry storage of the fuel provides additional flexibility in the event the DOE is not able to meet the current timetable for completing the transfer of assemblies to an off-site facility and minimizes the associated caretaking expenses.
The cost for waste disposal includes only those costs associated with the controlled disposition of the low-level radioactive waste generated from decontamination and dismantling activities, including plant equipment and components, structural material, filters, resins and dry-active waste. As described in Section 5, disposition of the majority of the low-level radioactive material requiring controlled disposal is at the Barnwell 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 LR-N24-0040 Attachment 1 Page 83 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 6, Page 3 of 5 TLG Services, LLC 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 licenses.
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 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.
LR-N24-0040 Attachment 1 Page 84 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 6, Page 5 of 5 TLG Services, LLC TABLE 6.2 SAFSTOR ALTERNATIVE DECOMMISSIONING COST ELEMENTS (thousands of 2021 dollars)
Cost Element Cost Percentage Decontamination 37,152 1.6 Removal 308,667 13.6 Packaging 43,435 1.9 Transportation 32,514 1.4 Waste Disposal 105,233 4.6 Off-site Waste Processing 42,928 1.9 Program Management [1]
814,198 35.9 Severance 29,672 1.3 NEI Fees 18,300 0.8 Security 276,330 12.2 Spent Fuel Pool Equipment Modifications 2,471 0.1 Spent Fuel Storage (Direct Costs) [2]
271,308 12.0 Insurance and Regulatory Fees 127,755 5.6 Energy 57,821 2.6 Characterization and Licensing Surveys 55,105 2.4 Property Taxes 6,185 0.3 Miscellaneous Equipment 38,242 1.7 Total [3]
2,267,317 100.0 Cost Element Cost Percentage NRC License Termination 1,580,204 69.7 Spent Fuel Management [4]
539,327 23.8 Site Restoration 147,786 6.5 Total [3]
2,267,317 100.0
[1]
Includes engineering
[2]
Includes costs for the dry storage system components, spent fuel loading and transfer, spent fuel pool O&M and EP fees
[3]
Columns may not add due to rounding
[4]
Reflects savings in ISFSI operations with the adjacent Hope Creek Generating Station LR-N24-0040 Attachment 1 Page 85 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 7, Page 1 of 4 TLG Services, LLC
- 7. REFERENCES
- 1.
Decommissioning Cost Analysis for the Salem Generating Station, Document No. P07-1756-002, Rev. 1, TLG Services, Inc., December 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.
U.S. Code of Federal Regulations, Title 10, Part 20, Subpart E, Radiological Criteria for License Termination [Open]
- 5.
U.S. Code of Federal Regulations, Title 10, Parts 20 and 50, Entombment Options for Power Reactors, Advance Notice of Proposed Rulemaking, 66 Fed.
Reg. 52551, October 16, 2001 [Open]
- 6.
U.S. Code of Federal Regulations, Title 10, Parts 2, 50 and 51, "Decommissioning of Nuclear Power Reactors," Nuclear Regulatory Commission, 61 Fed. Reg. 39278, July 29, 1996 [Open]
- 7.
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]
- 8.
Nuclear Waste Policy Act of 1982, 42 U.S. Code 10101, et seq. [Open]
- 9.
Nuclear Waste Policy Amendments of 1987, 42 U.S. Code 10172 [Open]
- 10.
Charter of the Blue Ribbon Commission on Americas Nuclear Future, Objectives and Scope of Activities [Open]
- 11.
Blue Ribbon Commission on Americas Nuclear Future, Report to the Secretary of Energy, p. 27, 32, January 2012 [Open]
- 12.
Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste, U.S. DOE, January 11, 2013 [Open]
LR-N24-0040 Attachment 1 Page 86 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 7, Page 2 of 4 TLG Services, LLC
- 7. REFERENCES (continued)
- 13.
United States Court of Appeals for the District of Columbia Circuit, In Re:
Aiken County, Et Al., August 2013 [Open]
- 14.
U.S. Code of Federal Regulations, Title 10, Part 50, Domestic Licensing of Production and Utilization Facilities, Subpart 54 (bb), Conditions of Licenses
[Open]
- 15.
U.S. Code of Federal Regulations, Title 10, Part 72, Subpart K, General License for Storage of Spent Fuel at Power Reactor Sites [Open]
- 16.
Low-Level Radioactive Waste Policy Act, Public Law 96-573, 1980 [Open]
- 17.
Low-Level Radioactive Waste Policy Amendments Act of 1985, Public Law 99-240, January 15, 1986 [Open]
- 18.
U.S. Code of Federal Regulations, Title 10, Part 61, Licensing Requirements for Land Disposal of Radioactive Waste [Open]
- 19.
Final Environmental Impact Statement for the Disposal of Greater-Than-Class C (GTCC) Low-Level Radioactive Waste and GTCC-Like Waste, (DOE/EIS-0375), January 2016 [Open]
- 20.
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]
- 21.
Establishment of Cleanup Levels for CERCLA Sites with Radioactive Contamination, EPA Memorandum OSWER No. 9200.4-18, August 22, 1997
[Open]
- 22.
U.S. Code of Federal Regulations, Title 40, Part 141.66, Maximum contaminant levels for radionuclides [Open]
- 23.
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]
LR-N24-0040 Attachment 1 Page 87 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 7, Page 3 of 4 TLG Services, LLC
- 7. REFERENCES (continued)
- 24.
Multi-Agency Radiation Survey and Site Investigation Manual (MARSSIM),
NUREG-1575, Rev. 1, EPA 402-R-97-016, Rev. 1, August 2000 [Open]
- 25.
T.S. LaGuardia et al., "Guidelines for Producing Commercial Nuclear Power Plant Decommissioning Cost Estimates," AIF/NESP-036, May 1986
- 26.
W.J. Manion and T.S. LaGuardia, "Decommissioning Handbook," U.S.
Department of Energy, DOE/EV/10128-1, November 1980
- 27.
"Building Construction Cost Data 2021," RSMeans (From the Gordian Group),
Kingston, Massachusetts
- 28.
Project and Cost Engineers Handbook, Second Edition, p. 239, American Association of Cost Engineers, Marcel Dekker, Inc., New York, New York, 1984
- 29.
"Strategy for Management and Disposal of Greater-Than-Class C Low-Level Radioactive Waste, Federal Register Volume 60, Number 48 (p 13424 et seq.),
March 1995 [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 4007-E, January 2018
- 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]
LR-N24-0040 Attachment 1 Page 88 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Section 7, Page 4 of 4 TLG Services, LLC
- 7. REFERENCES (continued)
- 35.
SECY-00-0145, Integrated Rulemaking Plan for Nuclear Power Plant Decommissioning, June 2000
- 36.
"Microsoft Project Professional," Microsoft Corporation, Redmond, WA
- 37.
Atomic Energy Act of 1954, (68 Stat. 919) [Open]
LR-N24-0040 Attachment 1 Page 89 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Appendix A, Page 1 of 4 TLG Services, LLC APPENDIX A UNIT COST FACTOR DEVELOPMENT LR-N24-0040 Attachment 1 Page 90 / 123
Salem Generating Station Document P07-1794-002, 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 LR-N24-0040 Attachment 1 Page 91 / 123
Salem Generating Station Document P07-1794-002, 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
$77.84
$2,619.39 Craftsmen 2.00 11.217
$97.97
$2,197.86 Foreman 1.00 11.217
$105.58
$1,184.29 General Foreman 0.25 11.217
$116.85
$327.68 Fire Watch 0.05 11.217
$77.84
$43.66 Health Physics Technician 1.00 11.217
$76.34
$856.31 Total Labor Cost
$7,229.19
- 4.
EQUIPMENT & CONSUMABLES COSTS Equipment Costs none Consumables/Materials Costs Universal Sorbent 50 @ $0.65 sq ft {1}
$32.50 Tarpaulins (oil resistant/fire retardant) 50 @ $0.50/sq ft {2}
$25.00 Gas torch consumables 1 @ $21.65/hr x 1 hr {3}
$21.65 Subtotal cost of equipment and materials
$79.15 Overhead & profit on equipment and materials @ 16.63 %
$13.16 Total costs, equipment & material
$92.31 TOTAL COST:
Removal of contaminated heat exchanger <3000 pounds:
$7,321.50 Total labor cost:
$7,229.19 Total equipment/material costs:
$92.31 Total craft labor man-hours required per unit:
81.88 LR-N24-0040 Attachment 1 Page 92 / 123
Salem Generating Station Document P07-1794-002, 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 (2021) Division 01 56, Section 13.60-0600, page 23
- 3. RSMeans (2021) Division 01 54 33, Section 40-6360, page 744 Material and consumable costs were adjusted using the regional indices for Wilmington, Delaware.
LR-N24-0040 Attachment 1 Page 93 / 123
Salem Generating Station Document P07-1794-002, 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)
LR-N24-0040 Attachment 1 Page 94 / 123
Salem Generating Station Document P07-1794-002, 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 0.86 Removal of clean pipe 0.25 to 2 inches diameter, $/linear foot 9.11 Removal of clean pipe >2 to 4 inches diameter, $/linear foot 12.99 Removal of clean pipe >4 to 8 inches diameter, $/linear foot 25.09 Removal of clean pipe >8 to 14 inches diameter, $/linear foot 48.54 Removal of clean pipe >14 to 20 inches diameter, $/linear foot 63.06 Removal of clean pipe >20 to 36 inches diameter, $/linear foot 92.80 Removal of clean pipe >36 inches diameter, $/linear foot 110.28 Removal of clean valve >2 to 4 inches 168.16 Removal of clean valve >4 to 8 inches 250.92 Removal of clean valve >8 to 14 inches 485.43 Removal of clean valve >14 to 20 inches 630.61 Removal of clean valve >20 to 36 inches 927.97 Removal of clean valve >36 inches 1,102.75 Removal of clean pipe hanger for small bore piping 56.29 Removal of clean pipe hanger for large bore piping 202.61 Removal of clean pump, <300 pound 422.23 Removal of clean pump, 300-1000 pound 1,165.88 Removal of clean pump, 1000-10,000 pound 4,625.12 Removal of clean pump, >10,000 pound 8,941.47 Removal of clean pump motor, 300-1000 pound 489.00 Removal of clean pump motor, 1000-10,000 pound 1,924.17 Removal of clean pump motor, >10,000 pound 4,329.36 Removal of clean heat exchanger <3000 pound 2,487.02 Removal of clean heat exchanger >3000 pound 6,255.71 Removal of clean feedwater heater/deaerator 17,610.52 Removal of clean moisture separator/reheater 36,173.82 Removal of clean tank, <300 gallons 543.26 Removal of clean tank, 300-3000 gallon 1,714.93 Removal of clean tank, >3000 gallons, $/square foot surface area 14.29 LR-N24-0040 Attachment 1 Page 95 / 123
Salem Generating Station Document P07-1794-002, 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 230.18 Removal of clean electrical equipment, 300-1000 pound 796.13 Removal of clean electrical equipment, 1000-10,000 pound 1,592.25 Removal of clean electrical equipment, >10,000 pound 3,794.01 Removal of clean electrical transformer < 30 tons 2,634.90 Removal of clean electrical transformer > 30 tons 7,588.04 Removal of clean standby diesel generator, <100 kW 2,691.32 Removal of clean standby diesel generator, 100 kW to 1 MW 6,007.19 Removal of clean standby diesel generator, >1 MW 12,436.11 Removal of clean electrical cable tray, $/linear foot 21.54 Removal of clean electrical conduit, $/linear foot 9.41 Removal of clean mechanical equipment, <300 pound 230.18 Removal of clean mechanical equipment, 300-1000 pound 796.13 Removal of clean mechanical equipment, 1000-10,000 pound 1,592.25 Removal of clean mechanical equipment, >10,000 pound 3,794.01 Removal of clean HVAC equipment, <300 pound 278.34 Removal of clean HVAC equipment, 300-1000 pound 956.62 Removal of clean HVAC equipment, 1000-10,000 pound 1,906.52 Removal of clean HVAC equipment, >10,000 pound 3,794.01 Removal of clean HVAC ductwork, $/pound 0.90 Removal of contaminated instrument and sampling tubing, $/linear foot 2.57 Removal of contaminated pipe 0.25 to 2 inches diameter, $/linear foot 34.56 Removal of contaminated pipe >2 to 4 inches diameter, $/linear foot 60.73 Removal of contaminated pipe >4 to 8 inches diameter, $/linear foot 95.93 Removal of contaminated pipe >8 to 14 inches diameter, $/linear foot 189.32 Removal of contaminated pipe >14 to 20 inches diameter, $/linear foot 228.06 Removal of contaminated pipe >20 to 36 inches diameter, $/linear foot 316.91 Removal of contaminated pipe >36 inches diameter, $/linear foot 375.17 Removal of contaminated valve >2 to 4 inches 739.12 Removal of contaminated valve >4 to 8 inches 884.72 LR-N24-0040 Attachment 1 Page 96 / 123
Salem Generating Station Document P07-1794-002, 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 1,826.09 Removal of contaminated valve >14 to 20 inches 2,325.22 Removal of contaminated valve >20 to 36 inches 3,102.07 Removal of contaminated valve >36 inches 3,684.68 Removal of contaminated pipe hanger for small bore piping 240.97 Removal of contaminated pipe hanger for large bore piping 799.96 Removal of contaminated pump, <300 pound 1,575.57 Removal of contaminated pump, 300-1000 pound 3,654.20 Removal of contaminated pump, 1000-10,000 pound 12,108.59 Removal of contaminated pump, >10,000 pound 29,497.99 Removal of contaminated pump motor, 300-1000 pound 1,537.46 Removal of contaminated pump motor, 1000-10,000 pound 4,910.07 Removal of contaminated pump motor, >10,000 pound 11,023.59 Removal of contaminated heat exchanger <3000 pound 7,321.50 Removal of contaminated heat exchanger >3000 pound 21,170.06 Removal of contaminated tank, <300 gallons 2,614.61 Removal of contaminated tank, >300 gallons, $/square foot 51.55 Removal of contaminated electrical equipment, <300 pound 1,233.36 Removal of contaminated electrical equipment, 300-1000 pound 2,997.26 Removal of contaminated electrical equipment, 1000-10,000 pound 5,772.11 Removal of contaminated electrical equipment, >10,000 pound 11,359.22 Removal of contaminated electrical cable tray, $/linear foot 59.59 Removal of contaminated electrical conduit, $/linear foot 28.53 Removal of contaminated mechanical equipment, <300 pound 1,372.44 Removal of contaminated mechanical equipment, 300-1000 pound 3,311.31 Removal of contaminated mechanical equipment, 1000-10,000 pound 6,366.53 Removal of contaminated mechanical equipment, >10,000 pound 11,359.22 Removal of contaminated HVAC equipment, <300 pound 1,372.44 Removal of contaminated HVAC equipment, 300-1000 pound 3,311.31 Removal of contaminated HVAC equipment, 1000-10,000 pound 6,366.53 LR-N24-0040 Attachment 1 Page 97 / 123
Salem Generating Station Document P07-1794-002, 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 11,359.22 Removal of contaminated HVAC ductwork, $/pound 3.41 Removal/plasma arc cut of contaminated thin metal components, $/linear in.
6.63 Additional decontamination of surface by washing, $/square foot 13.41 Additional decontamination of surfaces by hydrolasing, $/square foot 58.76 Decontamination rig hook up and flush, $/ 250 foot length 11,596.92 Chemical flush of components/systems, $/gallon 22.28 Removal of clean standard reinforced concrete, $/cubic yard 90.42 Removal of grade slab concrete, $/cubic yard 102.88 Removal of clean concrete floors, $/cubic yard 556.72 Removal of sections of clean concrete floors, $/cubic yard 1,691.02 Removal of clean heavily rein concrete w/#9 rebar, $/cubic yard 130.76 Removal of contaminated heavily rein concrete w/#9 rebar, $/cubic yard 3,419.86 Removal of clean heavily rein concrete w/#18 rebar, $/cubic yard 177.27 Removal of contaminated heavily rein concrete w/#18 rebar, $/cubic yard 4,526.25 Removal heavily rein concrete w/#18 rebar & steel embedments, $/cubic yard 697.97 Removal of below-grade suspended floors, $/cubic yard 248.71 Removal of clean monolithic concrete structures, $/cubic yard 1,451.70 Removal of contaminated monolithic concrete structures, $/cubic yard 3,408.58 Removal of clean foundation concrete, $/cubic yard 1,137.50 Removal of contaminated foundation concrete, $/cubic yard 3,174.87 Explosive demolition of bulk concrete, $/cubic yard 75.83 Removal of clean hollow masonry block wall, $/cubic yard 31.73 Removal of contaminated hollow masonry block wall, $/cubic yard 83.83 Removal of clean solid masonry block wall, $/cubic yard 31.73 Removal of contaminated solid masonry block wall, $/cubic yard 83.83 Backfill of below-grade voids, $/cubic yard 45.62 Removal of subterranean tunnels/voids, $/linear foot 174.08 Placement of concrete for below-grade voids, $/cubic yard 156.04 Excavation of clean material, $/cubic yard 4.00 LR-N24-0040 Attachment 1 Page 98 / 123
Salem Generating Station Document P07-1794-002, 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 59.77 Removal of clean concrete rubble (tipping fee included), $/cubic yard 32.02 Removal of contaminated concrete rubble, $/cubic yard 36.99 Removal of building by volume, $/cubic foot 0.42 Removal of clean building metal siding, $/square foot 2.14 Removal of contaminated building metal siding, $/square foot 7.06 Removal of standard asphalt roofing, $/square foot 4.01 Removal of transite panels, $/square foot 3.52 Scarifying contaminated concrete surfaces (drill & spall), $/square foot 18.82 Scabbling contaminated concrete floors, $/square foot 12.36 Scabbling contaminated concrete walls, $/square foot 33.44 Scabbling contaminated ceilings, $/square foot 115.51 Scabbling structural steel, $/square foot 9.92 Removal of clean overhead crane/monorail < 10 ton capacity 1,108.83 Removal of contaminated overhead crane/monorail < 10 ton capacity 3,047.87 Removal of clean overhead crane/monorail >10-50 ton capacity 2,661.17 Removal of contaminated overhead crane/monorail >10-50 ton capacity 7,313.63 Removal of polar crane > 50 ton capacity 11,154.02 Removal of gantry crane > 50 ton capacity 42,366.53 Removal of structural steel, $/pound 0.31 Removal of clean steel floor grating, $/square foot 7.89 Removal of contaminated steel floor grating, $/square foot 22.42 Removal of clean free standing steel liner, $/square foot 21.42 Removal of contaminated free standing steel liner, $/square foot 60.45 Removal of clean concrete-anchored steel liner, $/square foot 10.71 Removal of contaminated concrete-anchored steel liner, $/square foot 70.45 Placement of scaffolding in clean areas, $/square foot 19.62 Placement of scaffolding in contaminated areas, $/square foot 36.68 Landscaping with topsoil, $/acre 27,759.19 Cost of CPC B-88 LSA box & preparation for use 2,219.99 LR-N24-0040 Attachment 1 Page 99 / 123
Salem Generating Station Document P07-1794-002, 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 1,920.09 Cost of CPC B-12V 12 gauge LSA box & preparation for use 1,746.75 Cost of CPC B-144 LSA box & preparation for use 10,537.79 Cost of LSA drum & preparation for use 290.06 Cost of cask liner for CNSI 8 120A cask (resins) 13,533.00 Cost of cask liner for CNSI 8 120A cask (filters) 9,963.47 Decontamination of surfaces with vacuuming, $/square foot 1.27 LR-N24-0040 Attachment 1 Page 100 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Appendix D, Page 1 of 21 TLG Services, LLC APPENDIX D DETAILED COST ANALYSIS SAFSTOR Tables Page D-1 Salem Generating Station, Unit 1..................................................................... 2 D-2 Salem Generating Station, Unit 2................................................................... 12 LR-N24-0040 Attachment 1 Page 101 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 2 of 21 Table D-1 Salem Generating Station Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:28:51 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 0a - Pre-Shutdown Early Planning Period 0a Direct Decommissioning Activities Period 0a Additional Costs 0a.2.1 Utility Resources 9,024 1,354 10,378 10,378 41,600 0a.2.2 Environmental Report for PSDAR 25 4
29 29 0a.2.3 Emergency Plan Calculations 125 19 144 144 0a.2.4 Security Modifications (planning) 1,500 225 1,725 1,725 0a.2 Subtotal Period 0a Additional Costs 10,674 1,601 12,275 10,550 1,725 41,600 0a.0 TOTAL PERIOD 0a COST 10,674 1,601 12,275 10,550 1,725 41,600 PERIOD 1a - Shutdown through Transition Period 1a Direct Decommissioning Activities 1a.1.1 SAFSTOR site characterization survey 570 171 741 741 1a.1.2 Prepare preliminary decommissioning cost 205 31 235 235 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 315 47 362 362 2,000 1a.1.8 Review plant dwgs & specs.
205 31 235 235 1,300 1a.1.9 Perform detailed rad survey a
1a.1.10 Estimate by-product inventory 157 24 181 181 1,000 1a.1.11 End product description 157 24 181 181 1,000 1a.1.12 Detailed by-product inventory 236 35 271 271 1,500 1a.1.13 Define major work sequence 157 24 181 181 1,000 1a.1.14 Perform SER and EA 488 73 561 561 3,100 1a.1.15 Perform Site-Specific Cost Study 787 118 905 905 5,000 Activity Specifications 1a.1.16.1 Prepare plant and facilities for SAFSTOR 774 116 891 891 4,920 1a.1.16.2 Plant systems 656 98 754 754 4,167 1a.1.16.3 Plant structures and buildings 491 74 565 565 3,120 1a.1.16.4 Waste management 315 47 362 362 2,000 1a.1.16.5 Facility and site dormancy 315 47 362 362 2,000 1a.1.16 Total 2,551 383 2,933 2,933 16,207 Detailed Work Procedures 1a.1.17.1 Plant systems 186 28 214 214 1,183 1a.1.17.2 Facility closeout & dormancy 189 28 217 217 1,200 1a.1.17 Total 375 56 431 431 2,383 1a.1.18 Procure vacuum drying system 16 2
18 18 100 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 6,218 1,018 7,237 7,237 35,890 Period 1a Additional Costs 1a.2.1 Fuel Assembly Modifications 600 90 690 690 1a.2.2 Security Modifications 1,000 150 1,150 1,150 1a.2.3 Prepare and submit PSDAR (credit)
(315)
(47)
(362)
(2,000) 1a.2.4 ISFSI Security Modifications 1,425 214 1,639 1,639 1a.2.5 Prepare/submit Irradiated Fuel Management Plan (Reassigned to SF) 157 24 181 181 1,000 1a.2 Subtotal Period 1a Additional Costs 2,868 430 3,298 3,660 (1,000)
Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 13,286 1,993 15,279 15,279 1a.3.2 Severance 1,583 238 1,821 1,821 1a.3.3 Barnwell Annual Access Fee 500 75 575 575 1a.3 Subtotal Period 1a Collateral Costs 15,370 2,305 17,675 2,396 15,279 Period 1a Period-Dependent Costs 1a.4.1 Insurance 2,025 202 2,227 2,227 1a.4.3 Health physics supplies 614 153 767 767 TLG Services, LLC LR-N24-0040 Attachment 1 Page 102 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 3 of 21 Table D-1 Salem Generating Station Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:28:51 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 Period-Dependent Costs (continued) 1a.4.4 Heavy equipment rental 756 113 869 869 1a.4.5 Disposal of DAW generated 13 4
35 11 64 64 610 12,190 20 1a.4.6 Plant energy budget 2,121 318 2,439 2,439 1a.4.7 NRC Fees 964 96 1,060 1,060 1a.4.8 Spent Fuel Pool O&M 853 128 981 981 1a.4.9 ISFSI Operating Costs 32 5
37 37 1a.4.10 NEI Fees 527 79 606 606 1a.4.11 Security Staff Cost 8,089 1,213 9,302 9,302 127,816 1a.4.12 Utility Staff Cost 31,789 4,768 36,557 36,557 422,240 1a.4 Subtotal Period 1a Period-Dependent Costs 1,370 13 4
35 46,399 7,088 54,910 53,892 1,018 610 12,190 20 550,056 1a.0 TOTAL PERIOD 1a COST 1,370 13 4
35 70,855 10,842 83,119 63,163 19,957 610 12,190 20 584,946 PERIOD 1b - SAFSTOR Limited DECON Activities Period 1b Direct Decommissioning Activities Decontamination of Site Buildings 1b.1.1.1 Reactor Containment 2,131 1,065 3,196 3,196 23,533 1b.1.1.2 Auxiliary Building 685 343 1,028 1,028 7,696 1b.1.1.3 Fuel Handling Building 960 480 1,439 1,439 10,054 1b.1.1 Totals 3,776 1,888 5,663 5,663 41,283 1b.1 Subtotal Period 1b Activity Costs 3,776 1,888 5,663 5,663 41,283 Period 1b Additional Costs 1b.2.1 Spent Fuel Pool Equipment Modifications 1,289 193 1,483 1,483 1b.2.2 ISFSI Expansion 7,481 1,122 8,603 8,603 1b.2.3 Leaking Fuel Characterization 1,544 232 1,776 1,776 1b.2 Subtotal Period 1b Additional Costs 10,315 1,547 11,862 1,483 10,379 Period 1b Collateral Costs 1b.3.1 Decon equipment 1,073 161 1,234 1,234 1b.3.2 Process decommissioning water waste 157 109 151 679 282 1,378 1,378 965 57,920 188 1b.3.4 Small tool allowance 64 10 73 73 1b.3.5 Spent Fuel Capital and Transfer 5,398 810 6,207 6,207 1b.3.6 Severance 643 96 740 740 1b.3.7 Barnwell Annual Access Fee 125 19 143 143 1b.3 Subtotal Period 1b Collateral Costs 1,230 64 109 151 679 6,165 1,377 9,775 3,568 6,207 965 57,920 188 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 973 243 1,217 1,217 1b.4.2 Insurance 505 50 555 555 1b.4.4 Health physics supplies 389 97 486 486 1b.4.5 Heavy equipment rental 189 28 217 217 1b.4.6 Disposal of DAW generated 11 4
31 9
55 55 531 10,613 17 1b.4.7 Plant energy budget 529 79 608 608 1b.4.8 NRC Fees 177 18 195 195 1b.4.9 Spent Fuel Pool O&M 213 32 244 244 1b.4.10 ISFSI Operating Costs 8
1 9
9 1b.4.11 NEI Fees 131 20 151 151 1b.4.12 Security Staff Cost 2,017 302 2,319 2,319 31,866 1b.4.13 Utility Staff Cost 7,925 1,189 9,114 9,114 105,271 1b.4 Subtotal Period 1b Period-Dependent Costs 973 577 11 4
31 11,505 2,070 15,171 14,918 254 531 10,613 17 137,137 1b.0 TOTAL PERIOD 1b COST 5,979 641 120 155 710 27,985 6,882 42,472 25,632 16,840 1,496 68,532 41,488 137,137 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 593 89 682 682 3,000 1c.1.2 Install containment pressure equal. lines 69 10 79 79 700 1c.1.3 Interim survey prior to dormancy 733 220 953 953 9,036 1c.1.4 Secure building accesses a
1c.1.5 Prepare & submit interim report 92 14 106 106 583 1c.1 Subtotal Period 1c Activity Costs 661 825 333 1,819 1,819 12,736 583 TLG Services, LLC LR-N24-0040 Attachment 1 Page 103 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 4 of 21 Table D-1 Salem Generating Station Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:28:51 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 1c.3.1 Process decommissioning water waste 199 139 192 865 359 1,755 1,755 1,230 73,778 240 1c.3.3 Small tool allowance 6
1 7
7 1c.3.4 Spent Fuel Capital and Transfer 6,020 903 6,923 6,923 1c.3.5 Severance 650 98 748 748 1c.3.6 Barnwell Annual Access Fee 126 19 145 145 1c.3 Subtotal Period 1c Collateral Costs 199 6
139 192 865 6,796 1,379 9,577 2,655 6,923 1,230 73,778 240 Period 1c Period-Dependent Costs 1c.4.1 Insurance 277 28 305 305 1c.4.3 Health physics supplies 229 57 286 286 1c.4.4 Heavy equipment rental 191 29 219 219 1c.4.5 Disposal of DAW generated 3
1 9
3 16 16 154 3,073 5
1c.4.6 Plant energy budget 535 80 615 615 1c.4.7 NRC Fees 179 18 197 197 1c.4.8 Spent Fuel Pool O&M 215 32 247 247 1c.4.9 ISFSI Operating Costs 8
1 9
9 1c.4.10 NEI Fees 133 20 153 153 1c.4.11 Security Staff Cost 2,039 306 2,345 2,345 32,217 1c.4.12 Utility Staff Cost 8,013 1,202 9,214 9,214 106,428 1c.4 Subtotal Period 1c Period-Dependent Costs 419 3
1 9
11,398 1,775 13,606 13,349 257 154 3,073 5
138,644 1c.0 TOTAL PERIOD 1c COST 199 1,087 142 194 874 19,019 3,487 25,002 17,823 7,179 1,383 76,851 12,981 139,228 PERIOD 1 TOTALS 6,178 3,098 275 353 1,620 117,858 21,211 150,593 106,618 43,976 3,489 157,574 54,489 861,310 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 10 1
11 11 2a.1.5 Maintenance supplies 295 74 368 368 2a.1 Subtotal Period 2a Activity Costs 304 75 379 379 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 59,456 8,918 68,375 68,375 2a.3.2 Severance 5,156 773 5,929 5,929 2a.3.3 Barnwell Annual Access Fee 999 150 1,149 1,149 2a.3 Subtotal Period 2a Collateral Costs 65,612 9,842 75,453 7,079 68,375 Period 2a Period-Dependent Costs 2a.4.1 Insurance 1,273 127 1,400 1,373 27 2a.4.3 Health physics supplies 493 123 616 616 2a.4.4 Disposal of DAW generated 10 3
27 8
48 48 460 9,203 15 2a.4.5 Plant energy budget 848 127 976 488 488 2a.4.6 NRC Fees 589 59 648 648 2a.4.7 Spent Fuel Pool O&M 1,705 256 1,961 1,961 2a.4.8 ISFSI Operating Costs 65 10 75 75 2a.4.9 NEI Fees 1,054 158 1,212 1,212 2a.4.10 Security Staff Cost 16,178 2,427 18,604 1,451 17,153 255,631 2a.4.11 Utility Staff Cost 13,028 1,954 14,982 4,465 10,518 164,320 2a.4 Subtotal Period 2a Period-Dependent Costs 493 10 3
27 34,740 5,249 40,521 10,301 30,221 460 9,203 15 419,951 2a.0 TOTAL PERIOD 2a COST 493 10 3
27 100,656 15,166 116,354 17,758 98,596 460 9,203 15 419,951 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 235 35 271 271 2b.1.5 Maintenance supplies 7,204 1,801 9,005 9,005 2b.1 Subtotal Period 2b Activity Costs 7,439 1,836 9,276 9,276 Period 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 13,370 2,005 15,375 15,375 2b.3.2 Severance 4,868 730 5,598 5,598 TLG Services, LLC LR-N24-0040 Attachment 1 Page 104 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 5 of 21 Table D-1 Salem Generating Station Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:28:51 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 (continued) 2b.3.3 Emergency Operations Facility 123 18 141 141 2b.3.4 Estuary Program 2,800 420 3,220 3,220 2b.3 Subtotal Period 2b Collateral Costs 21,161 3,174 24,335 5,598 15,517 3,220 Period 2b Period-Dependent Costs 2b.4.1 Insurance 31,131 3,113 34,244 24,485 9,760 2b.4.2 Property taxes 2,580 258 2,838 1,149 1,689 2b.4.3 Health physics supplies 5,589 1,397 6,986 6,986 2b.4.4 Disposal of DAW generated 109 37 295 90 531 531 5,093 101,859 166 2b.4.5 Plant energy budget 10,375 1,556 11,931 11,931 2b.4.6 NRC Fees 13,586 1,359 14,944 14,944 2b.4.7 Emergency Planning Fees 1,269 127 1,396 1,396 2b.4.8 ISFSI Operating Costs 1,587 238 1,826 1,826 2b.4.9 NEI Fees 2,579 387 2,965 2,965 2b.4.10 Security Staff Cost 78,646 11,797 90,443 20,711 69,731 1,171,309 2b.4.11 Utility Staff Cost 84,281 12,642 96,923 77,539 19,385 1,086,105 2b.4 Subtotal Period 2b Period-Dependent Costs 5,589 109 37 295 226,033 32,964 265,027 161,241 103,785 5,093 101,859 166 2,257,414 2b.0 TOTAL PERIOD 2b COST 5,589 109 37 295 254,633 37,975 298,637 176,115 119,302 3,220 5,093 101,859 166 2,257,414 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 2
0 2
2 2c.1.5 Maintenance supplies 56 14 71 71 2c.1 Subtotal Period 2c Activity Costs 58 14 73 73 Period 2c Period-Dependent Costs 2c.4.1 Insurance 138 14 152 152 2c.4.2 Property taxes 10 1
11 11 2c.4.3 Health physics supplies 43 11 54 54 2c.4.4 Disposal of DAW generated 1
0 2
1 4
4 39 781 1
2c.4.5 Plant energy budget 81 12 94 94 2c.4.6 NRC Fees 98 10 107 107 2c.4.7 NEI Fees 20 3
23 23 2c.4.8 Security Staff Cost 404 61 465 465 5,984 2c.4.9 Utility Staff Cost 528 79 608 608 6,981 2c.4 Subtotal Period 2c Period-Dependent Costs 43 1
0 2
1,280 191 1,518 1,518 39 781 1
12,964 2c.0 TOTAL PERIOD 2c COST 43 1
0 2
1,339 206 1,591 1,591 39 781 1
12,964 PERIOD 2 TOTALS 6,124 119 40 324 356,628 53,346 416,582 195,464 217,898 3,220 5,592 111,843 182 2,690,329 PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy Period 3a Direct Decommissioning Activities 3a.1.1 Prepare preliminary decommissioning cost 205 31 235 235 1,300 3a.1.2 Review plant dwgs & specs.
724 109 833 833 4,600 3a.1.3 Perform detailed rad survey a
3a.1.4 End product description 157 24 181 181 1,000 3a.1.5 Detailed by-product inventory 205 31 235 235 1,300 3a.1.6 Define major work sequence 1,180 177 1,357 1,357 7,500 3a.1.7 Perform SER and EA 488 73 561 561 3,100 3a.1.8 Prepare/submit Defueled Technical Specifications 1,180 177 1,357 1,357 7,500 3a.1.9 Perform Site-Specific Cost Study 787 118 905 905 5,000 3a.1.10 Prepare/submit Irradiated Fuel Management Plan 157 24 181 181 1,000 Activity Specifications 3a.1.11.1 Re-activate plant & temporary facilities 1,160 174 1,334 1,201 133 7,370 3a.1.11.2 Plant systems 656 98 754 679 75 4,167 3a.1.11.3 Reactor internals 1,117 168 1,285 1,285 7,100 3a.1.11.4 Reactor vessel 1,023 153 1,176 1,176 6,500 3a.1.11.5 Biological shield 79 12 90 90 500 3a.1.11.6 Steam generators 491 74 565 565 3,120 3a.1.11.7 Reinforced concrete 252 38 290 145 145 1,600 3a.1.11.8 Main Turbine 63 9
72 72 400 TLG Services, LLC LR-N24-0040 Attachment 1 Page 105 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 6 of 21 Table D-1 Salem Generating Station Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:28:51 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 (continued) 3a.1.11.9 Main Condensers 63 9
72 72 400 3a.1.11.10 Plant structures & buildings 491 74 565 282 282 3,120 3a.1.11.11 Waste management 724 109 833 833 4,600 3a.1.11.12 Facility & site closeout 142 21 163 81 81 900 3a.1.11 Total 6,260 939 7,200 6,337 862 39,777 Planning & Site Preparations 3a.1.12 Prepare dismantling sequence 378 57 434 434 2,400 3a.1.13 Plant prep. & temp. svces 3,600 540 4,140 4,140 3a.1.14 Design water clean-up system 220 33 253 253 1,400 3a.1.15 Rigging/Cont. Cntrl Envlps/tooling/etc.
2,400 360 2,760 2,760 3a.1.16 Procure casks/liners & containers 194 29 223 223 1,230 3a.1 Subtotal Period 3a Activity Costs 18,136 2,720 20,856 19,994 862 77,107 Period 3a Additional Costs 3a.2.1 Prepare/submit Defueled Technical Specifications (credit)
(1,180)
(177)
(1,357)
(7,500) 3a.2.2 Prepare/submit Irradiated Fuel Management Plan (credit LT)
(157)
(24)
(181)
(1,000) 3a.2 Subtotal Period 3a Additional Costs (1,338)
(201)
(1,538)
(8,500)
Period 3a Collateral Costs 3a.3.1 Barnwell Annual Access Fee 500 75 575 575 3a.3 Subtotal Period 3a Collateral Costs 500 75 575 575 Period 3a Period-Dependent Costs 3a.4.1 Insurance 361 36 397 397 3a.4.2 Property taxes 26 3
28 28 3a.4.3 Health physics supplies 537 134 671 671 3a.4.4 Heavy equipment rental 756 113 869 869 3a.4.5 Disposal of DAW generated 11 4
30 9
54 54 514 10,287 17 3a.4.6 Plant energy budget 2,121 318 2,439 2,439 3a.4.7 NRC Fees 388 39 427 427 3a.4.8 NEI Fees 527 79 606 606 3a.4.9 Security Staff Cost 2,147 322 2,469 2,469 35,620 3a.4.10 Utility Staff Cost 19,977 2,997 22,974 22,974 257,920 3a.4 Subtotal Period 3a Period-Dependent Costs 1,293 11 4
30 25,547 4,050 30,934 30,934 514 10,287 17 293,540 3a.0 TOTAL PERIOD 3a COST 1,293 11 4
30 42,845 6,645 50,826 49,964 862 514 10,287 17 362,147 PERIOD 3b - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 745 112 857 771 86 4,733 3b.1.1.2 Reactor internals 393 59 452 452 2,500 3b.1.1.3 Remaining buildings 212 32 244 61 183 1,350 3b.1.1.4 CRD cooling assembly 157 24 181 181 1,000 3b.1.1.5 CRD housings & ICI tubes 157 24 181 181 1,000 3b.1.1.6 Incore instrumentation 157 24 181 181 1,000 3b.1.1.7 Reactor vessel 571 86 657 657 3,630 3b.1.1.8 Facility closeout 189 28 217 109 109 1,200 3b.1.1.9 Missile shields 71 11 81 81 450 3b.1.1.10 Biological shield 189 28 217 217 1,200 3b.1.1.11 Steam generators 724 109 833 833 4,600 3b.1.1.12 Reinforced concrete 157 24 181 90 90 1,000 3b.1.1.13 Main Turbine 246 37 282 282 1,560 3b.1.1.14 Main Condensers 246 37 282 282 1,560 3b.1.1.15 Auxiliary building 430 64 494 445 49 2,730 3b.1.1.16 Reactor building 430 64 494 445 49 2,730 3b.1.1 Total 5,075 761 5,836 4,704 1,132 32,243 3b.1 Subtotal Period 3b Activity Costs 5,075 761 5,836 4,704 1,132 32,243 Period 3b Additional Costs 3b.2.1 Site Characterization 3,640 1,092 4,732 4,732 19,100 7,852 3b.2 Subtotal Period 3b Additional Costs 3,640 1,092 4,732 4,732 19,100 7,852 Period 3b Collateral Costs 3b.3.1 Decon equipment 1,073 161 1,234 1,234 3b.3.2 DOC staff relocation expenses 1,565 235 1,800 1,800 TLG Services, LLC LR-N24-0040 Attachment 1 Page 106 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 7 of 21 Table D-1 Salem Generating Station Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:28:51 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 Collateral Costs (continued) 3b.3.3 Pipe cutting equipment 1,200 180 1,380 1,380 3b.3.4 Barnwell Annual Access Fee 253 38 291 291 3b.3 Subtotal Period 3b Collateral Costs 1,073 1,200 1,819 614 4,705 4,705 Period 3b Period-Dependent Costs 3b.4.1 Decon supplies 39 10 48 48 3b.4.2 Insurance 323 32 355 355 3b.4.3 Property taxes 13 1
14 14 3b.4.4 Health physics supplies 300 75 375 375 3b.4.5 Heavy equipment rental 383 57 441 441 3b.4.6 Disposal of DAW generated 6
2 17 5
31 31 295 5,898 10 3b.4.7 Plant energy budget 1,075 161 1,236 1,236 3b.4.8 NRC Fees 197 20 216 216 3b.4.9 NEI Fees 267 40 307 307 3b.4.10 Security Staff Cost 1,088 163 1,251 1,251 18,054 3b.4.11 DOC Staff Cost 6,857 1,029 7,886 7,886 59,038 3b.4.12 Utility Staff Cost 10,125 1,519 11,644 11,644 130,727 3b.4 Subtotal Period 3b Period-Dependent Costs 39 683 6
2 17 19,945 3,112 23,805 23,805 295 5,898 10 207,818 3b.0 TOTAL PERIOD 3b COST 1,112 1,883 6
2 17 30,479 5,579 39,078 37,947 1,132 295 5,898 19,110 247,913 PERIOD 3 TOTALS 1,112 3,176 17 6
47 73,323 12,224 89,905 87,911 1,994 809 16,185 19,126 610,060 PERIOD 4a - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Reactor Coolant Piping 100 426 55 39 182 194 244 1,239 1,239 1,284 1,359 180,354 5,684 4a.1.1.2 Pressurizer Relief Tank 11 42 12 8
39 42 34 187 187 274 290 38,533 604 4a.1.1.3 Reactor Coolant Pumps & Motors 29 147 87 2,756 692 646 4,357 4,357 3,548 984,800 2,392 80 4a.1.1.4 Pressurizer 98 414 749 628 335 2,223 2,223 3,220 274,761 1,346 750 4a.1.1.5 Steam Generators 3,999 777 6,207 10,866 4,725 26,574 26,574 55,722 3,473,898 11,067 2,250 4a.1.1.6 CRDMs/ICIs/Service Structure Removal 54 410 227 32 59 232 224 1,239 1,239 753 2,947 141,134 5,231 4a.1.1.7 Reactor Vessel Internals 76 5,058 11,370 704 3,189 308 8,491 29,196 29,196 3,622 501 574 346,896 24,523 1,139 4a.1.1.8 Vessel & Internals GTCC Disposal 10,829 1,624 12,453 12,453 2,061 411,642 4a.1.1.9 Reactor Vessel 6,622 2,106 463 3,161 308 7,235 19,895 19,895 15,726 995,627 24,523 1,139 4a.1.1 Totals 270 16,800 15,049 10,958 281 29,833 616 23,559 97,364 97,364 2,312 86,435 501 574 2,061 6,847,645 75,370 5,359 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 760 157 54 706 320 1,996 1,996 7,369 331,600 8,301 4a.1.3 Main Condensers 2,592 143 49 642 766 4,191 4,191 6,693 301,200 28,205 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor Containment 676 101 777 777 4,304 4a.1.4.2 Auxiliary Building 146 22 168 168 918 4a.1.4.3 Fuel Handling Building 201 30 231 231 1,309 4a.1.4 Totals 1,023 153 1,176 1,176 6,531 Disposal of Plant Systems 4a.1.5.1 Auxiliary Feedwater 82 12 94 94 892 4a.1.5.2 Auxiliary Feedwater (RCA) 536 7
24 312 185 1,064 1,064 3,611 146,632 5,455 4a.1.5.3 Bleed Steam & Heater Drains 262 39 301 301 2,984 4a.1.5.4 Circulating Water 426 64 489 489 4,757 4a.1.5.5 Condensate Polishing 1,571 19 62 811 526 2,988 2,988 9,372 380,608 16,706 4a.1.5.6 Condenser Air Removal & Priming 236 35 272 272 2,693 4a.1.5.7 Containment Spray 9
1 11 11 104 4a.1.5.8 Containment Spray (RCA) 199 12 39 512 134 896 896 5,918 240,350 2,119 4a.1.5.9 Equipment Vents & Drains - Contaminated 9
0 1
6 1
4 20 20 71 6
3,248 102 4a.1.5.10 Generator Stator Cooling Water 50 8
58 58 568 4a.1.5.11 Heater Vents & Miscellaneous Drains 60 1
2 27 19 109 109 316 12,833 639 4a.1.5.12 Main & Reheat & Turbine By-Pass Steam 1,417 122 404 5,321 1,225 8,489 8,489 61,514 2,498,099 15,763 4a.1.5.13 Main Turbine Lubricating Oil 188 28 216 216 2,099 4a.1.5.14 Miscellaneous Condensate 93 14 107 107 1,051 4a.1.5.15 Moisture Separator Rehtrs Steam & Drains 770 8
26 349 250 1,403 1,403 4,033 163,780 8,163 4a.1.5.16 Steam Gen Drains & Blowdown 323 3
8 109 99 542 542 1,261 51,191 3,398 4a.1.5.17 Steam Gen Drains & Blowdown (RCA) 64 0
1 19 19 104 104 222 9,003 665 4a.1.5.18 Steam Gen Feed Pump & Turbine Lube Oil 54 8
62 62 611 4a.1.5.19 Steam Generator Feed & Condensate 635 95 731 731 7,121 TLG Services, LLC LR-N24-0040 Attachment 1 Page 107 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 8 of 21 Table D-1 Salem Generating Station Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:28:51 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) 4a.1.5.20 Turbine Auxiliaries Cooling 316 47 364 364 3,594 4a.1.5.21 Turbine Drains 63 1
3 39 22 128 128 448 18,213 689 4a.1.5.22 Turbine Electro-Hydraulic Control 7
1 8
8 73 4a.1.5.23 Turbine Gland Sealing Steam & Leak-Off 144 22 165 165 1,654 4a.1.5.24 Waste Disposal - Gas 145 4
13 175 65 402 402 2,022 82,119 1,610 4a.1.5 Totals 7,660 177 583 7,680 1
2,922 19,023 16,145 2,878 88,788 6
3,606,077 83,511 4a.1.6 Scaffolding in support of decommissioning 1,624 13 5
53 6
417 2,117 2,117 550 48 27,807 19,740 4a.1 Subtotal Period 4a Activity Costs 270 30,458 15,539 11,648 9,361 29,840 616 28,137 125,867 122,989 2,878 105,712 86,489 501 574 2,061 11,114,330 221,659 5,359 Period 4a Additional Costs 4a.2.1 Remedial Action Surveys 2,243 673 2,916 2,916 29,386 4a.2 Subtotal Period 4a Additional Costs 2,243 673 2,916 2,916 29,386 Period 4a Collateral Costs 4a.3.1 Process decommissioning water waste 4
8 11 49 17 88 88 69 4,145 13 4a.3.3 Small tool allowance 345 52 397 357 40 4a.3.4 Barnwell Annual Access Fee 707 106 813 813 4a.3 Subtotal Period 4a Collateral Costs 4
345 8
11 49 707 174 1,298 1,258 40 69 4,145 13 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 108 27 135 135 4a.4.2 Insurance 900 90 990 990 4a.4.3 Property taxes 36 4
40 40 4a.4.4 Health physics supplies 2,281 570 2,851 2,851 4a.4.5 Heavy equipment rental 3,554 533 4,087 4,087 4a.4.6 Disposal of DAW generated 86 29 234 71 420 420 4,029 80,580 131 4a.4.7 Plant energy budget 2,848 427 3,275 3,275 4a.4.8 NRC Fees 767 77 844 844 4a.4.9 Liquid Radwaste Processing Equipment/Services 606 91 697 697 4a.4.10 NEI Fees 745 112 857 857 4a.4.11 Security Staff Cost 3,657 549 4,205 4,205 61,750 4a.4.12 DOC Staff Cost 22,657 3,399 26,055 26,055 202,130 4a.4.13 Utility Staff Cost 27,997 4,200 32,196 32,196 362,598 4a.4 Subtotal Period 4a Period-Dependent Costs 108 5,835 86 29 234 60,213 10,148 76,652 76,652 4,029 80,580 131 626,479 4a.0 TOTAL PERIOD 4a COST 382 36,638 15,632 11,687 9,361 30,122 63,778 39,133 206,734 203,816 2,918 105,712 90,587 501 574 2,061 11,199,050 251,190 631,838 PERIOD 4b - Site Decontamination Period 4b Direct Decommissioning Activities 4b.1.1 Remove spent fuel racks 829 93 190 49 562 605 2,329 2,329 4,317 274,241 1,189 Disposal of Plant Systems 4b.1.2.1 Building & Equipment Drains-Conventional 75 11 86 86 850 4b.1.2.2 Chem & Vol Ctrl - Boric Acid Recovery 854 52 47 353 227 335 1,869 1,869 4,083 1,725 276,409 9,340 4b.1.2.3 Chem & Vol Ctrl - Primary Water Recovery 584 34 32 256 144 229 1,278 1,278 2,957 1,099 190,559 6,388 4b.1.2.4 Chem & Vol Ctrl Operation 943 56 31 128 242 326 1,726 1,726 1,480 1,826 178,224 10,014 4b.1.2.5 Component Cooling 30 5
35 35 345 4b.1.2.6 Component Cooling (RCA) 667 25 80 1,050 339 2,161 2,161 12,135 492,793 6,979 4b.1.2.7 Compressed Air 205 31 236 236 2,328 4b.1.2.8 Compressed Air (RCA) 147 1
3 37 43 230 230 428 17,395 1,577 4b.1.2.9 Control Air - Auxiliary Building 239 3
10 136 82 471 471 1,576 63,990 2,685 4b.1.2.10 Control Air - Containment Building 76 1
3 43 26 148 148 493 20,025 861 4b.1.2.11 Control Air - Penetration Area 59 9
68 68 672 4b.1.2.12 Control Air - Turbine Generator Area 85 13 97 97 965 4b.1.2.13 Demineralized Water - Restricted Areas 79 1
2 30 25 137 137 348 14,143 793 4b.1.2.14 Electrical 6,144 922 7,066 7,066 67,956 4b.1.2.15 Electrical (RCA - Clean) 1,118 11 36 477 358 2,000 2,000 5,511 223,814 11,316 4b.1.2.16 Electrical (RCA) 298 4
13 175 103 594 594 2,019 81,988 3,216 4b.1.2.17 Fire Protection 185 28 212 212 2,115 4b.1.2.18 Fire Protection (CO2) 27 4
31 31 305 4b.1.2.19 Fire Protection (RCA) 308 2
8 104 94 517 517 1,201 48,762 3,103 4b.1.2.20 Floor Drains - Contaminated 294 13 7
33 53 94 494 494 377 398 41,195 3,085 4b.1.2.21 HVAC - Auxiliary Building 296 5
16 211 109 636 636 2,440 99,090 3,093 4b.1.2.22 HVAC - Control Area 53 8
61 61 604 4b.1.2.23 HVAC - Diesel Generator Area 13 2
15 15 143 4b.1.2.24 HVAC - Fuel Handling Area 137 2
8 102 51 301 301 1,180 47,922 1,436 TLG Services, LLC LR-N24-0040 Attachment 1 Page 108 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 9 of 21 Table D-1 Salem Generating Station Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:28:51 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.1.2.25 HVAC - Reactor Containment 742 13 42 549 275 1,620 1,620 6,344 257,650 7,692 4b.1.2.26 Heating Water 64 10 74 74 732 4b.1.2.27 Heating Water (RCA) 85 1
2 28 26 143 143 328 13,333 851 4b.1.2.28 Miscellaneous Reactor Coolant 132 1
1 13 2
36 185 185 154 16 7,311 1,482 4b.1.2.29 Residual Heat Removal 269 79 51 227 380 212 1,217 1,217 2,622 2,888 291,977 3,059 4b.1.2.30 Safety Injection 960 64 53 376 276 380 2,107 2,107 4,345 2,094 310,979 10,517 4b.1.2.31 Sampling 198 2
6 85 63 355 355 980 39,800 2,359 4b.1.2.32 Service Water - Nuclear Area 1,604 64 204 2,685 841 5,398 5,398 31,036 1,260,378 17,058 4b.1.2.33 Service Water - Turbine Area 116 17 134 134 1,336 4b.1.2.34 Spent Fuel Cooling 323 33 43 425 125 185 1,135 1,135 4,918 950 260,601 3,502 4b.1.2.35 Waste Disposal - Liquid 594 62 47 301 278 276 1,559 1,559 3,482 2,110 277,017 6,538 4b.1.2 Totals 18,004 530 746 7,823 1,727 5,565 34,395 26,281 8,114 90,437 13,106 4,515,354 195,295 4b.1.3 Scaffolding in support of decommissioning 2,435 19 7
79 9
626 3,176 3,176 824 73 41,711 29,610 Decontamination of Site Buildings 4b.1.4.1 Reactor Containment 1,936 1,160 72 404 123 478 1,464 5,636 5,636 1,419 13,249 699,933 33,150 4b.1.4.2 Auxiliary Building 637 187 11 67 28 77 400 1,407 1,407 323 2,215 118,476 8,949 4b.1.4.3 Fuel Handling Building 866 969 8
26 180 23 712 2,784 2,784 2,076 512 109,847 19,865 4b.1.4 Totals 3,438 2,316 91 498 330 578 2,576 9,827 9,827 3,818 15,976 928,256 61,964 4b.1.5 Prepare/submit License Termination Plan 645 97 741 741 4,096 4b.1.6 Receive NRC approval of termination plan a
4b.1 Subtotal Period 4b Activity Costs 4,268 22,847 831 1,300 8,232 2,877 645 9,469 50,468 42,354 8,114 95,079 33,471 5,759,562 288,058 4,096 Period 4b Additional Costs 4b.2.1 License Termination Survey Planning 1,182 355 1,536 1,536 6,240 4b.2.2 ISFSI License Termination 222 158 437 1,403 2,301 1,130 5,651 5,651 35,660 1,891,180 10,954 3,718 4b.2.3 Remove Underground Utilities 1,384 434 273 2,090 2,090 2,085 4b.2.4 Operational Tools & Equipment 11 32 313 53 410 410 5,880 147,000 16 4b.2.5 Asbestos Abatement 3,014 753 3,767 3,767 26,318 4b.2.6 Remedial Action Surveys 4,026 1,208 5,233 5,233 52,735 4b.2 Subtotal Period 4b Additional Costs 4,620 169 469 313 1,403 7,943 3,772 18,688 13,037 5,651 5,880 35,660 2,038,180 92,107 9,958 Period 4b Collateral Costs 4b.3.1 Process decommissioning water waste 11 20 28 128 44 231 231 181 10,883 35 4b.3.3 Small tool allowance 515 77 592 592 4b.3.4 Decommissioning Equipment Disposition 140 57 575 69 126 967 967 6,000 529 303,608 147 4b.3.5 Barnwell Annual Access Fee 1,268 190 1,459 1,459 4b.3 Subtotal Period 4b Collateral Costs 11 515 160 85 575 197 1,268 437 3,248 3,248 6,000 710 314,491 182 Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 1,148 287 1,435 1,435 4b.4.2 Insurance 1,614 161 1,776 1,776 4b.4.3 Property taxes 65 7
72 72 4b.4.4 Health physics supplies 3,542 885 4,427 4,427 4b.4.5 Heavy equipment rental 6,547 982 7,529 7,529 4b.4.6 Disposal of DAW generated 90 30 244 74 438 438 4,207 84,138 137 4b.4.7 Plant energy budget 4,035 605 4,641 4,641 4b.4.8 NRC Fees 1,376 138 1,514 1,514 4b.4.9 Liquid Radwaste Processing Equipment/Services 1,088 163 1,251 1,251 4b.4.10 NEI Fees 1,337 201 1,538 1,538 4b.4.11 Security Staff Cost 6,563 984 7,547 7,547 110,816 4b.4.12 DOC Staff Cost 26,201 3,930 30,131 30,131 248,016 4b.4.13 Utility Staff Cost 32,669 4,900 37,570 37,570 443,262 4b.4 Subtotal Period 4b Period-Dependent Costs 1,148 10,089 90 30 244 74,949 13,319 99,868 99,868 4,207 84,138 137 802,094 4b.0 TOTAL PERIOD 4b COST 5,427 38,070 1,250 1,884 9,120 4,720 84,804 26,996 172,273 158,507 5,651 8,114 106,959 74,048 8,196,370 380,485 816,147 PERIOD 4e - Delay before License Termination Period 4e Direct Decommissioning Activities Period 4e Collateral Costs 4e.3.1 Barnwell Annual Access Fee 512 77 589 589 4e.3 Subtotal Period 4e Collateral Costs 512 77 589 589 TLG Services, LLC LR-N24-0040 Attachment 1 Page 109 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 10 of 21 Table D-1 Salem Generating Station Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:28:51 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 4e Period-Dependent Costs 4e.4.2 Property taxes 26 3
29 29 4e.4.3 Health physics supplies 113 28 142 142 4e.4.4 Disposal of DAW generated 2
1 6
2 11 11 102 2,043 3
4e.4.6 NRC Fees 261 26 287 287 4e.4.7 NEI Fees 540 81 621 621 4e.4.8 Utility Staff Cost 1,045 157 1,202 1,202 14,919 4e.4 Subtotal Period 4e Period-Dependent Costs 113 2
1 6
1,872 297 2,291 2,291 102 2,043 3
14,919 4e.0 TOTAL PERIOD 4e COST 113 2
1 6
2,385 373 2,880 2,880 102 2,043 3
14,919 PERIOD 4f - License Termination Period 4f Direct Decommissioning Activities 4f.1.1 ORISE confirmatory survey 183 55 238 238 4f.1.2 Terminate license a
4f.1 Subtotal Period 4f Activity Costs 183 55 238 238 Period 4f Additional Costs 4f.2.1 License Termination Survey 9,531 2,859 12,391 12,391 104,253 3,120 4f.2 Subtotal Period 4f Additional Costs 9,531 2,859 12,391 12,391 104,253 3,120 Period 4f Collateral Costs 4f.3.1 DOC staff relocation expenses 1,565 235 1,800 1,800 4f.3.2 Barnwell Annual Access Fee 377 57 433 433 4f.3 Subtotal Period 4f Collateral Costs 1,942 291 2,233 2,233 Period 4f Period-Dependent Costs 4f.4.2 Property taxes 19 2
21 21 4f.4.3 Health physics supplies 723 181 904 904 4f.4.4 Disposal of DAW generated 7
2 19 6
35 35 335 6,698 11 4f.4.5 Plant energy budget 320 48 368 368 4f.4.6 NRC Fees 472 47 519 519 4f.4.7 NEI Fees 397 60 457 457 4f.4.8 Security Staff Cost 744 112 855 855 11,753 4f.4.9 DOC Staff Cost 5,350 803 6,153 6,153 46,622 4f.4.10 Utility Staff Cost 4,799 720 5,519 5,519 56,808 4f.4 Subtotal Period 4f Period-Dependent Costs 723 7
2 19 12,101 1,977 14,830 14,830 335 6,698 11 115,184 4f.0 TOTAL PERIOD 4f COST 723 7
2 19 23,757 5,183 29,693 29,693 335 6,698 104,264 118,304 PERIOD 4 TOTALS 5,809 75,545 16,892 13,575 18,482 34,868 174,724 71,685 411,579 394,896 5,651 11,032 212,671 165,072 501 574 2,061 19,404,160 735,942 1,581,207 PERIOD 5b - Site Restoration Period 5b Direct Decommissioning Activities Demolition of Remaining Site Buildings 5b.1.1.1 Reactor Containment 3,841 576 4,418 4,418 24,505 5b.1.1.2 Auxiliary Building 1,316 197 1,513 1,513 8,262 5b.1.1.3 Auxiliary Building Control Area 322 48 370 370 1,444 5b.1.1.4 Auxiliary Building Diesel Generator Area 134 20 154 154 610 5b.1.1.5 Circulating Water Intake Structure 371 56 426 426 2,469 5b.1.1.6 Condensate Polishing Building 64 10 74 74 396 5b.1.1.7 Main Steam Isolation Structure 237 36 273 273 1,693 5b.1.1.8 Penetration Area 289 43 332 332 1,141 5b.1.1.9 Service Water Intake Structure 240 36 276 276 1,152 5b.1.1.10 Turbine Building 3,283 492 3,775 3,775 29,037 5b.1.1.11 Turbine Pedestal 433 65 498 498 1,943 5b.1.1.12 Fuel Handling Building 1,847 277 2,124 2,124 12,241 5b.1.1 Totals 12,377 1,857 14,234 14,234 84,891 Site Closeout Activities 5b.1.2 Grade & landscape site 416 62 479 479 789 5b.1.3 Final report to NRC 246 37 282 282 1,560 5b.1 Subtotal Period 5b Activity Costs 12,794 246 1,956 14,995 282 14,713 85,680 1,560 Period 5b Additional Costs 5b.2.1 Concrete Crushing 690 5
104 799 799 2,546 5b.2.2 Circulating Water Intake Structure Cofferdam 943 142 1,085 1,085 7,195 TLG Services, LLC LR-N24-0040 Attachment 1 Page 110 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 11 of 21 Table D-1 Salem Generating Station Unit 1 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:28:51 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 Additional Costs (continued) 5b.2.3 Service Water Intake Structure Cofferdam 468 70 538 538 3,449 5b.2.4 ISFSI Demolition and Site Restoration 3,973 426 660 5,059 5,059 37,156 80 5b.2.5 Construction Debris 7
1 8
8 5b.2 Subtotal Period 5b Additional Costs 6,074 438 977 7,489 5,059 2,431 50,346 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 205 31 236 236 5b.3 Subtotal Period 5b Collateral Costs 205 31 236 236 Period 5b Period-Dependent Costs 5b.4.2 Property taxes 36 4
39 39 5b.4.3 Heavy equipment rental 6,799 1,020 7,819 7,819 5b.4.4 Plant energy budget 424 64 488 488 5b.4.5 Security Staff Cost 1,775 266 2,041 2,041 27,560 5b.4.6 DOC Staff Cost 13,148 1,972 15,120 15,120 110,240 5b.4.7 Utility Staff Cost 4,753 713 5,466 5,466 54,080 5b.4 Subtotal Period 5b Period-Dependent Costs 6,799 20,136 4,039 30,974 30,974 191,880 5b.0 TOTAL PERIOD 5b COST 25,873 20,820 7,002 53,695 282 5,059 48,354 136,026 193,520 PERIOD 5 TOTALS 25,873 20,820 7,002 53,695 282 5,059 48,354 136,026 193,520 TOTAL COST TO DECOMMISSION 13,099 113,815 17,303 13,973 18,482 36,859 754,028 167,070 1,134,629 795,721 274,309 64,599 212,671 174,962 501 574 2,061 19,689,770 945,765 5,978,027 TOTAL COST TO DECOMMISSION WITH 17.27% CONTINGENCY:
$1,134,629 thousands of 2021 dollars TOTAL NRC LICENSE TERMINATION COST IS 70.13% OR:
$795,721 thousands of 2021 dollars SPENT FUEL MANAGEMENT COST IS 24.18% OR:
$274,309 thousands of 2021 dollars NON-NUCLEAR DEMOLITION COST IS 5.69% OR:
$64,599 thousands of 2021 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):
176,037 Cubic Feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:
2,061 Cubic Feet TOTAL SCRAP METAL REMOVED:
48,437 Tons TOTAL CRAFT LABOR REQUIREMENTS:
945,765 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 LR-N24-0040 Attachment 1 Page 111 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 12 of 21 Table D-2 Salem Generating Station Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:29:31 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 570 171 741 741 1a.1.2 Prepare preliminary decommissioning cost 88 13 101 101 556 1a.1.3 Notification of Cessation of Operations a
1a.1.4 Remove fuel & source material n/a 1a.1.5 Notification of Permanent Defueling a
1a.1.6 Deactivate plant systems & process waste a
1a.1.7 Prepare and submit PSDAR 135 20 155 155 856 1a.1.8 Review plant dwgs & specs.
88 13 101 101 556 1a.1.9 Perform detailed rad survey a
1a.1.10 Estimate by-product inventory 67 10 77 77 428 1a.1.11 End product description 67 10 77 77 428 1a.1.12 Detailed by-product inventory 101 15 116 116 642 1a.1.13 Define major work sequence 67 10 77 77 428 1a.1.14 Perform SER and EA 209 31 240 240 1,327 1a.1.15 Perform Site-Specific Cost Study 337 51 387 387 2,140 Activity Specifications 1a.1.16.1 Prepare plant and facilities for SAFSTOR 331 50 381 381 2,106 1a.1.16.2 Plant systems 281 42 323 323 1,783 1a.1.16.3 Plant structures and buildings 210 32 242 242 1,335 1a.1.16.4 Waste management 135 20 155 155 856 1a.1.16.5 Facility and site dormancy 135 20 155 155 856 1a.1.16 Total 1,092 164 1,255 1,255 6,936 Detailed Work Procedures 1a.1.17.1 Plant systems 80 12 92 92 506 1a.1.17.2 Facility closeout & dormancy 81 12 93 93 514 1a.1.17 Total 161 24 185 185 1,020 1a.1.18 Procure vacuum drying system 7
1 8
8 43 1a.1.19 Drain/de-energize non-cont. systems a
1a.1.20 Drain & dry NSSS a
1a.1.21 Drain/de-energize contaminated systems a
1a.1.22 Decon/secure contaminated systems a
1a.1 Subtotal Period 1a Activity Costs 2,987 534 3,521 3,521 15,361 Period 1a Additional Costs 1a.2.1 Fuel Assembly Modifications 600 90 690 690 1a.2.2 Security Modifications 1,000 150 1,150 1,150 1a.2.3 Prepare and submit PSDAR (credit)
(135)
(20)
(155)
(856) 1a.2.4 ISFSI Security Modifications 1,425 214 1,639 1,639 1a.2.5 Prepare/submit Irradiated Fuel Management Plan (Reassigned to SF) 67 10 77 77 428 1a.2 Subtotal Period 1a Additional Costs 2,958 444 3,401 3,556 (428)
Period 1a Collateral Costs 1a.3.1 Spent Fuel Capital and Transfer 7,207 1,081 8,288 8,288 1a.3.2 Severance 756 113 870 870 1a.3.3 Barnwell Annual Access Fee 500 75 575 575 1a.3.4 Estuary Program 776 116 892 892 1a.3 Subtotal Period 1a Collateral Costs 9,239 1,386 10,625 1,445 8,288 892 Period 1a Period-Dependent Costs 1a.4.1 Insurance 2,025 202 2,227 2,227 1a.4.3 Health physics supplies 614 153 767 767 1a.4.4 Heavy equipment rental 756 113 869 869 1a.4.5 Disposal of DAW generated 13 4
35 11 64 64 610 12,190 20 1a.4.6 Plant energy budget 2,121 318 2,439 2,439 1a.4.7 NRC Fees 964 96 1,060 1,060 1a.4.8 Spent Fuel Pool O&M 853 128 981 981 1a.4.9 ISFSI Operating Costs 32 5
37 37 1a.4.10 NEI Fees 527 79 606 606 1a.4.11 Security Staff Cost 7,772 1,166 8,938 8,938 123,656 1a.4.12 Utility Staff Cost 31,789 4,768 36,557 36,557 422,240 1a.4 Subtotal Period 1a Period-Dependent Costs 1,370 13 4
35 46,082 7,041 54,546 53,528 1,018 610 12,190 20 545,896 1a.0 TOTAL PERIOD 1a COST 1,370 13 4
35 61,266 9,404 72,093 58,339 12,862 892 610 12,190 20 560,829 TLG Services, LLC LR-N24-0040 Attachment 1 Page 112 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 13 of 21 Table D-2 Salem Generating Station Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:29:31 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 Containment 2,131 1,065 3,196 3,196 23,533 1b.1.1.2 Auxiliary Building 685 343 1,028 1,028 7,696 1b.1.1.3 Controlled Facilities Building 94 47 142 142 1,061 1b.1.1.4 Low Level Radwaste Storage Fac (HC) 30 15 46 46 340 1b.1.1.5 Fuel Handling Building 960 480 1,439 1,439 10,054 1b.1.1 Totals 3,900 1,950 5,851 5,851 42,684 1b.1 Subtotal Period 1b Activity Costs 3,900 1,950 5,851 5,851 42,684 Period 1b Additional Costs 1b.2.1 Spent Fuel Pool Equipment Modifications 860 129 988 988 1b.2.2 ISFSI Expansion 7,481 1,122 8,603 8,603 1b.2.3 Leaking Fuel Characterization 1,544 232 1,776 1,776 1b.2 Subtotal Period 1b Additional Costs 9,885 1,483 11,367 988 10,379 Period 1b Collateral Costs 1b.3.1 Decon equipment 1,073 161 1,234 1,234 1b.3.2 Process decommissioning water waste 158 110 152 683 283 1,386 1,386 971 58,261 189 1b.3.4 Small tool allowance 66 10 76 76 1b.3.5 Spent Fuel Capital and Transfer 6,129 919 7,049 7,049 1b.3.6 Severance 643 96 740 740 1b.3.7 Barnwell Annual Access Fee 125 19 143 143 1b.3.8 Estuary Program 150 22 172 172 1b.3 Subtotal Period 1b Collateral Costs 1,231 66 110 152 683 7,047 1,511 10,799 3,579 7,049 172 971 58,261 189 Period 1b Period-Dependent Costs 1b.4.1 Decon supplies 1,019 255 1,273 1,273 1b.4.2 Insurance 505 50 555 555 1b.4.4 Health physics supplies 397 99 496 496 1b.4.5 Heavy equipment rental 189 28 217 217 1b.4.6 Disposal of DAW generated 12 4
32 10 57 57 550 11,000 18 1b.4.7 Plant energy budget 529 79 608 608 1b.4.8 NRC Fees 177 18 195 195 1b.4.9 Spent Fuel Pool O&M 213 32 244 244 1b.4.10 ISFSI Operating Costs 8
1 9
9 1b.4.11 NEI Fees 131 20 151 151 1b.4.12 Security Staff Cost 1,519 228 1,747 1,747 23,569 1b.4.13 Utility Staff Cost 7,925 1,189 9,114 9,114 105,271 1b.4 Subtotal Period 1b Period-Dependent Costs 1,019 585 12 4
32 11,007 2,009 14,668 14,414 254 550 11,000 18 128,840 1b.0 TOTAL PERIOD 1b COST 6,150 651 121 156 715 27,938 6,953 42,685 24,832 17,681 172 1,521 69,261 42,891 128,840 PERIOD 1c - Preparations for SAFSTOR Dormancy Period 1c Direct Decommissioning Activities 1c.1.1 Prepare support equipment for storage 593 89 682 682 3,000 1c.1.2 Install containment pressure equal. lines 69 10 79 79 700 1c.1.3 Interim survey prior to dormancy 733 220 953 953 9,036 1c.1.4 Secure building accesses a
1c.1.5 Prepare & submit interim report 39 6
45 45 250 1c.1 Subtotal Period 1c Activity Costs 661 772 325 1,759 1,759 12,736 250 Period 1c Collateral Costs 1c.3.1 Process decommissioning water waste 199 139 192 865 359 1,755 1,755 1,230 73,778 240 1c.3.3 Small tool allowance 6
1 7
7 1c.3.4 Spent Fuel Capital and Transfer 6,197 929 7,126 7,126 1c.3.5 Severance 650 98 748 748 1c.3.6 Barnwell Annual Access Fee 126 19 145 145 1c.3.7 Estuary Program 151 23 174 174 1c.3 Subtotal Period 1c Collateral Costs 199 6
139 192 865 7,124 1,428 9,955 2,655 7,126 174 1,230 73,778 240 TLG Services, LLC LR-N24-0040 Attachment 1 Page 113 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 14 of 21 Table D-2 Salem Generating Station Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:29:31 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 277 28 305 305 1c.4.3 Health physics supplies 229 57 286 286 1c.4.4 Heavy equipment rental 191 29 219 219 1c.4.5 Disposal of DAW generated 3
1 9
3 16 16 154 3,073 5
1c.4.6 Plant energy budget 535 80 615 615 1c.4.7 NRC Fees 179 18 197 197 1c.4.8 Spent Fuel Pool O&M 215 32 247 247 1c.4.9 ISFSI Operating Costs 8
1 9
9 1c.4.10 NEI Fees 133 20 153 153 1c.4.11 Security Staff Cost 1,536 230 1,766 1,766 23,828 1c.4.12 Utility Staff Cost 8,013 1,202 9,214 9,214 106,428 1c.4 Subtotal Period 1c Period-Dependent Costs 419 3
1 9
10,895 1,700 13,027 12,770 257 154 3,073 5
130,256 1c.0 TOTAL PERIOD 1c COST 199 1,087 142 194 874 18,791 3,453 24,740 17,184 7,383 174 1,383 76,851 12,981 130,505 PERIOD 1 TOTALS 6,349 3,108 276 354 1,625 107,996 19,810 139,518 100,354 37,926 1,238 3,514 158,302 55,892 820,174 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 65 10 75 75 2a.1.5 Maintenance supplies 295 74 368 368 2a.1 Subtotal Period 2a Activity Costs 360 83 443 443 Period 2a Collateral Costs 2a.3.1 Spent Fuel Capital and Transfer 65,605 9,841 75,446 75,446 2a.3.2 Severance 5,157 774 5,930 5,930 2a.3.3 Barnwell Annual Access Fee 999 150 1,149 1,149 2a.3.4 Estuary Program 1,120 168 1,288 1,288 2a.3 Subtotal Period 2a Collateral Costs 72,881 10,932 83,814 7,080 75,446 1,288 Period 2a Period-Dependent Costs 2a.4.1 Insurance 1,273 127 1,400 1,373 27 2a.4.3 Health physics supplies 493 123 616 616 2a.4.4 Disposal of DAW generated 10 3
27 8
48 48 460 9,203 15 2a.4.5 Plant energy budget 848 127 976 488 488 2a.4.6 NRC Fees 589 59 648 648 2a.4.7 Spent Fuel Pool O&M 1,705 256 1,961 1,961 2a.4.8 ISFSI Operating Costs 65 10 75 75 2a.4.9 NEI Fees 1,054 158 1,212 1,212 2a.4.10 Security Staff Cost 12,184 1,828 14,012 869 13,143 189,071 2a.4.11 Utility Staff Cost 13,028 1,954 14,982 1,333 13,649 164,320 2a.4 Subtotal Period 2a Period-Dependent Costs 493 10 3
27 30,746 4,650 35,929 6,587 29,342 460 9,203 15 353,391 2a.0 TOTAL PERIOD 2a COST 493 10 3
27 103,987 15,666 120,185 14,109 104,788 1,288 460 9,203 15 353,391 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 1,472 221 1,693 1,693 2b.1.5 Maintenance supplies 6,662 1,665 8,327 8,327 2b.1 Subtotal Period 2b Activity Costs 8,134 1,886 10,020 10,020 Period 2b Collateral Costs 2b.3.1 Spent Fuel Capital and Transfer 13,370 2,005 15,375 15,375 2b.3.2 Severance 5,694 854 6,548 6,548 2b.3.3 Emergency Operations Facility 123 18 141 141 2b.3.4 Estuary Program 603 91 694 694 2b.3 Subtotal Period 2b Collateral Costs 19,790 2,969 22,759 6,548 15,517 694 Period 2b Period-Dependent Costs 2b.4.1 Insurance 28,788 2,879 31,667 22,642 9,025 2b.4.2 Property taxes 2,580 258 2,838 1,277 1,561 TLG Services, LLC LR-N24-0040 Attachment 1 Page 114 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 15 of 21 Table D-2 Salem Generating Station Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:29:31 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 Period-Dependent Costs (continued) 2b.4.3 Health physics supplies 5,168 1,292 6,460 6,460 2b.4.4 Disposal of DAW generated 100 34 273 83 491 491 4,710 94,192 154 2b.4.5 Plant energy budget 9,594 1,439 11,033 11,033 2b.4.6 NRC Fees 11,563 1,156 12,719 12,719 2b.4.7 Emergency Planning Fees 1,269 127 1,396 1,396 2b.4.8 ISFSI Operating Costs 1,468 220 1,688 1,688 2b.4.9 NEI Fees 2,384 358 2,742 2,742 2b.4.10 Security Staff Cost 72,726 10,909 83,635 19,152 64,483 1,083,146 2b.4.11 Utility Staff Cost 77,937 11,691 89,628 71,702 17,926 1,004,355 2b.4 Subtotal Period 2b Period-Dependent Costs 5,168 100 34 273 208,310 30,412 244,298 148,219 96,078 4,710 94,192 154 2,087,501 2b.0 TOTAL PERIOD 2b COST 5,168 100 34 273 236,234 35,267 277,076 164,787 111,595 694 4,710 94,192 154 2,087,501 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 41 6
47 47 2c.1.5 Maintenance supplies 184 46 229 229 2c.1 Subtotal Period 2c Activity Costs 224 52 276 276 Period 2c Period-Dependent Costs 2c.4.1 Insurance 450 45 495 495 2c.4.2 Property taxes 32 3
35 35 2c.4.3 Health physics supplies 134 34 168 168 2c.4.4 Disposal of DAW generated 3
1 7
2 12 12 120 2,395 4
2c.4.5 Plant energy budget 264 40 304 304 2c.4.6 NRC Fees 306 31 337 337 2c.4.7 NEI Fees 66 10 76 76 2c.4.8 Security Staff Cost 1,314 197 1,511 1,511 19,447 2c.4.9 Utility Staff Cost 667 100 767 767 10,372 2c.4 Subtotal Period 2c Period-Dependent Costs 134 3
1 7
3,099 461 3,705 3,705 120 2,395 4
29,818 2c.0 TOTAL PERIOD 2c COST 134 3
1 7
3,324 513 3,981 3,981 120 2,395 4
29,818 PERIOD 2 TOTALS 5,795 113 38 307 343,545 51,446 401,243 182,878 216,383 1,982 5,290 105,790 173 2,470,710 PERIOD 3a - Reactivate Site Following SAFSTOR Dormancy Period 3a Direct Decommissioning Activities 3a.1.1 Prepare preliminary decommissioning cost 88 13 101 101 556 3a.1.2 Review plant dwgs & specs.
310 46 356 356 1,969 3a.1.3 Perform detailed rad survey a
3a.1.4 End product description 67 10 77 77 428 3a.1.5 Detailed by-product inventory 88 13 101 101 556 3a.1.6 Define major work sequence 505 76 581 581 3,210 3a.1.7 Perform SER and EA 209 31 240 240 1,327 3a.1.8 Prepare/submit Defueled Technical Specifications 505 76 581 581 3,210 3a.1.9 Perform Site-Specific Cost Study 337 51 387 387 2,140 3a.1.10 Prepare/submit Irradiated Fuel Management Plan 67 10 77 77 428 Activity Specifications 3a.1.11.1 Re-activate plant & temporary facilities 496 74 571 514 57 3,154 3a.1.11.2 Plant systems 281 42 323 291 32 1,783 3a.1.11.3 Reactor internals 478 72 550 550 3,039 3a.1.11.4 Reactor vessel 438 66 504 504 2,782 3a.1.11.5 Biological shield 34 5
39 39 214 3a.1.11.6 Steam generators 210 32 242 242 1,335 3a.1.11.7 Reinforced concrete 108 16 124 62 62 685 3a.1.11.8 Main Turbine 27 4
31 31 171 3a.1.11.9 Main Condensers 27 4
31 31 171 3a.1.11.10 Plant structures & buildings 210 32 242 121 121 1,335 3a.1.11.11 Waste management 310 46 356 356 1,969 3a.1.11.12 Facility & site closeout 61 9
70 35 35 385 3a.1.11 Total 2,679 402 3,081 2,712 369 17,024 TLG Services, LLC LR-N24-0040 Attachment 1 Page 115 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 16 of 21 Table D-2 Salem Generating Station Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:29:31 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 Planning & Site Preparations 3a.1.12 Prepare dismantling sequence 162 24 186 186 1,027 3a.1.13 Plant prep. & temp. svces 3,600 540 4,140 4,140 3a.1.14 Design water clean-up system 94 14 108 108 599 3a.1.15 Rigging/Cont. Cntrl Envlps/tooling/etc.
2,400 360 2,760 2,760 3a.1.16 Procure casks/liners & containers 83 12 95 95 526 3a.1 Subtotal Period 3a Activity Costs 11,194 1,679 12,873 12,504 369 33,002 Period 3a Additional Costs 3a.2.1 Prepare/submit Irradiated Fuel Management Plan (credit LT)
(67)
(10)
(77)
(428) 3a.2.2 Prepare/submit Defueled Technical Specifications (credit)
(505)
(76)
(581)
(3,210) 3a.2 Subtotal Period 3a Additional Costs (573)
(86)
(658)
(3,638)
Period 3a Collateral Costs 3a.3.1 Barnwell Annual Access Fee 500 75 575 575 3a.3 Subtotal Period 3a Collateral Costs 500 75 575 575 Period 3a Period-Dependent Costs 3a.4.1 Insurance 361 36 397 397 3a.4.2 Property taxes 26 3
28 28 3a.4.3 Health physics supplies 509 127 636 636 3a.4.4 Heavy equipment rental 756 113 869 869 3a.4.5 Disposal of DAW generated 10 3
28 9
50 50 481 9,613 16 3a.4.6 Plant energy budget 2,121 318 2,439 2,439 3a.4.7 NRC Fees 311 31 342 342 3a.4.8 NEI Fees 527 79 606 606 3a.4.9 Security Staff Cost 2,147 322 2,469 2,469 35,620 3a.4.10 Utility Staff Cost 14,668 2,200 16,868 16,868 199,680 3a.4 Subtotal Period 3a Period-Dependent Costs 1,265 10 3
28 20,160 3,238 24,705 24,705 481 9,613 16 235,300 3a.0 TOTAL PERIOD 3a COST 1,265 10 3
28 31,281 4,907 37,495 37,126 369 481 9,613 16 264,664 PERIOD 3b - Decommissioning Preparations Period 3b Direct Decommissioning Activities Detailed Work Procedures 3b.1.1.1 Plant systems 319 48 367 330 37 2,026 3b.1.1.2 Reactor internals 168 25 194 194 1,070 3b.1.1.3 Remaining buildings 91 14 105 26 78 578 3b.1.1.4 CRD cooling assembly 67 10 77 77 428 3b.1.1.5 CRD housings & ICI tubes 67 10 77 77 428 3b.1.1.6 Incore instrumentation 67 10 77 77 428 3b.1.1.7 Reactor vessel 245 37 281 281 1,554 3b.1.1.8 Facility closeout 81 12 93 46 46 514 3b.1.1.9 Missile shields 30 5
35 35 193 3b.1.1.10 Biological shield 81 12 93 93 514 3b.1.1.11 Steam generators 310 46 356 356 1,969 3b.1.1.12 Reinforced concrete 67 10 77 39 39 428 3b.1.1.13 Main Turbine 105 16 121 121 668 3b.1.1.14 Main Condensers 105 16 121 121 668 3b.1.1.15 Auxiliary building 184 28 211 190 21 1,168 3b.1.1.16 Reactor building 184 28 211 190 21 1,168 3b.1.1 Total 2,172 326 2,498 2,013 484 13,800 3b.1 Subtotal Period 3b Activity Costs 2,172 326 2,498 2,013 484 13,800 Period 3b Additional Costs 3b.2.1 Site Characterization 1,557 467 2,024 2,024 8,167 3,357 3b.2 Subtotal Period 3b Additional Costs 1,557 467 2,024 2,024 8,167 3,357 Period 3b Collateral Costs 3b.3.1 Decon equipment 1,073 161 1,234 1,234 3b.3.2 DOC staff relocation expenses 1,565 235 1,800 1,800 3b.3.3 Pipe cutting equipment 1,200 180 1,380 1,380 3b.3.4 Barnwell Annual Access Fee 253 38 291 291 3b.3 Subtotal Period 3b Collateral Costs 1,073 1,200 1,819 614 4,705 4,705 Period 3b Period-Dependent Costs 3b.4.1 Decon supplies 39 10 48 48 3b.4.2 Insurance 323 32 355 355 TLG Services, LLC LR-N24-0040 Attachment 1 Page 116 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 17 of 21 Table D-2 Salem Generating Station Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:29:31 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 Period-Dependent Costs (continued) 3b.4.3 Property taxes 13 1
14 14 3b.4.4 Health physics supplies 278 70 348 348 3b.4.5 Heavy equipment rental 383 57 441 441 3b.4.6 Disposal of DAW generated 6
2 16 5
28 28 269 5,373 9
3b.4.7 Plant energy budget 1,075 161 1,236 1,236 3b.4.8 NRC Fees 158 16 173 173 3b.4.9 NEI Fees 267 40 307 307 3b.4.10 Security Staff Cost 1,088 163 1,251 1,251 18,054 3b.4.11 DOC Staff Cost 4,728 709 5,437 5,437 43,224 3b.4.12 Utility Staff Cost 7,434 1,115 8,549 8,549 101,208 3b.4 Subtotal Period 3b Period-Dependent Costs 39 662 6
2 16 15,085 2,380 18,189 18,189 269 5,373 9
162,486 3b.0 TOTAL PERIOD 3b COST 1,112 1,862 6
2 16 20,633 3,786 27,415 26,931 484 269 5,373 8,176 179,643 PERIOD 3 TOTALS 1,112 3,127 16 5
43 51,914 8,693 64,910 64,057 853 749 14,985 8,191 444,307 PERIOD 4a - Large Component Removal Period 4a Direct Decommissioning Activities Nuclear Steam Supply System Removal 4a.1.1.1 Reactor Coolant Piping 100 426 55 39 182 194 244 1,239 1,239 1,284 1,359 180,354 5,684 4a.1.1.2 Pressurizer Relief Tank 11 42 12 8
39 42 34 187 187 274 290 38,533 604 4a.1.1.3 Reactor Coolant Pumps & Motors 29 147 87 2,756 692 646 4,357 4,357 3,548 984,800 2,392 80 4a.1.1.4 Pressurizer 98 414 749 628 335 2,223 2,223 3,220 274,761 1,346 750 4a.1.1.5 Steam Generators 3,999 777 6,207 10,866 4,725 26,574 26,574 55,722 3,473,898 11,067 2,250 4a.1.1.6 CRDMs/ICIs/Service Structure Removal 54 410 227 32 59 232 224 1,239 1,239 753 2,947 141,134 5,231 4a.1.1.7 Reactor Vessel Internals 76 5,045 12,399 704 3,189 306 8,738 30,458 30,458 3,622 501 574 346,896 24,373 1,133 4a.1.1.8 Vessel & Internals GTCC Disposal 11,057 1,659 12,716 12,716 2,061 411,642 4a.1.1.9 Reactor Vessel 6,609 2,087 454 3,103 306 7,190 19,750 19,750 15,440 980,041 24,373 1,133 4a.1.1 Totals 270 16,776 16,058 10,950 281 30,004 613 23,796 98,746 98,746 2,312 86,149 501 574 2,061 6,832,059 75,070 5,347 Removal of Major Equipment 4a.1.2 Main Turbine/Generator 769 157 54 706 322 2,008 2,008 7,369 331,600 8,403 4a.1.3 Main Condensers 2,592 143 49 642 766 4,191 4,191 6,693 301,200 28,205 Cascading Costs from Clean Building Demolition 4a.1.4.1 Reactor Containment 676 101 777 777 4,304 4a.1.4.2 Auxiliary Building 146 22 168 168 918 4a.1.4.3 Low Level Radwaste Storage Fac (HC) 4 1
4 4
19 4a.1.4.4 Fuel Handling Building 201 30 231 231 1,309 4a.1.4 Totals 1,026 154 1,180 1,180 6,550 Disposal of Plant Systems 4a.1.5.1 Auxiliary Feedwater 82 12 94 94 892 4a.1.5.2 Auxiliary Feedwater (RCA) 536 7
24 312 185 1,064 1,064 3,611 146,632 5,455 4a.1.5.3 Bleed Steam & Heater Drains 262 39 301 301 2,984 4a.1.5.4 Circulating Water 426 64 489 489 4,757 4a.1.5.5 Circulating Water Sampling 9
1 11 11 104 4a.1.5.6 Condensate Polishing 1,571 19 62 811 526 2,988 2,988 9,372 380,608 16,706 4a.1.5.7 Condenser Air Removal & Priming 236 35 272 272 2,693 4a.1.5.8 Containment Spray 9
1 11 11 104 4a.1.5.9 Containment Spray (RCA) 199 12 39 512 134 896 896 5,918 240,350 2,119 4a.1.5.10 Equipment Vents & Drains - Contaminated 9
0 1
6 1
4 20 20 71 6
3,248 102 4a.1.5.11 Feedwater Chemical Treatment 16 2
19 19 182 4a.1.5.12 Generator Stator Cooling Water 50 8
58 58 568 4a.1.5.13 Heater Vents & Miscellaneous Drains 60 1
2 27 19 109 109 316 12,833 639 4a.1.5.14 Hydrogen & Carbon Dioxide 21 3
24 24 235 4a.1.5.15 Main & Reheat & Turbine By-Pass Steam 1,417 122 404 5,321 1,225 8,489 8,489 61,514 2,498,099 15,763 4a.1.5.16 Main Turbine Lubricating Oil 188 28 216 216 2,099 4a.1.5.17 Miscellaneous Condensate 93 14 107 107 1,051 4a.1.5.18 Moisture Separator Rehtrs Steam & Drains 770 8
26 349 250 1,403 1,403 4,033 163,780 8,163 4a.1.5.19 Oil Water Separator 81 12 93 93 907 4a.1.5.20 Steam Gen Drains & Blowdown 323 3
8 109 99 542 542 1,261 51,191 3,398 4a.1.5.21 Steam Gen Drains & Blowdown (RCA) 64 0
1 19 19 104 104 222 9,003 665 4a.1.5.22 Steam Gen Feed Pump & Turbine Lube Oil 54 8
62 62 611 4a.1.5.23 Steam Generator Feed & Condensate 633 95 728 728 7,097 4a.1.5.24 Turbine Auxiliaries Cooling 316 47 364 364 3,594 4a.1.5.25 Turbine Drains 63 1
3 39 22 128 128 448 18,213 689 TLG Services, LLC LR-N24-0040 Attachment 1 Page 117 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 18 of 21 Table D-2 Salem Generating Station Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:29:31 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) 4a.1.5.26 Turbine Electro-Hydraulic Control 7
1 8
8 73 4a.1.5.27 Turbine Gland Sealing Steam & Leak-Off 144 22 165 165 1,654 4a.1.5.28 Waste Disposal - Gas 145 4
13 175 65 402 402 2,022 82,119 1,610 4a.1.5 Totals 7,785 177 583 7,680 1
2,941 19,167 16,145 3,023 88,788 6
3,606,077 84,916 4a.1.6 Scaffolding in support of decommissioning 1,748 13 5
53 6
448 2,273 2,273 550 48 27,807 21,242 4a.1 Subtotal Period 4a Activity Costs 270 30,697 16,548 11,639 9,361 30,011 613 28,427 127,565 124,542 3,023 105,712 86,203 501 574 2,061 11,098,740 224,387 5,347 Period 4a Additional Costs 4a.2.1 Remedial Action Surveys 2,230 669 2,899 2,899 29,215 4a.2 Subtotal Period 4a Additional Costs 2,230 669 2,899 2,899 29,215 Period 4a Collateral Costs 4a.3.1 Process decommissioning water waste 5
8 11 50 17 90 90 71 4,234 14 4a.3.3 Small tool allowance 349 52 401 361 40 4a.3.4 Barnwell Annual Access Fee 703 105 808 808 4a.3 Subtotal Period 4a Collateral Costs 5
349 8
11 50 703 175 1,300 1,260 40 71 4,234 14 Period 4a Period-Dependent Costs 4a.4.1 Decon supplies 107 27 134 134 4a.4.2 Insurance 894 89 984 984 4a.4.3 Property taxes 36 4
40 40 4a.4.4 Health physics supplies 2,287 572 2,859 2,859 4a.4.5 Heavy equipment rental 3,534 530 4,064 4,064 4a.4.6 Disposal of DAW generated 86 29 233 71 419 419 4,018 80,360 131 4a.4.7 Plant energy budget 2,832 425 3,256 3,256 4a.4.8 NRC Fees 518 52 570 570 4a.4.9 Liquid Radwaste Processing Equipment/Services 603 90 693 693 4a.4.10 NEI Fees 741 111 852 852 4a.4.11 Security Staff Cost 3,636 545 4,181 4,181 61,391 4a.4.12 DOC Staff Cost 22,404 3,361 25,764 25,764 200,187 4a.4.13 Utility Staff Cost 27,296 4,094 31,390 31,390 355,498 4a.4 Subtotal Period 4a Period-Dependent Costs 107 5,821 86 29 233 58,959 9,971 75,207 75,207 4,018 80,360 131 617,076 4a.0 TOTAL PERIOD 4a COST 382 36,867 16,642 11,679 9,361 30,294 62,505 39,242 206,970 203,908 3,063 105,712 90,291 501 574 2,061 11,183,340 253,746 622,423 PERIOD 4b - Site Decontamination Period 4b Direct Decommissioning Activities 4b.1.1 Remove spent fuel racks 829 93 190 49 562 605 2,329 2,329 4,317 274,241 1,189 Disposal of Plant Systems 4b.1.2.1 Building & Equipment Drains-Conventional 75 11 86 86 850 4b.1.2.2 Chem & Vol Ctrl - Boric Acid Recovery 854 52 47 353 227 335 1,869 1,869 4,083 1,725 276,409 9,340 4b.1.2.3 Chem & Vol Ctrl - Primary Water Recovery 584 34 32 256 144 229 1,278 1,278 2,957 1,099 190,559 6,388 4b.1.2.4 Chem & Vol Ctrl Operation 943 56 31 128 242 326 1,726 1,726 1,480 1,826 178,224 10,014 4b.1.2.5 Chilled Water 351 53 404 404 4,017 4b.1.2.6 Chilled Water (RCA) 374 4
11 147 118 653 653 1,698 68,948 3,763 4b.1.2.7 Component Cooling 30 5
35 35 345 4b.1.2.8 Component Cooling (RCA) 667 25 80 1,050 339 2,161 2,161 12,135 492,793 6,979 4b.1.2.9 Compressed Air 209 31 240 240 2,369 4b.1.2.10 Compressed Air (RCA) 147 1
3 37 43 230 230 428 17,395 1,577 4b.1.2.11 Control Air - Auxiliary Building 239 3
10 136 82 471 471 1,576 63,990 2,685 4b.1.2.12 Control Air - Containment Building 76 1
3 43 26 148 148 493 20,025 861 4b.1.2.13 Control Air - Penetration Area 59 9
68 68 672 4b.1.2.14 Control Air - Turbine Generator Area 85 13 97 97 965 4b.1.2.15 Demineralized Water - Restricted Areas 113 1
4 49 36 204 204 571 23,200 1,152 4b.1.2.16 Demineralized Water Make-up 817 122 939 939 9,096 4b.1.2.17 Diesel Engine Auxiliaries 235 35 271 271 2,602 4b.1.2.18 Electrical 6,310 947 7,257 7,257 69,784 4b.1.2.19 Electrical (RCA - Clean) 1,118 11 36 477 358 2,000 2,000 5,511 223,814 11,316 4b.1.2.20 Electrical (RCA) 314 4
14 187 109 629 629 2,166 87,958 3,389 4b.1.2.21 Fire Protection 482 72 554 554 5,488 4b.1.2.22 Fire Protection (CO2) 27 4
31 31 305 4b.1.2.23 Fire Protection (RCA) 340 3
9 116 104 571 571 1,340 54,407 3,426 4b.1.2.24 Floor Drains - Contaminated 294 13 7
33 53 94 494 494 377 398 41,195 3,085 4b.1.2.25 Fresh Water 531 80 610 610 5,906 4b.1.2.26 Fuel Oil 407 61 468 468 4,452 TLG Services, LLC LR-N24-0040 Attachment 1 Page 118 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 19 of 21 Table D-2 Salem Generating Station Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:29:31 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.1.2.27 HVAC - Auxiliary Building 296 5
16 211 109 636 636 2,440 99,090 3,093 4b.1.2.28 HVAC - Control Area 53 8
61 61 604 4b.1.2.29 HVAC - Diesel Generator Area 13 2
15 15 143 4b.1.2.30 HVAC - Fuel Handling Area 137 2
8 102 51 301 301 1,180 47,922 1,436 4b.1.2.31 HVAC - Miscellaneous 346 52 398 398 4,118 4b.1.2.32 HVAC - Reactor Containment 742 13 42 549 275 1,620 1,620 6,344 257,650 7,692 4b.1.2.33 Heating Steam & Cond Return 302 45 348 348 3,462 4b.1.2.34 Heating Steam & Cond Return (RCA) 245 2
7 92 76 422 422 1,064 43,191 2,457 4b.1.2.35 Heating Water 208 31 239 239 2,332 4b.1.2.36 Heating Water (RCA) 123 1
3 41 38 206 206 474 19,257 1,228 4b.1.2.37 Htng Boiler Air/Gas Flow & Ignition Gas 7
1 8
8 80 4b.1.2.38 Miscellaneous Reactor Coolant 132 1
1 13 2
36 185 185 154 16 7,311 1,482 4b.1.2.39 Non-Radioactive Liquid Waste Disposal 597 90 686 686 6,636 4b.1.2.40 Plumbing - Hot and Cold Water 86 13 99 99 988 4b.1.2.41 Plumbing - Sanitary 55 8
64 64 622 4b.1.2.42 Residual Heat Removal 269 79 51 227 380 212 1,217 1,217 2,622 2,888 291,977 3,059 4b.1.2.43 Safety Injection 960 64 53 376 276 380 2,107 2,107 4,345 2,094 310,979 10,517 4b.1.2.44 Sampling 198 2
6 85 63 355 355 980 39,800 2,359 4b.1.2.45 Service Water - Nuclear Area 1,604 64 204 2,685 841 5,398 5,398 31,036 1,260,378 17,058 4b.1.2.46 Service Water - Turbine Area 116 17 134 134 1,336 4b.1.2.47 Spent Fuel Cooling 323 33 43 425 125 185 1,135 1,135 4,918 950 260,601 3,502 4b.1.2.48 Waste Disposal - Liquid 594 62 47 301 278 276 1,559 1,559 3,482 2,110 277,017 6,538 4b.1.2.49 Waste Disposal - Solid 100 6
7 68 23 43 247 247 790 173 43,150 1,096 4b.1.2.50 Water Pretreatment 170 26 196 196 1,911 4b.1.2 Totals 23,357 543 775 8,187 1,750 6,518 41,130 27,823 13,306 94,643 13,279 4,697,240 254,576 4b.1.3 Scaffolding in support of decommissioning 2,622 19 7
79 9
673 3,409 3,409 824 73 41,711 31,863 Decontamination of Site Buildings 4b.1.4.1 Reactor Containment 1,936 1,160 72 404 123 478 1,464 5,636 5,636 1,419 13,249 699,933 33,150 4b.1.4.2 Auxiliary Building 637 187 11 67 28 77 400 1,407 1,407 323 2,215 118,476 8,949 4b.1.4.3 Controlled Facilities Building 87 17 1
9 2
8 52 176 176 19 280 13,970 1,137 4b.1.4.4 Low Level Radwaste Storage Fac (HC) 28 7
0 3
0 3
17 58 58 4
93 4,534 378 4b.1.4.5 Fuel Handling Building 866 969 8
26 180 23 712 2,784 2,784 2,076 512 109,847 19,865 4b.1.4 Totals 3,554 2,340 93 509 332 589 2,645 10,061 10,061 3,840 16,349 946,760 63,479 4b.1.5 Prepare/submit License Termination Plan 276 41 317 317 1,753 4b.1.6 Receive NRC approval of termination plan a
4b.1 Subtotal Period 4b Activity Costs 4,383 28,411 845 1,341 8,598 2,911 276 10,482 57,246 43,940 13,306 99,307 34,017 5,959,951 351,107 1,753 Period 4b Additional Costs 4b.2.1 License Termination Survey Planning 1,182 355 1,536 1,536 6,240 4b.2.2 ISFSI License Termination 222 158 437 1,403 2,301 1,130 5,651 5,651 35,660 1,891,180 10,954 3,718 4b.2.3 Remove Underground Utilities 1,384 434 273 2,090 2,090 2,085 4b.2.4 Operational Tools & Equipment 11 32 313 53 410 410 5,880 147,000 16 4b.2.5 Asbestos Abatement 3,098 775 3,873 3,873 26,318 4b.2.6 Remedial Action Surveys 4,295 1,289 5,584 5,584 56,265 4b.2 Subtotal Period 4b Additional Costs 4,704 169 469 313 1,403 8,212 3,874 19,144 13,493 5,651 5,880 35,660 2,038,180 95,638 9,958 Period 4b Collateral Costs 4b.3.1 Process decommissioning water waste 12 21 29 132 45 240 240 188 11,275 37 4b.3.3 Small tool allowance 610 91 701 701 4b.3.4 Decommissioning Equipment Disposition 140 57 575 69 126 967 967 6,000 529 303,608 147 4b.3.5 Barnwell Annual Access Fee 1,353 203 1,556 1,556 4b.3 Subtotal Period 4b Collateral Costs 12 610 161 86 575 201 1,353 466 3,464 3,464 6,000 717 314,883 184 Period 4b Period-Dependent Costs 4b.4.1 Decon supplies 1,207 302 1,508 1,508 4b.4.2 Insurance 1,723 172 1,895 1,895 4b.4.3 Property taxes 70 7
77 77 4b.4.4 Health physics supplies 4,156 1,039 5,195 5,195 4b.4.5 Heavy equipment rental 6,985 1,048 8,033 8,033 4b.4.6 Disposal of DAW generated 98 33 268 82 481 481 4,612 92,246 150 4b.4.7 Plant energy budget 4,306 646 4,951 4,951 4b.4.8 NRC Fees 998 100 1,098 1,098 4b.4.9 Liquid Radwaste Processing Equipment/Services 1,160 174 1,334 1,334 4b.4.10 NEI Fees 1,427 214 1,641 1,641 4b.4.11 Security Staff Cost 7,002 1,050 8,052 8,052 118,235 TLG Services, LLC LR-N24-0040 Attachment 1 Page 119 / 123
Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 20 of 21 Table D-2 Salem Generating Station Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:29:31 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 4b Period-Dependent Costs (continued) 4b.4.12 DOC Staff Cost 42,501 6,375 48,876 48,876 377,227 4b.4.13 Utility Staff Cost 51,841 7,776 59,617 59,617 664,369 4b.4 Subtotal Period 4b Period-Dependent Costs 1,207 11,141 98 33 268 111,027 18,985 142,758 142,758 4,612 92,246 150 1,159,831 4b.0 TOTAL PERIOD 4b COST 5,602 44,867 1,274 1,929 9,486 4,782 120,868 33,806 222,613 203,655 5,651 13,306 111,187 75,006 8,405,260 447,079 1,171,542 PERIOD 4f - License Termination Period 4f Direct Decommissioning Activities 4f.1.1 ORISE confirmatory survey 183 55 238 238 4f.1.2 Terminate license a
4f.1 Subtotal Period 4f Activity Costs 183 55 238 238 Period 4f Additional Costs 4f.2.1 License Termination Survey 9,531 2,859 12,391 12,391 104,253 3,120 4f.2 Subtotal Period 4f Additional Costs 9,531 2,859 12,391 12,391 104,253 3,120 Period 4f Collateral Costs 4f.3.1 DOC staff relocation expenses 1,565 235 1,800 1,800 4f.3.2 Barnwell Annual Access Fee 377 57 433 433 4f.3 Subtotal Period 4f Collateral Costs 1,942 291 2,233 2,233 Period 4f Period-Dependent Costs 4f.4.2 Property taxes 19 2
21 21 4f.4.3 Health physics supplies 723 181 904 904 4f.4.4 Disposal of DAW generated 7
2 19 6
35 35 335 6,698 11 4f.4.5 Plant energy budget 320 48 368 368 4f.4.6 NRC Fees 306 31 337 337 4f.4.7 NEI Fees 397 60 457 457 4f.4.8 Security Staff Cost 744 112 855 855 11,753 4f.4.9 DOC Staff Cost 5,350 803 6,153 6,153 46,622 4f.4.10 Utility Staff Cost 4,799 720 5,519 5,519 56,808 4f.4 Subtotal Period 4f Period-Dependent Costs 723 7
2 19 11,935 1,961 14,648 14,648 335 6,698 11 115,184 4f.0 TOTAL PERIOD 4f COST 723 7
2 19 23,592 5,166 29,511 29,511 335 6,698 104,264 118,304 PERIOD 4 TOTALS 5,983 82,456 17,922 13,611 18,847 35,095 206,965 78,214 459,094 437,073 5,651 16,369 216,899 165,632 501 574 2,061 19,595,290 805,089 1,912,268 PERIOD 5b - Site Restoration Period 5b Direct Decommissioning Activities Demolition of Remaining Site Buildings 5b.1.1.1 Reactor Containment 3,841 576 4,418 4,418 24,505 5b.1.1.2 Administration Building 485 73 558 558 3,615 5b.1.1.3 Auxiliary Building 1,316 197 1,513 1,513 8,262 5b.1.1.4 Auxiliary Building Control Area 322 48 370 370 1,444 5b.1.1.5 Auxiliary Building Diesel Generator Area 134 20 154 154 610 5b.1.1.6 Barge Slip 290 43 333 333 1,362 5b.1.1.7 Chromate Demineralizer Enclosure 6
1 6
6 48 5b.1.1.8 Circulating Water Intake Structure 373 56 429 429 2,489 5b.1.1.9 Circulating Water Piping 2,296 344 2,640 2,640 20,963 5b.1.1.10 Clean Facilities Building 342 51 393 393 2,579 5b.1.1.11 Condensate Polishing Building 72 11 83 83 566 5b.1.1.12 Controlled Facilities Building 162 24 186 186 1,046 5b.1.1.13 Fire Pump House 40 6
46 46 259 5b.1.1.14 Guard House and Extension 75 11 86 86 635 5b.1.1.15 Heating Boiler Plant 47 7
54 54 245 5b.1.1.16 Low Level Radwaste Storage Fac (HC) 70 11 81 81 360 5b.1.1.17 Main Steam Isolation Structure 143 21 165 165 864 5b.1.1.18 Miscellaneous Structures 2,590 389 2,979 2,979 16,439 5b.1.1.19 Non-Rad Liquid Waste Chem Treatment Bldg 55 8
63 63 297 5b.1.1.20 Non-Rad Liquid Waste Disposal Basin 19 3
21 21 116 5b.1.1.21 Non-Rad Liquid Waste Transfer House 5
1 5
5 39 5b.1.1.22 Penetration Area 289 43 332 332 1,141 5b.1.1.23 Security Improvements 1,139 171 1,310 1,310 4,750 5b.1.1.24 Service Building 470 71 541 541 3,656 5b.1.1.25 Service Water Intake Structure 240 36 276 276 1,152 5b.1.1.26 Sewage Treatment Facilities 7
1 8
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Salem Generating Station Decommissioning Cost Analysis Document P07-1794-002, Rev. 0 Appendix D, Page 21 of 21 Table D-2 Salem Generating Station Unit 2 SAFSTOR Decommissioning Cost Estimate (Thousands of 2021 Dollars)
Costs run: Fri, Dec 10, 2021 at 10:29:31 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 Demolition of Remaining Site Buildings (continued) 5b.1.1.27 Switchyard 25 4
29 29 272 5b.1.1.28 Turbine Building 3,283 492 3,775 3,775 29,037 5b.1.1.29 Turbine Pedestal 433 65 498 498 1,943 5b.1.1.30 Fuel Handling Building 1,847 277 2,124 2,124 12,241 5b.1.1 Totals 20,415 3,062 23,477 23,477 140,967 Site Closeout Activities 5b.1.2 BackFill Site 1,217 183 1,400 1,400 1,601 5b.1.3 Grade & landscape site 416 62 479 479 789 5b.1.4 Final report to NRC 105 16 121 121 668 5b.1 Subtotal Period 5b Activity Costs 22,049 105 3,323 25,477 121 25,356 143,356 668 Period 5b Additional Costs 5b.2.1 Concrete Crushing 1,126 8
170 1,305 1,305 4,156 5b.2.2 Circulating Water Intake Structure Cofferdam 943 142 1,085 1,085 7,195 5b.2.3 Service Water Intake Structure Cofferdam 468 70 538 538 3,449 5b.2.4 ISFSI Demolition and Site Restoration 3,973 426 660 5,059 5,059 37,156 80 5b.2.5 Construction Debris 1,350 203 1,553 1,553 5b.2.6 Barge Slip Cofferdam 653 98 751 751 4,987 5b.2.7 Asphalt Milling 724 109 833 833 5b.2 Subtotal Period 5b Additional Costs 7,164 2,509 1,451 11,123 5,059 6,065 56,942 80 Period 5b Collateral Costs 5b.3.1 Small tool allowance 304 46 349 349 5b.3 Subtotal Period 5b Collateral Costs 304 46 349 349 Period 5b Period-Dependent Costs 5b.4.2 Property taxes 36 4
39 39 5b.4.3 Heavy equipment rental 6,799 1,020 7,819 7,819 5b.4.4 Plant energy budget 424 64 488 488 5b.4.5 Security Staff Cost 1,775 266 2,041 2,041 27,560 5b.4.6 DOC Staff Cost 13,148 1,972 15,120 15,120 110,240 5b.4.7 Utility Staff Cost 4,753 713 5,466 5,466 54,080 5b.4 Subtotal Period 5b Period-Dependent Costs 6,799 20,136 4,039 30,974 30,974 191,880 5b.0 TOTAL PERIOD 5b COST 36,315 22,750 8,858 67,924 121 5,059 62,744 200,299 192,628 PERIOD 5 TOTALS 36,315 22,750 8,858 67,924 121 5,059 62,744 200,299 192,628 TOTAL COST TO DECOMMISSION 13,444 130,801 18,327 14,008 18,847 37,070 733,169 167,020 1,132,688 784,483 265,019 83,187 216,899 175,185 501 574 2,061 19,874,370 1,069,643 5,840,087 TOTAL COST TO DECOMMISSION WITH 17.3% CONTINGENCY:
$1,132,688 thousands of 2021 dollars TOTAL NRC LICENSE TERMINATION COST IS 69.26% OR:
$784,483 thousands of 2021 dollars SPENT FUEL MANAGEMENT COST IS 23.4% OR:
$265,019 thousands of 2021 dollars NON-NUCLEAR DEMOLITION COST IS 7.34% OR:
$83,187 thousands of 2021 dollars TOTAL LOW-LEVEL RADIOACTIVE WASTE VOLUME BURIED (EXCLUDING GTCC):
176,260 Cubic Feet TOTAL GREATER THAN CLASS C RADWASTE VOLUME GENERATED:
2,061 Cubic Feet TOTAL SCRAP METAL REMOVED:
56,932 Tons TOTAL CRAFT LABOR REQUIREMENTS:
1,069,643 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 LR-N24-0040 Attachment 1 Page 121 / 123
Salem Generating Station Document P07-1794-002, Rev. 0 Decommissioning Cost Analysis Appendix E, Page 1 of 2 TLG Services, LLC APPENDIX E ISFSI DECOMMISSIONING LR-N24-0040 Attachment 1 Page 122 / 123
Salem Generating Station, Decommissioning Cost Analysis Document P01-1794-002, 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) 494 494 1,288 Decontamination (activated disposition) 445 316 874 2,805 4,440 71,319 4,175 License Termination (radiological surveys) 2,635 2,635 17,733 Subtotal 445 316 874 2,805 3,130 7,570 71,319 21,908 1,288 Supporting Costs NRC and NRC Contractor Fees and Costs 551 551 1,153 Insurance 193 193 Property taxes 17 17 Plant energy budget 8
8 Barnwell Annual Access Fee 337 337 Security Staff Cost 170 170 2,797 Utility Staff Cost 196 196 2,197 Subtotal 1,473 1,473 6,147 Total (w/o contingency) 445 316 874 2,805 4,603 9,042 71,319 21,908 7,435 Total (w/25% contingency) 556 395 1,093 3,506 5,753 11,303 Table E Salem Generating Station ISFSI Decommissioning Cost Estimate (thousands of 2021 dollars)
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)
TLG Services, LLC LR-N24-0040 Attachment 1 Page 123 / 123