ML20205F588

Decommissioning Cost Estimate for Diablo Canyon Power Plant,Units 1 & 2

ML20205F588
Person / Time
Site:	Diablo Canyon, Humboldt Bay
Issue date:	07/24/1997
From:	Carlson J, Palmer C, Seymore F TLG ENGINEERING, INC.
To:
Shared Package
ML20205F584	List: DCL-99-038, Forwards Decommissioning Funding Repts for Diablo Canyon Power Plant,Units 1 & 2 & Humboldt Bay Power Plant,Unit 3, Per Requirements of 10CFR50.75(f) ML20205F588 ML20205F599
References
P01-1252-002, P1-1252-2, NUDOCS 9904060323
Download: ML20205F588 (127)

Text

Enclosura 3

l. DCL-99-038 HBL-99-004 1

Decommissioning Cost Estimate for the l Diablo Canyon Power Plant j l

i Units 1 and 2 i l

I Prepared by TLG Services, Inc.

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Dscument No. P01-1252 002 233552 I l

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. DECOMMISSIONING COST ESTIMATE for the DIABLO CANYON POWER PLANT

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UNITS 1 AND 2 N )

prepared for Pacific Gas & Electrie Company July,1997 l

prepared by TIJG Services, Inc. 1 Bridgewater, Connecticut k i

g Disbin C2nyon P;wer Plant Dscument P01-1252-002, Rev. 0

. Page ll of xiv 233552 APPROVALS Project Manager M d -- 7 VM9 ' '

Jiihn arlson Dat'e Technical Manager m si a - 7!#/[7 r n'cis'W. 5eym'o Daft Quality Assurance Manager M8dd 7/M/f7 ,

Carolyni Palmer Ddte '

DI: big Canyon Power Plant Document P01-1252-002, Rev. O

. Page tti o xto c,yyrry*

A, u u d d TABLE OF CONTENTS SECTION - PAGE EXECUTIVE

SUMMARY

. ... . ..... .. . ..... .... ........ .................. .. ............. ...... ... . . ... . ..viii xiii

1. I NTR O D U CTI O N . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

1.1 Objective of S tudy. . . . .. ............ ... .... . .. ... . . ..... ..... ... .. . . .... ... .. . . .. . .. . . . . . . . . . . . . . . ... . . 1 - 1 1.2 Site D e scriptio n . . . . . . . .. . . . .. ... . . .. .. . . . .. . ... .. . . .. . ... .. ... .. .. ..... . . . . . . . . . . . . .. . . .. ... . . . . . . . . . . . . ... . 1 - 1

1. 3 Re gulato ry G uid ance . .. . .. .. . . . . . . . . . . .. .... . ... .. . . . .... .. . . . .. . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . .. 1 -2 i

1.3.1 Nuclear Waste Policy Act ......... ......................................................... 1-4 1.3.2 Low Level Radioactive Waste Policy Amendments Act ..................1-5 l

- 2. DECOMMISSIONING ALTERNATIVES ........................................................... 2-1 2.1 DECON..........................................................................................................2-1 2.1.1 Pe riod 1 - Preparations ........ ...... .... .................................... . . . .... . . . ..... .. 2-2 l 2.1.2 Period 2 - Decommissioning Operations & License Termination.... 2 G {

1 2.1.3 Period 3 - Site Restoration .................................................................. 2-9 2.1.4 Post Period 3 - ISFSI Operations and Demolition.......................... 2-11 l

2. 2 S AFS TO R. . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . )

2.2.1 Period 1 SAFSTOR Operations...................................................... 2 12 2.2.2 Period 2 - SAFSTOR Dormancy ....................................................... 2-14 2.2.3 Period 3 4 Deferred Decommissioning............................................. 2 16 2.2.4 Period 5 - Site Restoration ........................ ....................... .............. 2-18

3. C O ST E S TIMAT E . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

3.1 B asis of E stim a te . ... . . . . . . . . .. . . . . ... . . . . . . . . . . .. . . .. . . . . .... .. ..... .. . . .. . . . .. . . ... . . . . . . . . . . . . . . . . .

3. 2 M e thod olo gy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

3.3 Financial Components of the Cost Model .................................................... 3-2

3. 3.1 Contin ge ncy . .. .. . . . .. .. .. .. . . . . . . ... . . . . . .... . . ... . . . . . . .. . . .... . . . . . . . .. . . . . . . . .. . . . . . . . . . .. . . . . . .

3. 3. 2 Fin ancial Risk . . . . . . . . . .. . . . .. .. . . .. . . ... . . . . . .. . . .. . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . .

3.4 Site Specific Considerations ...... ................................................................. 3 9 3.4.1 Spent Fuel Disposition .... ............ .. ........................ .... ...... .. ..... . .. .. .. . . . . . . 3 9 3.4.2 Reactor Vessel and Internal Components .......................................... 3 9 3.4.3 Steam Generators and Other NSSS Components ........................... 310 1

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233552 DI: bis Canyon P:werPlant Document Pol-1252-002, Rev. 0 Pageivofxiu TABLE OF CONTENTS (continued)

I SECTION-PAGE j 3.4.4 Transportation Methods .................................................................... 3-12 3.4.5 Low Level Radioactive Waste Disposa1............................................ 3-12 3.4.6 Site Conditions Following Decommissioning ................................... 3-13 3 . 5 As s ump tio n s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

3.6 Co st E stim ate S um m ary . . . . . . . . .. . . . . .. . . . . . . . . . . . . . . . .. . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 18

4. S C HED ULE ESTIMATE .. . . . . . . . . . . . . .. . . . . . . . . . .. ... . . ... . . . . .. . .. . .. . . . . .. . .. . . . . .. . .. . . . . . . . .

4.1 Sche dule Estimate Assump tions ................................. ................................ 4-1

4. 2 Proj e ct Sche d ule .. . . . . . . . . .. . . . . . . . . . . . .. . . . .. . . . . . . . . . . . . . . . . . . . .. . .. . . . . .. .. . . . . .. .. . . . . . . . . . .

5. RADIOACTIVE WASTE S . .. . . . . . . . . . . . . . . . . . . . . . . . . .. . .. . . . . . . .. . . . .. . . . . . . . . . . . . . .. . . . . . . . . .

6. O CCUPATIO NAL EXPOSURE .. . . ...... ... .... .... . ... ............... . ...... ..... .. .... . . . . . . . . . . . . . . . 6- 1

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

8. R E FE R E N CE S . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

TABLES Cost and Sche dule Estimate Summ ary ........................................... ....... ........ xiv 3.la Summary of DECON Decommissioning Costs - Unit 1............................... 3-19 3.1b Summary of DECON Decommissioning Costs - Unit 2............................. . 3 20

- 3.2a Summary of SAFSTOR Decommissioning Costs - Unit 1........................... 3 21 0.2b Summary of SAFSTOR Decommissioning Costs - Unit 2........................... 3-22 5.1 Decommissioning Radioactive Waste Burial Volumes ............................. ... 5 3 7.1 Summary of DECON Decommissioning Costs ............................................... 7-4 7.2 Summary of SAFSTOR Decommissioning Costs .................................... ...... 7-5

Di:blo C:nyon Power Plant Document P01-1252-002, Rev. 0

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TABLE OF CONTENTS (continued)

- SECTION-PAGE FIGURES 4.1 D E CO N Activity Sche dule .. . . .. . . . . . . .... . . ... .. . .. ... . ... . ....... . . .. . ... .. . . . . . . . . .. . . . . . . . . . .. . . . . . . 4 -3 4.2a DECON Decommissionin g Timelines ................................. ........................... 4-9 4.2b SAFSTOR Decommissioning Timelines ....................................................... 4-10 APPENDICES A. Unit Cost Factor Develop me nt ............. ........ ..... .. ...... .. ..... ....... ............ ... ... .... .... ..... .. A- 1 B . U nit Co st Factor Listing ......... ...... .. . . ... .. .. . . . . . .. . . . . .. . .. . . . . . . . ... . . . .. . .. . ... . . . . . ... . . . . . . . .. .. . . . . . . . B- 1 C. D e t aile d Co st Analyse s . . . .. . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . .. .. .. .. . . . . .. . . . . . . . . . . . . . . . . ... . . . . . . .. . . . .

Diablo Canyon P.:wer Plant Document P01-1252-002, Rev. 0

- Page vi of xlv 233552 TABLE OF ACRONYMS / ABBREVIATIONS

. ALARA As Low-As. Reasonably Achievable DAW Dry Active Waste DCPP Diablo Canyon Power Plant DECCER TLG's proprietary decommissioning cost model DF Decontamination Factor DOC Decommissioning Operations Contractor DOE Department of Energy DOT Department of Transportation DSC . Dry Shielded Canister i FSAR Final Safety Analysis Report GTCC Greater Than Class C HVAC Heating Ventilation and Air Conditioning ISFSI Independent Spent Fuel Storage Installation LSA Low Specific Activity NRC Nuclear Regulatory Commission NSSS_ Nuclear Steam Supply System P&ID' Piping & Instrument Diagram PERT Program Evaluation and Review Technique PG&E Pacific Gas & Electric Company PSDAR Post Shutdown Decommissioning Activities Report l

r Diabis Canyon Power Plant Document P01-12S?-002, Rev. 0 Page vil of xit, 233332 REVISION LOG i

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Ditblo Crnyon Power Plant Document P01-1252-002, Rev. 0

. Page viii ofxiv 233552 EXECUTIVE

SUMMARY

This study, prepared for Pacific Gas & Electric Company (PG&E) by TLG Services, Inc., evaluates two different decommissioning cliernatives for the Diablo Canyon Power Plant (DCPP) following the final cessation of plant operations. The projected costs to decommission the station are estimated at approximately $1,048.7 million and $1,082.0 million for the DECON and SAFSTOR alternatives, respectively. For each of these alternatives, the major cost contributors to the overall decommissioning cost are labor, radioactive waste disposal and other removal related activities (e.g.

engineering, support equipment). The costs are based on several key assumptions, including regulatory regtdrements, estimating methodology, contingency requirements, low-level radioactive waste disposal availability, high level radioactive waste disposal options, and site restoration requirements. A complete discussion of the assumptions used in this estimate is presented in Section 3.

A detailed breakdown of these major cost contributors to the decommissioning cost estimate is reported in Section 7. Cost and schedule summaries are reported in at the end of this section. Schedules of annual expenditures are provided in Section 3, with the detailed activity costs, waste volumes and removal man hours provided in the Appendices. Costs are reported in 1997 dollars. The DECON cost estimates include the continued operation of the Fuel Handling Buildings' fuel storage pools as an interim wet fuel storage facility until the year 2024 (approximately eight years after each unit's license expiration.) In addition, the DECON estimates include the costs to expand the site Independent Spent Fuel Storage Installation (ISFSI) to accommodate the inventory of spent fuellocated on site after year 2024. This ISFSI is expected to operate until the year 2034. The SAFSTOR cost estimates include no additional construction costs to expand the existing site ISFSI, but allow for continued wet pool storage until 2034.

Alternatives and Reculations The Nuclear Regulatory Commission (NRC) provided general decommissioning guidance in the rule adopted on June 27, 1988 1 In this rule the NRC set forth technical and financial criteria for decommissioning licensed nuclear facilities. The regulations addressed planning needs, timing, funding methods, and environmental review requirements for decommissioning. The rule also defined three decommissioning alternatives as being acceptable to the NRC - DECON, SAFSTOR and ENTOMB.

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

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Dickla C:nyon PcwerPlant ~ Document P01-1252-002, Rev. 0 Page ix of.xlv 233552 DECON was defined.as "the alternative in which the equipment, structures, and portions of a facility and site contaimng radioactive contaminants are

removed or decontaminated to a level that permits the property to be released i for unrestricted use shortly after cessation of operations." 2 SAFSTOR was defined as "the alternative in which the nuclear facility is placed and maintained in a condition that allows the nuclear facility to be safely stored and subsequently decontaminated (deferred decontamination) to levels that permit release for unrestricted use." 8 ENTOMB was defined as "the alternative in which radioactive contaminants are - encased in a structurally long lived matdrial, such as ' concrete;. the entombed structure is appropriately maintained and ' continued surveillance is  !

carried out until the radioactive material decays to a level permitting unrestricted release of the property." 4 4 In 1996, the NRC published revisions to the general requirements for decommissioning nuclear power plants to clarify ambiguities and codify procedures and terminology as a means of enhancing efficiency and uniformity in the decommissioning process. The amendments allow for greater public participation and better define the transition process from operations to decommissioning. The costs and schedules presented in this estimate follow the general guidance and sequence in the amended regulations.

Methodolorv The methodology used to develop the decommissioning cost estimates for DCPP follows the basic approach originally presented in the cost estimating guidelines 5 developed by the Atomic Industrial Forum (now Nuclear Energy Institute). This reference describes a unit cost factor method for estimating decommissioning activity costs. The unit cost factors used in this study reflect site-specific costs, as well as the latest available information about worker productivity in decommissioning. The

'information obtained from the Shippingport Station Decommissioning Project, completed in 1989, as well as from TLG's involvement in the decommissioning planning and engineering for the Shoreham, Yankee Rowe, Trojan, Rancho Seco, Pathfinder, and Cintichem reactor facilities, is reflected within this estimate.

'2 Ibid. Page FR24022, Columr. 3.  :

s Ihig, 4 Ibid. Page FR24023, Column 2.

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

Dizbio Canyon P:werPl:nt Document P01-1252-002, Rev. 0

- Page x of xiv 2!I!3552 An activity duration critical path is used to determine the total decommissioning program schedule required for calculating the carrying costs which include program management, administration, field engineering, equipment rental, quality assurance,

. and security. This systematic approach for assembling decommissioni2g estimates has ensured a high degree of confidence in the reliability of the resulting costs.

This study assumos that PG&E's primary contractor is experienced in the techniques and technology of nuclear power plant decommissioning, and therefore performs all work (both field activities and project management) in an optimally efficit manner.

Therefore, this study does not attempt to quantify any cost impact for any increase in efficiency from experience gained in decommissioning other plants in the past.

Contingency -

Consistent with industry practice, contingencies are applied to the decontamination and dismantling costs developed as, " specific provision for unforeseeable elements of cost within the defined project scope, - particularly important where previous experience relating estimates and actual costs has shown that unforeseeable events which willincrease costs are likely to occur."8 The cost elements in this estimate are I based on ideal conditions; therefore, the types of unforeseeable events that are almost certain to occur in decommissioning, based on industry experience, are addressed - ,

through a percentage contingency applied on a line item basis. This contingency j factor is a ne'arly universal element in all large-scale construction and demolition projects. It should be noted that contingency, as used in this estimate, does not account for price escalation and inflation in the cost of decommissioning over the remaining operating life of the units.

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

j Low-Level Radioactive Waste Disoosal 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 Disposal Act" in 1980, and its ,

' Project and Cost Engineers' Handbook, Second Edition, American Association of Cost Engi- l neers, Marcel Dekker, Inc., New York, New York, p. 239.

Diablo Canyon PswerPlant Document P01-1252-002, Rev. 0

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Amendments of 1985 7, the states became ultimately responsible for the disposition of low-level radioactive waste generated within their own borders. Consequently, low-level radioactive vaste generated in the decontamination and dismantling of PG&E's nuclear generating units is destined for the Southwest Compact's future Ward Valley disposal site.

For purposes of constructing the decommissioning cost estimates, an assumed unit burial rate of $509 per cubic foot was used to calculate the cost for disposal of low-level radioactive waste generated in the decontamination and dismantling of DCPP.

This rate is derived from projections developed by the Ward Valley site developer, US Ecology, as well as from discussions with PG&E.

High Level Waste Congress passed the " Nuclear Waste Policy Act" in 1982 s, assigning the responsibility for disposal of spent nuclear fuel created by the commercial nuclear generating plants to the Department of Energy (DOE). This legislation also created a Nuclear Waste Fund to cover the cost of the program, which is funded by the sale of electricity from PG&E, and an estimated equivalent for assemblies irradiated prior to '

April,1983. The target date for startup of the federal Waste Management System was originally 1998.

After several delays, DOE estimates that the geologic repository will' not be operational until sometime between the years 2010 and 2015. For the basis of this cost study, PG&E has assumed that the high level waste repository or some interim storage facility will accept spent fuel from DCPP starting in the year 2017. The backlog of spent fuel in the nationalinventory, and slow progress in the development of a waste transportation system, make it necessary to include spent fuel storage in the cost and schedule of commercial reactor decommissioning.

Although the cost to dispose of , , ant fuel assemblies generated during plant operations presently is not considered a decommissioning expense, the presence of those assemblies on site does have a bearing on the cost to decommission. For estimating purposes, a spent fuel. storage scenario was developed for DCPP. This scenario assumes that PG&E will have constructed an ISFSI at the plant site to support continued plant operations. It also assumes that the Fuel Handling Buildings at DCPP will be operational for at least 8 years after the cessation of each units operations, regardless of the decommissioning mode selected (so as to allow for sufficient cooling for passive stcrage). Considering the DECON decommissioning

' " Low. Level Radioactive Waste Policy Amendments Act of 1985," Public Law 99-240,1/15/86.

8 " Nuclear Waste Policy Act of 1982 and Amendments," U.S. Department of Energy's Office of Civilian Radioactive Management,1982.

Dizblp C:nyon P:wer Pl:nt D:cument PO1-1252-002, Rev. 0

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alternative, the spent fuel assemblies in the storage pools at the cessation of plant operations will be relocated to the ISFSI for storage until such time that a transfer to a DOE or interim storage facility can be completed. Costs are included within the

. estimates to expand the ISFSI to accommodate the poolinventories at shut down. By relocating the fuel to the ISFSI , PG&E can secure the wet storage pools and proceed with decommissioning the Diablo Canyon site.

The SAFSTOR decommissioning alternative includes no expansion of the ISFSI.

Therefore, the inventory of spent fuel, located in the units' storage pools at shutdown, will remain in wet storage until such time that DOE can take receipt. The current PG&E spent fuel storage plan projects that spent fuel will be at Diablo Canyon until the year 2034 for both the DECON and SAFSTOR alternatives.

Site Restoration The efficient removal of the contaminated materials at the site will result in substantial damage to many of the site structures. Blasting, coring, drilling and the other decontamination activities will substantially damage power block structures, potentially weakening the footings and structural supports. Prompt demolition after license termination 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 contamins. tion is removed. The cost to dismantle site structures with a work force already mobilized on site is more efficient and less costly than if the process is defe:: red. Experience at shutdown generating stations has shown that plant facilitier quickly degrade without continual maintenance, adding additional expense and creating potential hazards to the public, as well as to the demolition work force. Consequently, this study assumes that site structures will be removed to a nominal depth of three feet below the local grade level. The site will then be graded and stabilized.

Recommendations In most situations, the DECON alternative is the preferred mode of decommissioning. f This alternative is favored because it eliminates the costs for caretaking and prevents l the site from becoming a potential long term safety hazard. More importantly, the l individuals familiar with the operation of the nuclear facility are available to support j the dismantling effort; plant systems and ser' ices are fully functional; structural l integrity is intact; and the licensee has a coruprehensive management organization (

available to oversee / conduct the orderly decontamination and termination of the NRC licenses of the site.

The construction of barriers and the general decontamination of plant areas in preparation for long term storage (SAFSTOR) does not necessarily alleviate the need l

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- Page xill of xiv 233552 for continued surveillance. Therefore SAFSTOR would require a full time preventive and corrective maintenance staff to maintain essential site services and prevent the deterioration of the facilities. Maintenance would be required on security systems,

. area lighting, and on site facilities supporting the fuel storage activity. These facilities include power centers, administrative offices, and fuel transfer / repackaging facilities. Active supporting systems and components include plant fire protection,

- site drainage / monitoring and sewage, plant transformers and switchyard, plant grounding and lightning protection, communications, liquid collection, sampling and processing, seismic monitoring, etc. As a result, estimates for the caretaking of a dormant facility havc increased significantly. The NRC's review of current comparable facilities has resulted in a general increase in the level of maintenance required, as well as a greater on site presence by the licensee.  ;

i A manmum 60-year delay in decommissioning would not dramatically alter the l cleanup requirements, i.e., the quantities of waste to be remediated would be l comparable to those addressed in the DECON alternative. Although the radiation levels within the plant will have decreased substantially over the period of decay, the presence of long lived radioisotopes would control the removal and disposal techniques used in the decontamination and dismantling of plant systems and facilities. As such, the cost savings in postponing decommissioning are relatively small and the risk that regulatory requirements and waste disposal options will become more restrictive are relatively high.

Summary DECON, the alternative involves removal of all radioactive material from the site following permanent shutdown. The facility operator may then have unrestricted use of the site with no further requirement for a license. This study also assumes that the I remainder of the plant systems and structures on site, not previously removed in {

j support NRC license termination, are dismantled and site restoration is performed.

As an option, the SAFSTOR decommissioning alternative is also examined in this study. This alternative assumes that after a 30-year dormancy period, the I

decommissioning activity concludes with the decommissioning and dismantling of those site structures affected by the decontamination effort and restoration of the remainder of the areas of the DCPP site.

This study provides estimates for decommissioning the DCPP under current requirements and is based on present-day costs and available technology. A cost summary is provided in the following table. Detailed activity costs for each decommissioning alternative and nuclear unit are provided in Appendix C. The schedule and sequence of decommissioning activities is identified in Section 4.  !

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DIABLO CANYON UNITS 1 AND 2 COST AND SCHEDULE ESTIMATE

SUMMARY

Cost,978 ' Schedule (thousands) (years)

DECON (Prompt Removal / Dismantling)

Unit 1 436,570.6 19.7 l

Unit 2 & Common 612,128.8 18.8 STATION TOTAL 1,048,699.5 0) 19.7(2)

SAFSTOR (Mothball with Delayed Dismantling)

Unit 1 Preparations 67,480.1 1.5 30 year maintenance cost 106,741.7 30.0 Delayed dismantling 272,987.6 7.7 Subtotal 447,209.4 39.2 Unit 2 & Common Preparations 72,575.6 1.5 30.5 year maintenance cost 107,082.4 30.5 Delayed dismantling 455,117.2 6.3 Subtotal 634,775.2 38.3 STATION TOTAL 1,081,984.7 0) 39.2 (8)

(1) Columns may not add due to rounding.

(2) Time elapsed from the cessation of operations at Unit 1 to the completion of the transfer of spent fuel off-site.

(3) Time elapsed from the cessation of operations at Unit 1 to the completion of site restoration at Unit 2.

i Diabis Canyon PowerPlcnt Document P01-1252-002, Rev. 0 Section 1, Page 1 of 5 233552

1. INTRODUCTION l This analysis is designed to' provide Pacific Gas & Electric Company (PG&E) with sufficientinformation to prepare financial planning documents required by the Nuclear Regulatory Commission (NRC). It is not a detailed engineering document, but a cost estimate prepared in advance of the detailed engineering preparations required to carry out the decommissioning of Units 1 and 2 of the Diablo Canyon Power Plant (DCPP).

1.1 OBJECTIVE OF STUDY -

The objective of this study is to prepare an estimate of the cost, schedule, occupational exposure and Waste volume generated to decommission the DCPP, including all common and supporting facilities. The study considers the integration of two unit disr.tantling, as discussed below.

Unit 1 began commercial operation in May 1985, with Unit 2 following in March of 1986. For the purposes of this study, the shutdown dates were taken as 30 years after the date of commercial operation, or May 2015 for Unit I and March 2016 for Unit 2. This time frame was used as input for scheduling the decommissioning. .

1.2 SITE DESCRIPTION DCPP is located on the central California coast in San Luis Obispo County, approximately 12 miles west southwest of the City of San Luis Obispo. The plant, comprised of two nuclear units, is located on a 750 acre site adjacent to the Pacific Ocean roughly equidistant from San Francisco and Los Angeles.

The Nuclear Steam Supply Systems (NSSS) consist of a pressurized water reactor and four loop Reactor Coolant System. The systems were supplied by the. Westinghouse Electric Corporation. Unit I has a reference core design of 3488 MWt (thermal) and Unit 2, 3568 MWt, with corresponding net

~ dependable capability electrical ratings of 1131 and 1156 megawatts (electric),

respectively, with the reactors at rated power.

The reactor coolant system is comprised of the reactor vessel and four heat transfer loops, each containing a vertical U-tube type steam generator, and a single stage centrifugal reactor coolant pump. In addition, the system includes an electrically heated pressurizer, a pressurizer relief'ank and interconnected piping. The system is housed within a " containment structure," a seismic Category I reinforced-concrete dry structure. It consists of an upright cylinder 3

'Diabib 01nyon P:wer Picnt Document P01-1252-002, Rev. 0

. ' Secticn 1, Page 2 cf 5 233552 topped with a hemispherical dome, supported on a reinforced concrete foundation mat which is keyed into the bedrock. A welded steel liner plate anchored to the inside face of the containment, serves as a leak tight membrane. The liner on top of the foundation mat is protected by a two-foot thick concrete fill mat which supports the containment internals'and forms the

. floor of the containment. The lower portion of the containment cylindrical wall has additional embedded wide flange steel beams between elevations 88 ft. 2 in. MSL (mean sea level) and 108 ft. 2 in. MSL.

Heat produced in the reactor is converted to electrical energy by the steam and power conversion systems. 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 plant's 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 1800 rpm. The turbines are operated in a closed feedwater cycle which 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.

The circulating water system provides the heat sink required _ for removal of waste heat in the power plant's thermal cycle. The system has the principal function of removing heat by absorbing this energy in the main condenser.

Condenser circulating water is water from the Pacific Ocean. Each unit is served by two. circulating water pumps at the intake structure. From this structure seawater is pumped through two circulating water conduits to the condenser inlet water boxes. The water is returned to the ocean at Diablo Cove through an outfall at the water's edge.

1.3 REGULATORY GUIDANCE The NRC provided decommissioning guidance in the rule " General Requirements for Decommissioning Nuclear Facilities," (Ref.1) published and i adopted on June 27,1988. This rule amended NRC regulations to set forth i technical and financial criteria for decommissioning licensed nuclear facilities. I 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 licensee 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," (Ref. 2) which provided guidance to the licensees of nuclear facilities on methods acceptable to the NRC staff for complying with the requirements of the rule. The regulatory i

DE:blo C:nyon PowerPirnt Document P01-1252-002, Rev. 0 Section 1, Page 3 of 5 233fifi2 guide addressed the funding requirements and provided guidance on th(

content and form of the financial assurance mechanisms indicated in the rule amendments.

The rule defined three decommissioning alternatives as being acceptable to the NRC: DECON, SAFSTOR and ENTOMB. It also placed limits on the time allowed to complete the decommissioning process. For SAFSTOR, the process )

is restricted in overall duration to 60 years unless it can be shown that a longer i 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.

Consequently .with the new restrictions, the SAFSTOR and ENTOMB options are no longer decommissioning alternatives in themselves, as neither terminates the license for the site. 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 de6nition of unrestricted l release and license termination. Further, the NRC does not believe that j ENTOMB is generally a viable option for a power reactor due to the long-lived l nature of the radionuclides involved. j l

In 1996 the NRC published revisions to the general requirements for decommissioning nuclear power plants (Ref. 3). When the decommissioning regulations were adopted in 1988, it was assumed that the majority of licensees would decommission at the end of the operating license life. Since  ;

that time, several licensees had permanently and prematurely ceased '

operations without having submitted a decommissioning plan. In addition, these licensees requested exemptions from certain operating requirements as being unnecessary once the reactor is defueled. Each case has been 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 efHeiency 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 would submit written certification to the NRC within 30 days after the decision was made to cease operations.

Certification would also be required once fuel had been permanently removed from the reactor vessel. Submittal of these notices would entitle the licensee to a fee reduction and eliminate the obligation to follow certain requirements needed only during operation of the reactor. Within two years of submitting notice of permanent cessation of operations, the licensee would be required to

i 1

' Dinbio Canyon PzwerPlant Dicument P01-1252-002, Rw. 0

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• Sectisn 1, Page 4 of 5 233552 submit a Post Shutdown Decommissioning Activities Report (PSDAR) to the NRC. This report would describe the planned decommissioning activities, the associated sequence and schedule, and an estimate of expected costs. Prior to completing decommissioning, the licensee would be required to submit an application to the NRC to terminate the license, along wPh a license termination plan.

1.3.1 Nuclear Waste Policy Act Congress passed the Nuclear Waste Policy Act in 1982 (Ref. 4),

assigning the responsibility for disposal of spent nuclear fuel from the commercial generating plants to the Department of Energy (DOE). Two permanent disposal facilities were envisioned as well as an interim' facility. To recover the cost of. permanent spent fuel disposal, this legislation created a Nuclear Waste Fund th'uugh which money was to be collected from the consumers of the electricity generated by commercial nuclear power plants. The date targeted for startup of the federal Waste Management System was 1998.

.After pursuing a national site selection process, the Act was amended in 1987 to designate Yucca Mountain, Nevada, as the only site to be evaluated for geologic disposal of high level waste. Also in 1987, DOE announced a five-year delay in the opening date for the repository, from 1998 to 2003. Two years later, in 1989, an additional 7-year delay was announced, primarily due to problems in obtaining the required permits from the state of Nevada to perform the required characterization of the site. DOE has projected additional delays as a result of proposed Congressional reductions in appropriations for the program.

Utilities have responded to this impasse by initiating legal action and constructing supplemental storage as a means of maintaining operating margins. The U.S.~ Court ' of Appeals for the D.C. Circuit recently confirmed (July,1996) DOE's statutory obligation to provide spent fuel disposal beginning in 1998, regardless of whether the agency has an operating repository. However, since the agency is not currently in default, the court declined to prescribe " remedies" in the likely event DOE fails to uphold its obligation.

For purposes of constructing the decommissioning cost estimate, DOE is assumed to begin receiving spent fuel from the DCPP site in the year 2017. It is estimated that the DCPP spent fuel would be completely transferred to DOE by the end of year 2034. These schedules and dates are based upon information provided by PG&E and DOE's capacity and

=

Diabli Canyon Power Plant Document P01-1252-002, Rev. 0

- Section 1, Pege 5 of 5 233552 turnover schedule _(Ref. 5).

1.3.2 Low Level Radioactive Waste Policy Amendments Act Congress passed the " Low Level Radioactive Disposal Act" in 1980, declaring the states as being ultimately responsible for the disposition of low level radioactive waste generated within their own borders. The federallaw encouraged the formation of regional groups or compacts to implement this objective safely, efficiently and economically, and set a

. target date of 1986. With little progress, the " Amendments Act of 1985 (Ref. 6) extended the target, with specine milestones and stiff sanctions for non-compliance. However, more than 10 years later, no new sites have been developed and even the most advanced program is far behind schedule.

The low level radioactive waste generated in the decontamination and dismantling of DCPP_is destined for the Southwest Compact's future .

~

)

disposal facility'in Ward Valley, California. This study assumes that this facility will be operational and supporting decommissioning operations by the year 2000. Any delay in the scheduled opening of the Ward Valley site will ultimately increase burial costs.

For purposes of constructing the decommissioning cost estimate, a base burial rate of $509 per cubic foot was used for low level radioactive waste disposal within the Southwest Compact. The value was derived from projections developed by the site developer, US Ecology, and through discussions with PG&E.

.Dicblo Canyon PowerPlant Document P01-1252-002, Rev. 0

. Section 2, Page 1 of18

2. DECOMMISSIONING ALTERNATIVES Cost' studies were developed'to decommission DCPP for two of the NRC-approved decommissioning alternatives: DECON and SAFSTOR. The duration of dormancy (30 years) selected for the SAFSTOR alternatives is within the maximum allowable interval (60 years) between cessation of operations and terr - thn of the site license (s). Although the alternatives differ with respect to tecu - 9, process, cost, and schedule,' the two alternatives attain the same result: remova of all regulated radioactive material from the site and ultimate release of the site for unrestricted and/or alternative use.

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, these 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. I 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 reler. sed for unrestricted use shortly after cessation

. of operations." This study does not address the cost to remove spent fuel from the site; such costs are assumed to be funded through the surcharge on electrical generation (1 mill / kwhr). However, the study does recognize the constraint imposed by the spent fuel residing. on site during the decommissioning process and also the costs associated with extended onsite caretaking of the fuel.

The approach that the NRC has chosen in its recently amended regulations is to divide decommissioning into three pheses. The initial phase commences with the effective date of permanent cessation of operations and involves the transition of both plant and licensee from reactor operations, i.e., power  ;

, production to facility de activation and closure. During Phase I, notification is to be provided to the NRC certifying the permanent cessation of operations and the removal of fuel from the reactor vessel. The licensee is then prohibited from reactor op'eration. Within two years of notificata.n to ceese reactor operations, the ' licensee is required to provide a Post-Shutdown Decommissioning Activities Report (PSDAR). This report provides a description of the licensee's planned decommissioning activities, a corresponding schedule, and an estimate

' Disbla Canyon P:werPlant Document P01-1252-002, Rev. 0 Sectlon 2, Page 2 cf 18.

4 l i l

L of expected costs. The PSDAR also addresses whether environmental impacts associated with the proposed decommissioning scenario have already been considered in a previously prapared environmental statement (s). Ninety days following the NRC's receipt of the PSDAR, the licensee may initiate certain decommissioning activities, without specific NRC approval, under a modified -

Title 10 of the Code of Federal Regulations, Section 50.59 (all subsequent references to Title 10 of the Code will be by section number only, i.e. g50.59) review process. The amended regulations permit tl e licensee to expend / recover j

up to 3% of the generic decommissioning cost for planning, with an additional 20% available following the 90-day waiting period and certification of permanent defueling. Remaining funds would be available to the licensee with submittal of a detailed, site specific cost estimate.

l The second phase identified by the NRC addresses licensed activities during a storage period, applicable to the dormancy phases of the deferred decommissioning alternative, SAFSTOR. Phase III pertains to the activitiei, involved in license termination. The submittal of an application to terminate the license, along with a termination plan, marks the commencement of this Ollase. The termination plan contains a detailed site characterization, i.e.,

location, type and amount of radioactivity, a description of any remaininn; l

dismantling activities to be accomplished, detailed plans for a final sitrvey and any planned use of the site. An updated cost to complete is required along with the reporting of any new or altered environmental consequences.

The TLG methodology divides the decommissioning project into periods, based i upon major milestones in the project. Phase I of the NRC's 1996 smended ,

i regulations corresponds roughly to Period 1 of DECON with Phase III corresponding to Period 2. The NRC Phase II has no corresponding period in the DECON mode, being applicable only to the dormancy period of SAFSTOR (Period 2). Period 3, Site Restoration, is not addressed in the amended l regulations.

' 2.1.1 Period 1 - Preparations In anticipation of the cessation of ' plant operations, detailed I preparations are undertaken to provide a smooth transition from plant operations to site decommissioning. The organization required to manage the intended decommissioning activities is assembled from available plant staff and outside resources, as required. Preparations include the planning for permanent defueling of the reactor, revision of technical specifications appurtenant to the operating conditions and requirements, a characterization of the facility and major components,

.a.... . __

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Diablo Canyon P.:wer Plant Dscument P01-1252-002, Rev. 0

- Section 2, Page 3 cf 18 l

l and the develcpment of the PSDAR.

i' Eneineerine and Plannine Prior to the commencement of decommissioning operations the licensee will certify the permanent cessation of operations and the removal of fuel from the reactor vessel. The PSDAR, required within two years of l

the notice to cease operations, provides a description of the licensee's planned decommissioning activities, a timetable, and the associated financial requirements of the decommissioning program. Upon receipt of the PSDAR, the NRC will make the document available to the public for comment in a local hearing to be held in the vicinity of the reactor site.

Ninety days following submittal and NRC receipt of the PSDAR, the licensee may begin to perform major decommissioning activities under a l modified g50.59 procedure, i.e., without specific NRC approval. Major l activities are defined as any activity that results in permanent removal of major radioactive components (primary coolant system components /

piping), permanently modifies the structure of the containment (removal l

of the bioshield), or results in dismantling components containing I

l Greater than-Class C waste!(GE'O as defined under g61). Major l radioactively-contarainated corr .ents are further defined as comprising the reactor vessel and internals, steam generators, pressurizer, large bore reactor coolant system piping, and other large  ;

l 1

! components. The NRC includes the following additional criteria for use of the g50.59 process in decommissioning: the proposed activity must not j l

l 1) foreclose release of the site for possible unrestricted use, 2) i significantly increase _ decommissioning costs, 3) cause any significant

. environmental impact, or 4) violate the terms of the licens 3e's existing l license. Consequently, in conjunction with the developruent of the l PSDAR, activity specifications, cost benefit and safety malyses, work l packages and procedures, etc. must be assembled in support of the l proposed decontamination and dismantling activities.

The decommissioning program outlined in the PSDAR will be designed l

to accomplish the required tasks within the As Low As Reasonably-Achievable (ALARA, as defined in g20) guidelines for protection of personnel from exposure to radiation hazards. It will also address the continued protection of the. health and safety of the public and the environment during the dismantling activity.

The NRC recognizes that the existing operational tecimical specifications will require review and modifications to refle'c t plant  ;

i '

DI:bla Canyon Pow:rPlant Document P011252-002, Rev. 0 Sectlan 2, Page 4 ef18 r

P conditions and the safety concerns associated with peruanent cessation of operations. The environmental impact associated with the planned l

decommissioning activities must also be considered; an environmental report on specific and unique concerns must be submitted to the NRC for consideration and possible preparation of an environmental impact statement.

Much of the work in preparing the PSDAR is also relevant to the development of the detailed engineering plans and procedures. This work includes, but is not limited to:

1. Site preparation plans for the proposed decommissioning activities.

2. Detailed procedures and sequences for removal of systems and

! components.

3. Evaluation of the disposition alternatives for the reactor vessel and its internals.

4. Plans for decontamination of structures and systems.

5. Design / procurement and testing of tooling and equipment.

6. Identification / selection of specialty contractors.

i

7. Procedures for removal and disposal of radioactive materials.

8. Sequential planning of activities to minimize conflicts with ,

simultaneous tasks. {

Site PrenaratiQm j Following final plant shutfnwn and in preparation for actual decommissioning activities, the following activities are initiated.

1. Prepare site support and storage facilities, as required.

2. Perform site characterization study to determine extent of site

- contamination.

3. Isolate spent fuel storage services and fuel handling systems located in the Fuel Handling Building from the power block such that decommissioning operations can commance on the balance of the J i

i

Disblo Canyon P2werPlant Document P01-1252-002, Rev. 0 l Section 2, Page 5 cf18 1

plant. This activity may be carried out by existing plant personnel in accordance with existing operating technical specifications.

Decommissioning operations are assumed to be scheduled around the Fuel Handling Building to the greatest extent possible, such that the overall project schedule is optimized. Current dry storage cask designs are licensed for spent fuel with a core discharge decay time  !

averaging approximately five years or longer. Considering the longer fuel cycles and higher fuel burnup, the fuel at DCPP may require up i to eight years of active cooling before being relocated to dry storage.  !

Therefore, decommissioning operations for the Fuel Handling Building cannot be expected to begin prior to eight years after the cessation of plant operations. As spent fuel decays to the point that it meets the heat load criteria of the dry storage casks, it will be transferred either to the on site ISFSI or to the DOE high-level waste repository. It is assumed that all fuelis transferred from the Fuel Handling Building within approximately 96 months after cessation of operations at each unit.

4. Clean all plant areas of loose contamination and process all liquid and solid wastes.

5. Conduct radiation surveys of work areas, major components (including the reactor vessel and its internals), sampling of internal piping contamination levels, and primary shield cores.

6. Correlate survey data and normalize for development of packaging and transportation procedures.

7. Determine transport and disposal container requirements for activated materials and/or hazardous materials, including shielding and stabilization. Fabricate or procure such containers.

8. Develop procedures for occupational exposure control, control and release of liquid and gaseous efHuent, processing of radwaste including DAW, resins, filter media, metallic and non metallic 1 components - generated in decommis.sioning, site security and emergency programs, and industrial safety.

Following submittal of the PSDAR and certification of permanent fuel removal from the reactor vessel, the licensee may commence major decommissioning activities. Full access to the decommissioning fund wdl require the preparation of a detailed site-specific cost estimate for submittal to the NRC. In addition, a license termination plan, must be

Dirbh C:nyon P:wer Pl:nt Document P01-1252-002, Rev. 0

- Sectisn 2, Page 6 of18 prepared at least two years prior to the license termination date.

. 2.1.2 Period 2 - Decommissionina Ooerations & License Termination For the DECON alternative, significant decommissioning activities involve the following steps:

1. Construct temporary facilities and modify existing storage facilities to support the dismantling activities. These may include additional changing rooms and contaminated 1 sundry facilities for increased work force, establishment of laydown areas to facilitate equipment removal and preparation for off site transfer, upgrading roads to facilitate hauling and transportation, and modifications to the Reactor Building to facilitate access oflarge/ heavy equipment.

2. Design and fabricate shielding in support of removal and transportation activities as well as contamination control envelopes; specify/ procure specialty tooling and remotely operated equipment.

Modify the refueling canal to support segmentation activities and prepare rigging for segmentation and extraction of heavy components, including the reactor vessel and its internals.

3. Procure required shipping canisters, cask liners, and Industrial Packages (IPs) from suppliers.

4. Conduct decontamination of components and piping systems as required to control (minimize) worker exposure. Remove, package, and dispose of all piping and components that are no longer essential to support decommissioning operations.

5. Remove control rod drive housings and the head service structure from reactor vessel head and package for controlled disposal.

{ 6. Segment reactor vessel closure head and vessel flange for shipment in cask liners. Load overpack liners into shielded casks or place in shielded vans for transport.

7. Segment uppe: internals assembly, including upper support assembly, deep beam weldment, support columns, and upper core plates; package segments in shielded casks. These operations are performed remotely by cutting equipment located underwater in the refueling canal. Package and dispose ofitems that meet 61 " Class

l Disblo Canyon P:wer Plant D:cume, P01-1252-002, Rev. 0

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l C" criteria or less.  ;

8. Disassemble / segment remaining reactor internals in shielded casks.

These internals include core barrel, core bafHe/former assembly, thermal shields, lower core plate, and lower core support assembly.

The operations. are also conducted under water using remotely 1' operated tooling and contamination controls. Package and dispose of items that meet g61 " Class C" criteria or less.

9. Package g61 GTCC components into fuel bundle containers for handling and storage along with the spent fuel assemblies. Transfer fuel bundle containers to the Fuel Handling Building or suitable storage location.

10. Segment /section the reactor vessel, placing segments into shielded containers. The operation is performed remotely in air using a contamination control envelope. Sections are placed in containers l stored under water (for example in an isolated area of the refueling canal) using a remote or shielded crane. Transport the containers using shielded truck casks.

11. After the vessel water level drops below the elevation of the reactor  ;

vessel inlet and outlet nozzles during vessel segmentation, remove the reactor coolant piping and pumps. Package the piping in IPs; the reactor coolant pumps are sealed with steel plate so as to serve as their own containers. Ship piping and pumps for controlled disposal.

12. Remove systems and associated components as they become non-essential to the vessel removal operation, related decommissioning activities or worker health and safety (e.g., waste collection and processing systems, electrical and ventilation systems, etc.).

13. Remove activated concrete biological shield and accessible contaminated concrete (excluding steam generator and pressurizer cubicles). If dictated by the steam generator and pressunzer removal scenarios, remove those portions of the associated cubicles necessary for access and component extraction.

14. Remove steam generators and pressurizer for shipment and contwlled disposal. Remove steam domes from generators as the diameter exceeds the clearance requirements dictated by rail transport. Weld an end cap over the exposed tube bundle on the r

[.

r-Di:bb Cd,; yon PowerPlant D:cument P01-1252-002, Rev. 0 Section 2, Page 8 of 18 lower shell units. Decontaminate exterior surfaces, as required, and seal weld openings (nozzles, inspection hatches, and other penetrations). These components can serve as their own burial containers provided that all penetrations are properly sealed and the internal contaminants are stabilized. Add steel shields to those external areas of the steam generator lower shell units to meet transportation limits and regulations. Segment s! nam generator steam domes to meet individual package weight restrictions and transport dome segments offsite for recycle.

The preparation of a termination plan is required at least two years prior to the anticipated date of license termination. 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 any reuse 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 and make the plan available for public comment. A local hearing will also be scheduled.

Plan approval may be subject to conditions and limitations as deemed appropriate by the NRC. The licensee may then commence with the final remediation of site facilities and services, including:

1. Remove steel liners from the refueling ccnal and containment, including any contaminated canal concrete, and route for controlled disposition.

2. Remove contaminated equipment and material from the Auxiliary Building. Remediate until radiation surveys indicate that the structure can be released for unrestricted access.

3. Remove contaminated equipment and material from the Fuel Handling Building following the transfer of all residual spent fuel to either an onsite storage facility or a federal facility offsite. Remediate Fuel Handling Building areas until radiation surveys indicate that the structure can be released for unrestricted access.

4. Decontaminate remaining site buildings and facilities with residual contaminants. Remove all remaining low-level radioactive waste along with any remaining hazardous and toxic materials. Material removed in the decontamination and dismantling of the nuclear units will be routed to an on site central processing area. Material certified to be free of contamination will be released for unrestricted disposition, e.g., as scrap, 7:eycle or general disposal. Conta'minated I

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material will be characterized and segregated for additional on site decontamination, off site processing (disassembly, chemical cleaning, volume reduction, waste treatment, etc.) and/or packaged for controlled disposal at the regional low level radioactive waste disposal facility.

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

6. Conduct final radiation survey to ensure that all radioactive materials in excess of permissible residual levels have been remediated. This survey may coincide with final NRC site inspection.

Incorporated into the License Termination Plan, the Final Survey Plan details the radiological surveys to be' performed once the decontamination activities are completed. The Final Survey Plan is developed using the guidance provided in NUREG/CR-5849, " Manual for Conducting Radiological Surveys in Support of License Termination. This docume.it delineates the statistical approaches to survey design and data interpretation used by the Environmental Protection Agency (EPA). It also identifies state-of the art, commercially available, instrumentation and procedures for conducting radiological surveys. Use of this guidance ensures that survey design and implementation 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 revie'ws and evaluates the information, performs an independent confirmation of radiological site conditions, and makes a determine; ion on final termination of the license.

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

l 2.1.3 Period 3 - Site F9storation Following completion of decommissioning operations, site restoration

' activities may begin. Eflicient 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. Blasting, coring, drilling, scarification (surface removal),

t

Diablo Canyon PowerPlant Document P01-1252-002, Rev. 0 Section 2, Page 10 cf18 233552 and~ the -other' decontamination activities will substantially damage power block structures including the Reactor, Auxiliary and Turbine Buildings. Verifying that subsurface radionuclide concentrations meet NRC site release requirements may 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 j subsurface process' ar.d drain lines were not breached over the 1 operating life of the station.

Prompt dismantling of site structures is clearly the most appropriate and cost-effective option. It is unreasonable to anticipate that these j structures would be repaired and preserved after the radiological contamination is removed. The cost to dismantle site structures, with a work force already mobilized on site, is more efficient and less costly than if the process is deferred. Site facilities quickly degrade without continual 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. j This cost study presumes that non-essential structures and site facilities will be dismantled as a continuation of the decommissioning activity.

Foundations and exterior walls are assumed to be removed to a nominal depth of three feet below grade. This depth of removal allows for clear-ance of the exposed rebar mats, embedded conduit and piping and struc-tural steel produced in demolition. The three foot depth also allows for the placement of both gravel for drainage, as well as topsoil so that vegetation can be established for erosion control. Site areas affected by the dismantling activities are cleaned and the plant area graded as re-quired to prevent ponding and inhibit the refloating of subsurface ma-terials.' Activitiesinclude:

1. Perform demolition of the rerr.ainmg portions of the containment structure and interior portior,s of the Reactor Building. Internal floors and walls are removed kom the lower levels upward, using c:ntrolled blasting techniques. Concrete rubble and clean fill produced by demolition activities are used on site to backfill voids.

Suitable materials can be used on site for fill; otherwise the rubble is trucked off site for disposal as construction debris.

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Dizblo Ccnyon PowerPlant . Document P01-1252-002, Rev. 0 Section 2, Page il cf18 l

2. Remaining buildings are then removed using conventional j demolition techniques for above ground structures, including the  !

Turbine Generator Building, Auxiliary Building, Control Building,  !

Fuel Handling Building, and other site structures, including the Breakwater.

3. Prepare the final dismantling program report.  !

l 2.1.4' ' Post Period 3 - ISFSI Ooerations and Demolition l Following the transfer of the spent fuel inventory from the Fuel l Handling Buildings, the ISFSI will continue to operate under a separate l and independent license ($72). Transfer of spent fuel to a DOE or  !

interim facility will be exclusively from the ISFSI once the fuel pools  !

have been emptied and the structure released for decommissioning.

Assuming initiation of the federal Waste Management System in 2010, transfer of spent fuel is assumed to begin in 2017 and continue for a  ;

i period of approximately 17 years, with the final spent fuel shipment presumed to occur in the year 2034.

At the conclusion of the spent fuel transfer process, the ISFSI will be  ;

decommissioned. Long-term exposure from the spent fuel assemblies will have produced low level neutron activation of the interior surfaces of the dry storage modules to levels exceeding current release limits.

Consequently, portions of the modules will be disposed of as low level radioactive waste.

The Commission will terminate the $72 license ifit determines that site remediation has been performed in accordance with a license termination plan and the terminal radiation survey and associated documentation demonstrate that the facility is suitable for release. Once the requirements are satisfied, the NRC can terminate the license for the ISFSI.

The reinforced concrete dry storage modules are then demolished and disposed of as clean fill, the concrete loading ramps are removed, and the area graded and landscaped to conform with the surrounding environment.

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

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DI:bb Canyon Power Plant Document P01-1252-002, Rev. 0

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I safely stored and subsequently decontaminated (deferred decontamination) to levels that permit release for unrestricted use." The facility is left intact, (during the SAFSTOR period) with structures maintained in a sound condition.

Systems not required to operate in support of the spent fuel pool or site surveillance and security are drained, de energized, and secured. Minimal cleaning / removal of loose contamination and/or fixation and sealing of remniping contamination is performed. Access to contaminated areas is secured to provide controlled access for inspection and maintenance.

The engineering and plannmg 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 - SAFSTOR Ooerations As described in Section 2.1, notification would 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 re-initiating reactor operations. Within two years of notification to cease i reactor operations, the licensee is required to provide a PSDAR. This . I report provides a description of the licensee's planned decommissioning activities, a corresponding schedule and an estimate of expected costs.

The PSDAR will also address whether environmental impacts associated with the proposed decommissioning scenario differ from those already considered in previously prepared environmental statement (s).

Ninety days following the NRC's receipt of the PSDAR, the licensee may initiate certain decommissioning activities without specific NRC approval, under a modified 50.59 review process.

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 alternative SAFSTOR. After an j optional period of storage (up to 60 years after permanent cessation of I operations), it is required that the licensee submit an application to terminate the license, along with a termination plan, thereby initiating  !

the third phase. The termination plan would contain a stailed site characterization, i.e., location, type and amount of raa_0 activity, a description of any remaining dismantling activities to be accomplished, {

detailed plans for a final survey, and the planned end use of the site. An

I Disblo Canyon Power Plant Document P011252 002, Rw. 0 Section 2, Page 13 of 18 l updated cost to complete the decommissioning would be required along with a report of any new or altered environmental consequences. In anticipation of the cessation of plant operations, detailed preparations are undertaken to provide a smooth transition from plant operations to '

site decommissioning. The organization required to manage . the intended decommissioning program is assembled from available plant staff and outside resources, as required. Preparations include the planning for permanent defueling of the reactor, revision of technical specifications appurtenant to the operating - conditions and requirements, a characterization of the facility and major components, and the development of the PSDAR.

The program outlined in the PSDAR will be designed to accomplish the  ;

required tasks within the ALARA guidelines for protection of personnel from exposure to radiation hazards. It also addresses the continued protection of the health and safety of the public and the environment.

The NRC recognizes that the existing operational technical specifications will require review and modifications to reflect plant conditions and the safety concerns associated with permanent cessation of operations. The environmental impact associated with the planned decommissioning activities must be considered; an environmental report on those concerns not already assessed must be submitted to the NRC for consideration and possible preparation of an environmentalimpact statement.

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

1. Isolate spent fuel storage services and fuel handling systems located in the Fuel Handling Building from the power block 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 assumed to be scheduled around the fuel handling systems to the greatest extent possible. The spent fuel contained within dry storage casks at the time of shutdown will remain in dry storage until shipment to DOE can be completed. All remaining spent fuel on site will continue to be stored in the existing spent fuel pools awaiting pickup by DOE. The existing spent fuel storage facilities will continue to operate until all spent fuel is removed from the site. This is currently projected to occur in 2034.

l

Diablo Ccnyon PowerPl nt Document P01-1252-002, Rev. 0 Section 2, Page 14 cf18 j l'

2. Drain /de energize / secure all non contaminated systems not required a

to support dormancy operations.

3. Dispose of contaminated filter elements and resin beds not required for processing wastes from decontamination activities.

l

4. Drain reactor vessel; internals will remain in place.  !

5. Drain /de energize / secure all contaminated systems. Decontaminate systems as required for future maintenance and inspection.

6. Prepare lighting and alarm systems whose continued use is required.

De-energize and/or secure portions of fire protection, electric power, and HVAC systems whose continued use is not required.

7. Clean loose surface contamination from buildin'gaccess pathways.

8. Perform an interim radiation survey of plant; post warning signs as appropriate.

9. Erect physical barriers and/or secure all access to radioactive or cor.aminated areas, except as required for controlled access, i.e.,

inspection and maintenance.

10. Ship spent fuel to a DOE or intermediate facility - continuously throughout Period 1 and into the dormancy period.

11. Install security and surveillance monitoring equipment and relocate security fence around secured structures, as required.

12. This study assumes that demolition would be delayed for those I structures which are located outside the secured area until after the termination of the license.

si 2.2.2 Period 2 - SAFSTOR Dormancy Activities required during the planned dormancy period for the SAFSTOR alternative include a 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> guard force, preventive and corrective maintenance on security systems, area lighting, general {

building maintenance, heating and ventilation of buildings, routine i radiological inspections of contaminated structures, maintenance of l structural integrity, and a site environmental and radiation monitoring program. The length of the dormancy period selected for each unit is

i Dinblo Canyon Power Plant Document P011252-002, Rev. 0 Section 2. Page is of18 i

(

approximately 30 years.

Spent fuel transfers, from the existing ISFSI and the Fuel Handling Buildings to a federal repository, will continue until the year 2034.

Equipment maintenance, inspection activities and routine service are performed by resident maintenance personnel. This work force will maintain the structures in a safe condition, provide adequate lightmg,  :

heating, and ventilation, and perform periodic preventive maintenance on essential site services.

An environmental surveillance program is carried out during the dormancy period to ensure that potential releases of radioactive material to the environment are detected and controlled. Appropriate emergency procedures are established and initiated for potential releases that exceed prescribed limits. The environmental surveillance program constitutes an abbredated 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. Security will be provided by the security fence,  !

sensors alarms, surveillance equipment, etc., which must be maintained in good condition for the duration of this period. Fire and radiation alarms are also to be monitored and maintained. While remote ,

surveillance is an option, it does not offer the immediate response time of a physical presence.

Variations in the length of the dormancy period are expected to have little effect upon the quantities of radioactive wastes generated from system and structure removal operations. While there will be a decrease in the contamination levels present on all surfaces due to radioactive decay over an increased dormancy duration, it is not expected that any material that is non releasable at the time of shutdown will decay to a releasable state over the permissible time frame (i.e. 60 years maximum.) Without detailed contamination characterization information, it is not possible to make any further assumptions concerning contarr 'f.ation levels.

Given the levels of radioactivity and spectrum of radionuclide's expected from forty 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 waste

1

'Diablo Cenyon P.:werPlant Document P01-1252-002, Rev. 0 Section 2, Page 16 of18 )

{

l l

1 i

volume in delaying decommissioning. In fact, SAFSTOR estimates can ] '

show a slight increase in the total projected waste volume, due primarily to initial preparation activities for placing the units in safe-storage, as well as from follow up housekeeping tasks over the caretaking period for the station. Since the SAFSTOR option does not require system flushes I for decontamination purposes, the waste volumes associated with the I liquid waste processing have been eliminated. In this case, the cost I estimate showed a small decrease in the totallow-level waste volume in the SAFSTOR mode relative to DECON, The delay in decommissioning yields lower working area radiation levels'. As such, the difference between tl e prompt and delayed scenarios is moderated by reduced ALARA contro!s for the SAFSTOR's lower 4 occupational exposure potential. Because this alternative provides a  !

period of decay for the residual radioactive material, lower radiation )

i fields are encountered than with the DECON alternative. Some of the I

dismantling activities may niploy manual techniques rather than remote procedures. Thus, dismantling operations may be simplified for ,

some tasks. However, this study does not attempt to quantify this )

effect, because it would have an immaterial impact on overall costs. i

?

I 2.2.3 Eeriods 3 - 4 Deferred Decommissioning A termination plan must be prepared at least two years prior to the .

I anticipated date of license termination. Submitted as a supplement to the FSAR, or equivalent, the plan must include a site characterization, description of the remaining dismantling activities, plans for site remediation, detailed plans 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 ad make the plan available for public comment. A local hearing will also be scheduled. Plan approval will be subject to any conditions and limitations deemed appropriate by the NRC. The licensee may then commence with tL2 fit.al remediation of site facilities and plant services.

Although the initial radiation levels due to SoCo will decrease significantly during the dormancy period, the internal components of the I reactor vessel will still exhibit sufficiently high radiation dose rates to require remote sectioning under water due to the presence oflong lived radionuclides such as 84Nb and 59Ni. Therefore, the dismantling procedures described for the DECON alternative wotdd still be employed during SAFSTOR. Portions of the biological shield will still be I

l i

I l Dicbio Canyon P:werPlcnt Document P01-1252-002, Rev. 0 k

' Section 2, Page 17 of n l l

1 radioactive due to the presence of activated trace elements with long j

halflives (132Eu and mEu). Decontamination will require co~miled I l removal and disposal. It is assumed that radioactive corrosion pwducta on inner surfaces of piping and components will not have decayed to

)

l l l levels that will permit unrestricted use or allow conventional removal.

l These systems and components are surveyed as they are removed and j disposed ofin accordance with the existing radioactive release criteria.

Prior to the commencement of decommissioning operations, preparations l are undertaken to reactivate site service and prepare for decommissioning. Preparations include engineering and planning, a detailed site characterization, as well as the assembly 'of a

decommissioning management organization. Final planning for activities and 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, as well as the follow on l decontamination and dismantling processes are detailed in Sections l 2.1.1 and 2.1.2. The primary difference between the sequences

! -anticipated for the DECON and SAFSTOR scenarios is the absence, in the latter, of any constraint on the availability of the Fuel Handling Building for decommissioning. The timing for the.SAFSTOR scenario is such that the spent fuelinventory has been removed from the site prior to the initiation of decontamination and dismantling activities, l eliminating a significant scheduling hindrance. Any GTCC material l generated in the segmentation of the reactor vesselinternals is assumed l to be directly routed to DOE's geological facility, without the need to j provide for interim storage on site.

Incorporated into the License Termination Plan, the Final Survey Plan details the radiological surveys to be performed once the decontamination activities are empleted. The Final Survey Plan is myeloped using the guidance provided in NUREG/CR 5849, " Manual for Conducting Radiological Surveys in Support of License Termination." This document delineates the statistical approaches to survey design and data interpretation used by the Environmental Protection - Agency (EPA). It also identifies state of the-art, commercially available, instrumentation and procedures for conducting radiological surveys. Use of this guidance ensures that survey design and implementation are conducted in a manner that provides a high degree of confidence that applicable NRC criteria are

Dizbl3 Canyon P:wer Pl:nt D:cument P01-1252-002, Rev. O \

Section 2, Pcge 18 of18 '

t l

l 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 l evaluates the information, performs an independent confirmation of l radiological site conditions, and makes a determination on final termination of the license. The NRC will terminate the license if it determines that site remediation has been performed in accordance with the license termination plan and the terminal radiation survey and associated documentation demonstrate that the facility is suitable for release.

2.2.4 Period 5 - Site Restoration For the SAFSTOR alternative, the site restoration activities are the same as those for DECON Period 3, without restriction on the availabil-ity of the Fuel Handling Building or ISFSI for dismantling and demoli-tion.

- Disblo Canyon P:wer Plant Document P01-1252-002, Rev. 0 Section 3, Pcge i ci'22

3. COST ESTIMATE

. A site-specific cost estimate was prepared' for decommissioning DCPP. This estimate-accounts for the unique. features of the site,' including the primary coolant system, electric power ' generation systems, site buildings, and structures. The basis of the estimate an'd its sources of information, methodology, site specific considerations, assumptions and total costs are described in this section.

3.1 BASIS OF ESTIMATE A' site specific cost estimate was developed using drawings and plant

' documents provided by PG&E. Components were inventoried from the mechanical and electrical Piping & Instrument Diagrams (P&ID). Structural drawings and design documents were used to analyze the general arrangement of the facility and to determine estimates of building concrete volumes, steel quantities, numbers and sizes of major components, and areas of the plant to

. be addressed in remediation of the site.

Representative labor rates for each designated craft and salaried worker were provided by PG&E for use in construction of the unit removal factors, as well as for estimating the carrying costs for site management, worker supervision and essential support services, e.g., health physics and security.

For purposes of constructing the decommissioning cost estimate, a base burial rate of $509 per cubic foot was used for low level radioactive waste disposal within the Southwest Compact. The assumed disposal rate was derived from projections developed by the site developer, US Ecology, and through discussions with PG&E.

3.2 METHODOLOGY The methodology used to develop this cost estimate follows the basic approach originally presented in the AIF/NESP 036- study report, " Guidelines for Producing Commercial Nuclear Power - Plant Decommissioning Cost Estimates," (Ref. 7) and the US DOE " Decommissioning Handbook" (Ref. 8).

These references utilize a unit cost factor method for estimating decon missioning activity costs, which sir 2pliS9s the estimating calculations.

Unit cost factors for concrete removal ($/ cubic yard), steel removal ($/ ton), and cutting costs ($/ inch) were developed from the labor cost information provided

-by PG&E. The activity denendent costs are estimated with the item quantities (cubic yards, tons, inches, etc.) developed from plant drawings and inventory

~ documents.

1

Dizbis Canyon P:wer Plant D:cument P01-1252-002, Rev. 0

. Section 3, P:ge 2 of 22 233552 The unit cost factors used in this study reflect the latest available information about worker productivity in decommissioning, including the Shippingport Station Decommissioning Project completed in 1989, as well as from TLG's involvement in the decommissioning planning and engineering for the Shoreham, Yankee Rowe, Trojan, Rancho Seco, Pathfinder, and Cintichem reactor facilities.

An activity duration critical path was. used to determine the total decommissioning program schedule. The program schedule is _ used to determine the neriod denendent costs for program management, administration, field engineering, equipment rental, quality assurance, and security. The study used' typical salary and hourly rates for personnel associated with period-dependent costs for the region in which the station is located. Some of the costs for removal of radioactive components / structures were based on information obtainad from the " Building Construction Cost Data," published by R. S. Means (Ref. 9). Examples of unit oost factor development are presented in the AIF/NESP-036 study (Ref. 7). Appendix A presents the detailed development of a typical site-specific unit cost factor.

Appendix B provides the values contained within one set of factors developed for the DCPP analyses.

' The unit cost factor method provides a demonstrable basis for establishing reliable cost estimates. The detail of activities provided in the unit cost factors for activity time, labor costs (by craft), and equipment and consumable costs provides assurance that cost elements have not been omitted. These detailed unit cost factors, coupled with the plant specific inventory of piping, compo-nents and structures, provide a high degree of confidence in the reliability of the cost estimates.

( 3.3 FINANCIAL COMPONENTS OF THE COST MODEL The DECCER cost modelis composed of a number of distinct cost line items, calculated using the unit cost factor methodology described earlier, as well as additional cost elements in support of the 6 eld activities. These calculated costs in and of themselves, however, do not comprise the total cost to accomplish the project goal, i.e. the license termination and site restoration of the DCPP.

l 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, labor stoppages, etc. In the DECCER cost model, contingency fulfills this role. Contingency is added to each line item to account for costs that are difHeult or impossible to develop analytically. Such costs are historically inevitable over the duration of a job of

Diabis Canyon PawerPl:nt Document P01-1252-002, Rw. 0 Section 3, Page 3 ef 22 this magnitude; therefore, this cost analysis includes moneys to cover these types of expenses. Further discussion of this subject is presented below. ,

l In addition to the routine uncertainties that contingency addresses, another cost element that is necessary to consider when answering the question of decommissioning costs relates to other types and levels of uncertainties. These consist of changes in work scope, pricing, job performance and other variations that could conceivably, but not necessarily, occur. Consideration of such items may be-' necessary to address the question concerning how costly the decommissioning project could become, within a range of probabilities. TLG considers these types of costs under the broad term " financial risk." This cost study, however, does nv add any additional costs to the estimate for financial  ;

risk.

3.3.1 Contineencv The activity- and period-dependent costs are combined to develop the total decommissioning costs. 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" (Ref.10) 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 willincrease costs are likely to occur." The cost elements in this estimate are based upon ideal conditions and maximum efficiency; therefore, consistent with industry practice, a ,

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

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. Some of the rationale for (and need to incorpora%)

contingency within any estimate is offered in the following discussion.

An estimate without contingency, or from which contingency has been removed, can disrupt the orderly progression of events and jeopardize

Dh:bls Crnyon Power PI1nt Document P01-1252-002, Rev. 0

.' Section 3, Pzge 4 cf 22 a successful conclusion to the decommissioning process.

The' most technologically challenging task in decommissioning a commercial nuclear station will be the disposition of the reactor vessel and internal components, which have become highly radioactive after a lifetime of exposure to radiation produced in the core. The disposition of these highly radioactive components forms the basis for 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, i 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 risk and uncertainties associated with this task are that the expected optimization 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 specialty tooling modifications and repairs, field changes, discontinuities in the coordination of plant services, system failure, water clarity, lighting, computer controlled cutting software corrections, etc. Experience in decommissioning other plants in the j past has shown that many of these problem areas have occurred l during, and in support of, the segmentation process. Contingency j dollars are an integral part of the total cost to complete this task. [

Exclusion of this component puts at risk a successful completion of the intended tasks and, potentially, follow on related activities. ,

I The following list is a composite of some of the activities, assembled from past decommissioning programs, in which contingency dollars were needed to respond to, compensate for, and/or provide adequate funding of decontamination and dismantling tasks:

1

\

Disbis Cernyon P:wer Plant ~ Document P01-1252-002, Rev. 0

Section 3, P:ge 5 ef 22 Incomplete or Changed Conditions:

. Unavailable / incomplete operational history which led to a recontamination of a work area, because a sealed cubicle (incorrectly identined as being non contaminated) was breached without controls.

. Surface coatings covering contamination which, due to an incomplete characterization, required additional cost and time to remediate.

. Additional decontamination, controlled removal, and disposition of previously undetected (although at some sites, suspected) contamination due to access gained to formerly inaccessible areas and components.

. Unrecorded construction modifications, facility upgrades, maintenance, enhancements, etc., which precipitated scheduling delays, more costly removal scenarios, additional costs (e.g., for re-engineering, shoring, structural modifications), and compromised worker safety.

Adverse Working Conditions:

• Lower than expected productivity due to high temperature environments, resulting in a change in the working hours (shifting to cooler periods of the day) and additional manpower.-

. Confined space, low-oxygen environments where supplied air was necessary and additional safety precautions prolonged the time required to perform required tasks.

Maintenance, Repairs and Modifications e Facility refurbishment required to support site operations, including those needed to provide new site services, as well as to maintain the integrity of existing structures.

• Damage control, repair, and maintenance from birds'

Dl:bla C:nyon P werPl:nt . Document P01-1252-002, Rev. 0 Section 3, Page 6 cf 22 i

nesting and fouling of equipment and controls.

.- Building modification, i.e., re supporting of. floors to enhance loading capacity for heavily shielded casks.

.- Roadway. upgrades on site to handle heavier and Jwider loads; roadway rerouting, excavation, and reconstruction.

1

. Requests for additional safety margins by a vendor.

. Requests -to analyze accident scenarios beyond those defined by the removal scenario (requested by the NRC to comply with " total scope of regulation").

. Additional collection of site runoff and processing of such due to disturbance of natural site contours and drainage.

. Concrete coring for removal of embedments and internal f conduit, piping, and other potentially contaminated 1 material not originally identified as being contaminated.

. Modifications required to respond to higher than expected worker exposure, water clarity, water disassociation, and-hydrogen generation from high temperature cutting operations.

. Additional waste containers needed to accommodate cutting particulates (fines), inefficient waste geometries and excess material.

Labor

. Turnover of personnel, e.g., craft and health physics.

Replacement of labor is costly, involving additional training, badging, medical exams, and associated processing procedures. Recruitment costs are incurred for more experienced personnel and can include relocation and living expense compensation.

. Additional personnel required to comply with NRC mandates and requests.

L

Di blo C:nyon PowerPirnt Documznt P01-1252-002, Rev. 0

- Sectlan 3, Page 7 ef 22

. Replacement of personnel due to non qualification and/or incomplete certification (e.g., welders).

Schedule

. Schedule slippage due to a conflict in required resources, i.e., the licensee was forced into a delay until prior (non-licensee) commitments of outside resources were resolved.

. Rejection of material by NRC inspectors, requiring refabrication and causing program delays in activities I required to be completed prior to decommissioning operations.

Weather

. Weather related delays in the construction of facilities required to support site operations (with compensation for delayed mobilization made to vendor).

t

. Frozen crane hydraulics prior to a major lift.

. Destruction of an exterior asbestos containment enclosure due to violent winds.

The cost model incorporates considerations for items such as those described above, generating contingency dollars (at varying percentages of totalline item cost) with every activity.

3.3.2 Financial Risk Financial risk, as defined previously in this cost study, refers to the possibility and associated probabilities of certain events occurring that could increase or decrease costs for decommissioning. TLG's l methodology, when asked to perform a risk analysis, is to use a Monte Carlo simulation program such as @ Risk (Ref.11) for Microsoft Excel.

A Monte Carlo analysis of a decommissioning project examines the range of values that certain inputs could assume. The model req.uires the input of a distribution of values over this range; the distribution most often used for cost estimating is a triangular distribution. .All independent variables to be examined are assigned a high endpoint, low

DE:blo Cxnyon Pawer Plant Document P01 1252-002, Rev. 0

. Section 3, P:ge 8 of 22 endpoint, and most likely midpoint to denne their distribution. The l '

actual analysis involves picking random values from within each range for each variable and recalculating the total cost at each iteration. The output of a Monte Carlo simulation typically includes a curve and range of probabilities for various cost estimates.

Included within the category of financial risk are:

• Delays in approval of the decon4missioning plan due to intervention, public participation in local community meetings, legal challenges, state and local hearings, etc..

. 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 federal and state commitments, e.g., in the ability to accommodate certain waste forms for disposition, or in the timetable for such.

. Pricing changes for basic inputs, such as labor, energy, materials, and burial. Some of these inputs may vary slightly, e.g. -10% to +20%; burial could vary from -50% to

+200% or more.

It has been TLG's experience that the results of a risk analysis, when compared with the base case estimate for decommissioning, indicate that the chances of the base decommissioning estimate's being too high is a low probability, and the chances that the estimate is too low is a much higher probability. This is mostly due to the pricing uncertainty for low level radioactive waste burial, and to a lesser extent due to schedule increases from changes in plant conditions, and to pricing variations in the cost of labor (both craft and staff). TLG did.not perform a risk analysis for the DCPP and therefore the cost estimates in this report do not include any increase in decommissioning costs as l

. Dlublo Canyon P:werPlant D2cument P01-1252-002, Rev. 0

. Section 3, Page 9 cf 22 a result of any risk analysis performed for PG&E or any other TLG client.

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

3.4.1 Soent Fuel Disoosition ,

For purposes of this cost study, PG&E provided a spent fuel scenario management p?an that addressed the storage scenario for both PG&E nuclear units. The PG&E spent fuel disposition scenario assumes that DOE will begin receipt of spent fuel from DCPP in 2017. It also assumes construction of an on-site dry fuel storage facility prior to final plant shutdown in order to support continued plant operations. For the DECON scenario, the fuel will remain in wet storage in the existing fuel pool (s) for eight years following shutdown c# each unit. During this time, the existing ISFSI will be expanded to accept the inventory of fuel from the pools. All fuel will be transferrad to the ISFSI within eight years of final unit shutdown. The last spent fuel shipment is expected to occur in 2034.

For the SAFSTOR scenario, the fuelin the spent fuel pool (s) at the time of unit shutdown will remain in wet storage until transfer to the DOE or other intermediary occurs. No expansion of the ISFSI is assumed to support decommissioning; tl e existing IEFSI will continue to operate, in parallel with the wet fuel stc rage activity until all spent fuel is removed from the site. This is assumed to be completed by the end of year 2034.

3.4.2 Reactor Vessel and Internal Components The reactor pressure vessel and reactor internal components are segmented for disposal in shielded transportation casks. Segmentation and packaging of the internals' packages are performed in the refueling canal where a turntable and remote cutter will be installed. The vessel is segmented in place, using a mast mounted cutter supported off the lower head and directed from a shielded work platform installed overhead in the reactor cavity. Transportation cask specifications and Department of Transportation (DOT) regulations dictate segnientation and packaging methodology. All packages must meet the current

Disbb Canyon Pow:rPlant Document P01-1252-002, Rev. O Sectton 3, Page 10 ef 22 physical and radiological limitations and regulations. Cask shipments will be made in DOT-approved, currently available, truck casks.

The dismantling of reactor internals at DCPP will generate radioactive waste generally unsuitable for shallow land disposal (GTCC). Although the materialis not classified as high level waste, DOE has indicated it will accept title to this waste for disposal at the future high level waste repository. However, the DOE has not yet established an acceptance criteria or a disposition schedule for this material, and numerous questions remain as to the ultimate disposal cost and waste form requirements. As such, for purposes of this study, the GTCC waste has been packaged and disposed of as high-level waste, at a cost equivalent to that envisioned for the spent fuel.

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

3.4.3 Steam Generators and Other Primary Coolant System Comoonents The steam generators' size and weight, as well as their configuration in the Reactor Building and limited accees in the Reactor Building itself, places constraints on the intact removal of these components.

Modifications to the Reactor Building are necessary for component extraction, due to the fact that the only large access to tne building is the existing equipment hatch, located above grade level. To remove the generators through this hatch requires that the units be positioned horizontally, which becomes impossible due to physical impediments within the structure.

Determination of the removal strategy requires several different considerations. Considerations for the extraction process include modifications to the Reactor Building for removal of the generators, rigging needed to maneuver and extract the generators from the structure, and the component preparations needed to transport the  !

generators to a disposal site. f l

A potential method for removal (and the one used as the basis in this estimate)is the extraction of the generators through a hatch created in the side of the Reactor Building. Sections of concrete are removed to

T Disblo Canyon Power Plant Document P011252-002, Rev. 0

. Section 3, Page 11 of 22 create an opening large enough to extract the steam generators from the building. Removalof sections of the steam generator cubicle walls, adjoining floor slabs, and floor grating will also have to be accomplished to ' allow for the generators to be maneuvered to the opening.

The hatch would be re created using a diamond wire saw to section the containment wall into large blocks which could be removed. Once the building is opened, grating within the work area will be decontaminated and removed. Next, a trolley crane will be set up for l removal of the generators. By setting the trolley crane first, it can be used to lower portions of the steam generator cubicle walls that will have to be removed as part of the building modiBeation effort. It also can be used to help remove portions of the floor slab. A 15 foot section of the cubicle wall will be dismantled to allow the maneuvering of the generators within the building. Large cubicle wall sections will be lowered out of the Reactor Building using the trolley crane, where they l can be decontaminated and transported to the material handling area.

The upper steam generator domes will be disconnected from the i

surrounding piping and supports. The steam dome will then be rigged for removal. The steam domes will be cut from the lower shell units l and transferred to a laydown area for further segmentation. A j prefabricated end cap will mate with the exposed cut end on the lower i shell unit. This end-cap will cover the exposed lower shell tube bundle, recreating a leaktight container. The lower shell units will then be ,

disconnected from all piping and supports, riggad for removal and ]

l maneuvered into the open area where they will be lowered onto a dolly. The dolly will allow the lower end of the steam generator to rotate through the opening as it is being lowered. Nozzles and other i

openings will be welded closed. When this stage has been completed, the generator lower shell unit will be lifted onto a multi wheeled transporter and moved to an on site storage area to await transport to the disposal facility. The three remaining steam generators will be removed using the same technique. Once the components have been removed, a portion of the opening will be closed using concrete blocks.

A smaller opening will be covered with a temporary barrier to allow for future access.

Once at the storage area, each generator lower shell unit will have a two-inch thick carbon steel membrane welded to its outside surface for shielding during transport. The units will then be loaded onto a multi-wheeled transporter and moved to an on site rail head where they will

Dizbis C:nyon Pzwer Picnt Document P01-1252-002, Rev. 0 Section 3, Page 12 ef 22 233552 be shipped to the Ward Valley waste disposal facility. Depending upon the proximity of the rail head to the disposallocation, the units may be offloaded from the train and onto multi wheeled transporters to be i ,

moved for the remaining distance to the disposal site.

l The size and weight of the generator packages was a concern in evaluating transportation alternatives. As such, discussions were held with both the railroad and Lampson, Inc. (rigging), on the moving of the generators. Both companies have had experience with moving large nuclear components, and were able to supply costs based on the specific generator dimensions and weight. TLG was also able to apply its experience gained in the planning of the disposition of the steam generators at the Trojan site, where Lampson was a subcontractor.

4.4.4 hansnortation Methods For the purposes of the cost estimate, it was assumed that the low-level radioactive waste produced in the decontamination and dismantling of the nuclear units will be moved overland by truck, shielded van, rail, and/or multi wheeled transporter to the regional burial facility.

Transport costs were derived assuming a final destination of Needles, California, location of the proposed Southwest Compact site.

4.4.5 Low-Level Radioactive Waste Disnosal For purposes of constructing the decommissioning cost estimate, a base burial rate of $509 per cubic foot was used for low level radioactive waste disposal within the Southwest Compact. The value was derived from projections developed by the site developer, US Ecology, and through discussions with PG&E.

To the greatest extent practical, non compactable low level radioactive waste is treated to reduce the total volume of radioactive material requiring controlled disposal. The treated material meeting the '

regulatory and/or site release criteria is released as clean scrap, reauiring no further cost consideration. Material not meeting release criteria will be processed for volume reduction and packaged for controlled disposal as radioactive waste. Material / waste recovery and j recycling are assumed to be performed off site by a licensed processing j center.  !

Compactable DAW, such as booties, glove liners, respirator filter cartridges, shipping containers, radiological controls survey materials, i

I I

DI:bb Ccnyon Power Plent D:cument P01-1252-002, Rev. 0

. Sectinn 3, P:ge 13 of 22

)

etc. will be assumed to be drummed and compacted to 10% of their original volume. This is the minimum practical volume to which LLW can be compacted to reduce costs.

3.4.6 Site Conditions Followine Dmmmissionine l

Following the decommissioning effort, the structures and remammg i systems will meet the specified NRC site release limit. The NRC involvement in the decommissioning process typically will end at this point. Local building codes, state environmental regulations and PG&E's own future plans for the site will dictate the next step in the decommissioning process. TLG assumed the total removal of all plant systems and all of the above grade structures from the site. These non- i radiological costs are a part of this study.

3.5 ASSUMPTIONS The following are the major a=sumptions made in the development of the cost estimates for decommissioning LOPP.

1. Costs are calculated in 1997 dollars. A present-value economic analysis is not included, nor is escalation or general inflation reflected within the costs reported.

2. Both units are assumed to be essentially identical except for common structures and systems. Common systems and structures are assigned to, and incorporated within, the estimate for Unit 2 as being required to support decommissioning operations.

3. Plant drawings, equipment and structural specifications, including construction details, were provided by PG&E.

4. Employee salary and craft labor rates for site administration, j operations, construction, and maintenance personnel were provided by PG&E for positions identified by TLG.

5. PG&E provides for any necessary electrical power to be brought on site required to decommission the plant. Energy costs are included in the estimate.

! 6. Material and heavy equipment rental and operating costs were taken l from R.S. Means Building Construction Cost Data.

7. Radioactive contamination is considered to be within acceptable limits  !

for free-release in the secondary steam cycle components.

8. Radioactively contaminatedopiping, components, and structures other I i l

L

o Document P01-1252-002, Rev. O Dist.lg Canyon P:wer PI:nt Section 3, Page 14 cf 22

.than the reactor vessel and internals are assumed to meet DOT limits for LSA or Surface Contaminated Object (SCO) material. For transportation calculations, the distance from the plant. site to the Needles (the Ward Valley burial site) is 399 miles for trucking, and 518 miles for rail shipping. Rates for shipping radioactive wastes were provided by Tri-State Motor Transit in published tariffs for this cargo (Ref.12).

9. The reactor vessel and internals' disposal costs were based on remote in-place segmentation, packaging in shielded casks, ann inipping by truck to the burial ground. A maximum normal road weignt limit of 80,000 pounds is assumed for all truck shipments with the exception of several overweight' cask shipments. Cask shipments may exceed 95,000 pounds, including vessel segment (s), supplementary shielding, cask tie downs and tractor trailer. The maximum curies per shipment assumed permissible is based upon the license limits of available shielded shipping casks. The number and curie content of vessel segments were selected to meet these limits.

10. The number of cask shipments out of the Reactor Building is expected to average three every two weeks. In the DECON alternative, the reactor vessel and reactor coolant system will be chemically decontaminated using one chemical flush and two water rinses prior to segmentation.

Typically, a decontamination factor (DF) of 10 is expected from this operation.

11. Reactor vessel and internals packages' conditions:

Any fuel cladding failure that has occurred or may occur during the lifetime of the plantis assumed:

= to have released fission products at sufficiently low levels that the buildup of quantities of longlived isotopes (e.g. cesium 137, strontium 90, or transuranics) has been prevented from reaching levels exceeding those which permit the major primary coolant system components to be shipped as LSA or SCO waste and to be buried within the requirements of 10 CFR 61 or the regional burial ground; or e to have necessiteted systematic decontamination during the operating life of the plant; therefore, the radionuclide levels will be acceptable for transport as LSA or SCO waste and burial within the requirements of10 CFR 61.

12. The estimated curie content of the vessel and internals at final shutdown was derived from those listed in NUREG/CR-2474 (Ref.13).

Actual estimates will be derived from the Ci/ gram values in

i- -Dishl2 Canyon P:wer Plant ' Document P01-1252-002, Rev. 0 l- -

Secth:n 3, Page is of 22 .

l i

NUREG/CR 3474 and adjusted for the different mass of components and projected ' operating life, as- well as for different periods of decay.

Additional short-lived isotopes were derived from NUREG/CR-0130 (Ref.

14) and NUREG/CR-0672 (Ref.15), and benchmarked to the long-lived values from NUREG/CR-3474.

13. ' This study estimates that there will be some radioactive waste generat-ed which is greater than 10 CFR 61 Class C quantities (GTCC), result-ing from _ disposal of the highly activated sections of the reactor vessel internals. This waste will most likely be disposed of as high level waste

- in the DOE's deep geological repository unless an alternative solution is approved by the NRC. The cost of disposal, unlike that for the spent fuel, is not addressed by DOE's 1 - mill / kwhr surcharge, and has been estimated from equivalent disposal costs for spent nuclear fuel.

14. Control elements will be removed and disposed of along with the spent fuel assemblies.

15. Greater than Class "C" waste generated through segmentation of the reactor vesselinternals will be transferred to the on site ISFSI or to the-DOE high level repository within the approximate 96: month decay period following plant shutdown. If the DOE were to default on its obligations to accept spent fuel and GTCC material, decommissioning costs would almost certamly increase.

16. This study does not address the cost for the removal and disposal of spent fuel from the site. Ultimate disposition of the spent fuel is the province of DOE's Waste Management System, as defined by the Nuclear Waste Policy Act and funded through the 1 mill / kwhr electrical ,

generation surcharge. If DOE were to delay its obligations to accept l spent fuellater than a time consistent with DOE initial pickup of spent fuel from DCPP in 2017, then decommissioning costs would increase.

17. The final reactor core discharge will be transferred to the spent 6tel pool, located in the Fuel Handling Building, where it will remain for at least eight years. Additional storage of fuel on site will be necessary prior to its transfer to the DOE for final disposal.

! 18. Scrap generated during decommissioning is not included as a salvage credit line item in this study for two reasons: (1) the scrap value merely offsets the associated site removal and scrap processing costs, and (2) a l

relatively low value of scrap exists in the market. Scrap processing and site removal costs are not included in the estimate. ,

l 19. PG&E will make economically reasonable efforts to salvage equipment during decommissioning. Nonetheless, because placing a salvage value ,

on this machinery and equipment would be speculative, and the value l

I l

'a..

Disbis Cenyon Pzwer Plznt Document P01-1252-002, Rev. 0 Secticn 3, P:ge 16 cf 22 would be small in comparison to overall decommissioning expenses, this estimate does not attempt to quantify the value that PG&E may realize based upon those efforts. For purposes of this study, decommissicning is assumed to begin in 2015; it may occur earlier or later, depending on a variety of economic and regulatory factors. Additionally, because of PG&E's life cycle management of equipment, a program designed to optimize equipment performance through preventive maintenance, it is difficult to predict the remaining life of the equipment that will be on site when decommissioning begins. Finally, it is difficult to predict whether the market for used equipment will be stronger or weaker than it is today. For these reasons, it is not possible to provide an estimate of the salvage value of the equipment at the plant. Moreover, any salvage value would be small when compared to total decommissioning expenses.

20. The PG&E staffing requirements during decommissioning vary with the level of effort associated with the various phases of the project. Once the decommissioning program commences, only those staff positions necessary to support the decommissioning program are included.

However, there are costs included in this study for staff transition from plant operations to decommissioning.

21. This study assumes that PG&E will hire a DOC for the decommissioning project. This DOC staff will provide for the preparatory demolition planning and scheduling, and will manage the demolition efforts. Site security, radiological controls, quality assurance, and overall site administration will be provided by PG&E during decommissioning.

22. Engineering services for such items as wnting activity specifications, detailed procedures, detailed activation analyses, and structural modifications, etc. are assumed to be provided by outside contractors.

23. PG&E will remove items of personal property owned by PG&E that can be removed without the use of special equipment.

24. PG&E has sufficient scaffolding to support the decommissioning project.

No costs associated with the purchase or rental of scaffolding are included in the estimate.

25. Existing warehouses will remain for use by PG&E and its subcontractors. Those warehouses scheduled for removal will be dismantled as they are no longer needed to support the decommissioning program; others may remain for alternate use.

26. PG&E will perform the following activities as a stati function, shortly after cessation of operations at Unit 2:

Aw

DE: bin C:nyon Pzwer Plant D:cument P01-1252-002, Rev. 0 Secti:n 3, Page 17 ef 22 i

. Fuel oil tanks will be emptied. Tanks will be cleaned by flushing or i steam cleaning as required prior to disposal. l

• Acid and caustic tanks will be emptied through normal usage; any  ;

excess acid or caustic removed to support disposal of the storage '

container (s) is returned to the vendor.

• Lubricating and transformer oils will be drained and removed from site by a waste disposal vendor.

27. The decommissioning activities will be performed in accordance with the current regulations, which are assumed to still be in place at the time of  :

decommissioning. Changes in current regulations may have a cost i impact on decommissioning.

28. This study follows the principles of ALARA through the use of work duration adjustment factors - which incorporate such items as radiological protection instruction, mock-up training, the use of respiratory protection, and personnel protective clothing. These items  ;

lengthen a task's duration, which increase the costs and lengthens the '

schedule. ALARA planning is considered in the costs for engineering and planning, and in the development of activity specifications and detailed procedures. Changes to S20 worker exposure limits may impact the decommNioning cost and project schedule.

29. This study was performed in accordance with the published study from the Guidelines document. The contents of the guidelines were prepared '

under the review of a task force consisting of representatives from utilities, state regulatory commissions, architect / engineering firms, the  !

Federal Energy Regulatory Commission, the NRC, and the National Association of Regulatory Utility Commissioners.

30. Nuclear liability insurance provides coverage for damage or injuries due to radiation exposure from equipment, material, etc. used during decom-missioning. Nuclear liability insurance is phased out upon final decontamination of the site. PG&E provided current nuchar liability and property insurance premiums which were factored to reflect lower coverage limits and retr /n of premiums during decommissioning activities.

31. Nuclear property insurance currently carried by PG&E for the site will continue throughout the decommissioning period at a rate discounted from that in effect during operations. For a multi unit site, the nuclear property insurance will cease for each unit upon termination of that unit's 50 license.

32. Only existing site structures and those presently planned will be

r

- Dirblicanyon P:wer Plant - Document P01-1252 002, Rev. 0 Sectisn 3, Page 18 of 22

- considered in the decommissioning cost.

33. The perimeter fence and in. plant security barriers will be moved as '

appropriate to conform with the Site Security Plan in force at the various stages in the project.

34. The existing electrical switchyard will remain after decommissioning in support of the utility's electrical transmission and distribution system.

- 35. Underground metal and concrete piping will either be surveyed in place and released, or excavated and removed for survey. Any piping that exceeds the site release criteria will be removed.

36. A flat annual property tax payment for DCPP was provided by PG&E.

This payment continues throughout the decommissioning schedule and terminates upon final site restoration.

8.6 - COST ESTIMATE

SUMMARY

A summary of the radiological decommissioning costs and annual expenditures is provided in Tables 3.1 through 3.4. Tables 7.1 through 7.4 provide breakdowns of the costs into the components of decontamination, removal, packaging, transportation, waste disposal, project management (staffing), and other cost categories for the DECON and SAFSTOR options. The costs were 4

extracted from the detailed cost tables in Appendix C. The following should be considered when reviewing these tables:

. "Decon" as used in the headings of these tables, refers to decontamination activities, as opposed to the NRC term DECON, which refers to the prompt removal decommissbing scenario.

. " Total" as used in the headings of these tables, is the sum of Decon, Remove, Pack, Ship, Bury, and Contingency, as well as other miscellaneous items not listed (such as engineering and preparations).

. The subtotal reported for the major cost categories does not include contingency, which is reported in a separate column.

. "Other" includes different types of costs which are not easily categorized.

For instance, in systems removal and structures decontamination, the "Other" cost consists of the off site recycling costs for low-level radioactive waste. In most of the engineering preparatory activities the "Other" cost is strictly engineering labor, however, "Other" also includes taxes, insurance, plant energy budgets, and regulatory fees.

~ DichliC:nyon Power Plant Document P01-1252-002, Rev. 0 Sectirn 3, Page 19 of 22 l

l TABLE 3.la l DIABLO CANYON POWER PLANT - UNIT 1

SUMMARY

OF DECON DECOMMISSIONING COSTS (1997 Dollars)

Equipment & Contractor Year PG&E Labor Materials Labor Burial Other Yearly Totals 2015 4,489,313 13,751,077 24,893,594 3,446,414 2,462,218 49,042,616 2016 9,671,461 17,875,228 37,351,193 6,003,850 3,776,508 74,678,239 2017 10,773,449 4,526,837 12,829,663 10,252,403 4,256,129 42,638,481 2018 10,657,771 4,526,837 12,655,216 10,252,403 4,256,129 42,348,356 2019 10,520,620 4,526,837 12,448,38S 10,252,403 4,256,129 42,004,375 2020 4,870,306 4,539,240 7,461,704 10,280,492 4,223,378 31,375,120 2021 '1,954,979 4,526,837 4,875,711 10,252,403 4,189,145 25,799,075 2022 1,954,979 4,526,837 4,875,711 10,252,403. 4,189,145 25,799,075 2023 6,296,468 4,526,837 11,263,329 10,252,403 4,429,139 36,768,177 2024 4,239,375 4,955,212 9,214,723 4,606,559 2,453,982 25,469,850 2025 613,381 5,278,470 5,153,288 833,806 11,878,944 2026 743,800 5,278,470 5,572,817 833,806 12,428,894 2027 329,829 1,171,387 1,370,680 480,358 3,352,253 2028 212,340 172,654 380,590 765,585 2029 211,760 172,183 379,550 763,493 2030 211,760 172,183 379,550 763,493 2031 211,760 172,183 379,550 763,493 2032 212,340 172,654 380,590 765,585 2033 211,760 172,183 379,550 763,493 2034 560,945 2,646,466 1,700,455 2,928,563 565,598 8,402,027 68,948,394 82,656,573 152,700,508 88,780,295 43,484,854 436,570,623 l

l

Dirbis Canyon Pzwer s'lznt Document P01-1252-002, R1v. 0 Sectlon 3, Page 20 ef 22 TABLE 3.lb DIABLO CANYON POWER PLANT -UNIT 2

SUMMARY

OF DECON DECOMMISSIONING COSTS (1997 Dollars)

Equipment & Contractor Year PG&E Labor Materials Labor Burial Other Yearly Totals 2016 5,607,062 6,159,639 11,566,089 1,474,665 2,120,902 26,928,356 2017 5,106,111 7,347,282 14,362,318 1,758,996 2,529,833 31,104,540 2018 1,954,976 7,347,282 10,456,687 1,758,996 2,529,833 24,047,774 2019 1,954,976 7,347,282 10,456,687 1,758,996 2,529,833 24,047,774 2020 7,807,101 7,128,231 13,510,186 11,522,688 4,821,630 44,789,837 2021 10,760,981 6,986,535 15,000,160 16,477,958 5,976,016 55,201,648 2022 10,520,620 6,986,535 14,637,685 16,477,958 5,976,016 54,598,813 2023 6,179,129 6,986,535 10,844,630 16,477,958 5,976,016 46,464,267 2024 7,709,874 7,005,676 15,470,238 16,523,103 6,228,748 52,937,638 2025 4,991,098 68,779,555 18,849,674 2,889,286 1,846,968 97,356,581 2026 3,815,385 81,918,270 18,704,119 969,031 105,406,806 2027 1,638,257 18,179,123 4,348,248 510,367 24,675,995 2028 1,020,103 254,487 380,590 1,655,180 2029 1,017,316 253,792 379,550 1,650,658 2030 1,017,316 253,792 379,550 1,650,658 2031 1,017,316 253,792 379,550 1,650,658 2032 1,020,103 254,487 380,590 1,655,180 2033 1,017,316 253,792 379,550 1,650,658 2034 960,413 3,365,175 6,768,289 2,928,563 633,396 14,655,835

$75,115,450 $235,537,119 5166,499,152 $90,049,165 $44,927,972 $612,128,858

N. ,

l Dicbio Ccnyon P:werPl:nt D:cument P01 1252 002, Rey, o

\

. Secti2n 3, Page 21 ef 22 j TABLE 3.2a DIABLO CANYON POWER PLANT - UNIT 1

SUMMARY

OF SAFSTOR DECOMMISSIONING COSTS (1997 Dollars) l Equipment & Contractor Year PG&E Labor Materials Labor Burial Other Yearly Totals 4,420,377 3,174,033 19,879,179 1,474,177 1,215,764 30,163,529 2015 6,019,874 3,956,498 24,715,682 1,834,932 1,595,2853 38,122,272 2016

'3,198,752 172,724 709,679 64,791 529,291 4.675,236 j 2017 3,198,752 172,724 709,679 64,791 529,291 4,675.236 2018 3,198,752 172,724 709,679 64,791 529,291 4,675,236 ,

2019 3,207,516 173,197 711,623 64,968 530,741 4,688,045 I 2020 3,198,752 172,724 709,679 64,791 529,291 4,675,236 l 2021 l 3,198,752 172,724 709,679 64,791 529,291 4,675,236 2022 3,198,752 172,724 709,679 64,791 529,291 4,675,236 2023 3,207,516 173,197 711,623 64,968 530,741 4,688.045 2024 1 3,198,752 172,724 709,679 64,791 529,291 4,675,236 2025 3,198,752- 172,724 709,679 64,791 529,291 4,675,236 j 2026 3,198,752 172,724 709,679 64,791 529,291 4,675,236 2027 3,207,516 173,197 711,623 64,968 530,741 4,638,045 2028 '

3,196,752 172,724 709,679 64,791 529,291 4,675,236 2029 3,198,752 172,724 709,679 64,791 529,291 4.675,236 2030 3,198,752 172,724 709,679 64,791 529,291 4,675,236 2031 3,207,516 173,197 711,623 64,968 530,741 4,688,045 .

2032 3,198,752 172,724 709,679 64,791 529,291 4,675,236 1 2033 2034 2,134,956 172,724 461,437 64,791 t68,092 i' C 000 1,088,505 172,724 217,242 64,791 407,892 1,951,154 2035 1,091,487 173,197 217,837 64,966 409,010 1,956,499 2036 1,088,505 172,724 217,242 64,7A1 407,892 1,951,154 1 2037 1.088,505 172,724 217,242 64,791 407,692 1,951,154

, 2038 1,088,505 172,724 217,242 64,791 407,8?2 1,951,154 2039 1,091,487 173,197 217,837 64,968 409,010 1,956,499 2040 1,068,505 172,724 217,242 64,791 407,892 1,951,154 2041 1,088,505 172,724 217,242 64,791 407,892 1,951,154 2042 1,088,505 172,724 217,242 64,791 407,892 1,951,154 2043 1,091,487 173,197 217,837 64,968 409,010 1,956,499 2044 1,088,505 172,724 217,242 64,791 407,892 1,951,154 2045 2,372,753 689,613 1,978,100 301,594 773,305 6,115,365 2046 8,772,938 3,265,588 15,144,339 1,481,726 2,594,379 31,258,971 2047 9,028,147 7,962,523 17,113,705 17,818,377 6,656,424 68,579,177 2048 7,479,130 10,249,733 16,843,409 25,813,955 8,645,742 69,031,970 2049 3,473,337 10,249,733 16,739,271 25,813,955 8.646,403 64,925,700 2050 5,645,518 5,799,501 4,950,621 1,764,071 18,826,407 2051 666.695 510,930 4,565,467 4,064.513 236,014 9,376,924 2052 10,889,369 941,865 4,552,993 5,151,665 242,846 2053 485,125 2,345,103 2.653.460 125,082 5.608.771 2054 61,669,107 145,008,031 81,369,512 46,457,315 447,209,431 112,705,467 n i

m Diablo C:nyon Power Plant Dzcurnent P01-1252-002, R:v. 0 Section 3, Page 22 of 22 d

' 33552 TABLE 3.2b DIABLO CANYON POWER PLANT- UNIT 2

SUMMARY

OF SAFSTOR DECOMMISSIONING COSTS (1997 Dollars)

I Equipment & Contractor Year PG&E Labor Materials Labor Burial Other Yearly Totals 2016 8,457,521 5,079,262 23.221.324 1,903,826 1,874,231 40,536,165 2017 7,763,921 4,072,880 18,593,377 1,526,627 1,677,407 33,634,212

.2018 3,19'.,751 172,722 709,679 64,790 581,053 4,726,995 2019 3,198,751 172,722 709,679 64,790 581,053 4,726,995 2020 3.207,515 173,195 711,623- 64,968 582,645 4,739,946 2021 3,198,751 172,722 709,679 64,790 581,053 4,726,995 2022 3,198,751 172,722 709,679 64,790 581,053 4,726,995 2023 3,198,751 172,722 709,679 64,790 581,053 4.726,995 2024 3,207,515 173,195 711,623 64,968 582,645 4.739.,946 2025 3,198,751 172,722 709,679 64,790 581,053 4,726,995 2026 3,198,751 172,722 709,679 64,790 581,053 4,726,'.,s0 2027 3,198,751 177.,722 709,679 64,790 581,753 4,726,995 2028 3,207,517 173,195 711,623 64,968 582,F5 4,739,946

• 029 3,198,751 172,722 709,679 64,79') 581/# 4 '26,995 030 3,198,751 172,722 709,679 64,790 581,t? 4J26,000 2031 ,198,751 172,722 709,679 64,790 581,05U 'MO 2032 3,207,515 173,195 711,623 64,968 582,645l $ 4 ti4C 2033 3,198,751 172,722 709,679 64,790 581,053 4, m , A 2034 2,134,955 172,722 461,4 7 64,700 519,855 3,353,759 2035 1,088,504 172,722 217,242 64,790 459,654 2,002,913 2036 1,091,486 173,195 217,837 64,968 460,914 2,008,400 2037 1,088,504 172,722 217,242 64,790 459,6f4 2,002,913 2038 1,088,504 '172,722 217.242 64,790 459,654 2,002,913 2039 1,088,504 172,722 217,242 64,790 459,654 2,002,913 2040 1,091,486 173,195 217,837 64,968 460,914 2,008,400 2041 1,088,504 172,722 217,242 64,790 459,654 2,002,913 2042 1,088,504 172,722 217,242 64,790 459,654 2,002,913 2043 1,088,504 172.722 217,242 64,790 459,654 2,002,913 2044 1,091,486 173,195 217,837 64,968 460,914 2,008,400 2045 1,088,504 172,722 217,242 64,790 459,654 2,002,913 2046 1,088,504 172,722 217.242 64,790 459,654 2,002,913 2047 -1,088,504 172,722 217,242 64,790 459,654 2,002,913 2048 2,756.936 2,636,323 6,040,274 1,219,057 2,412,108 15,064,699 2049 4,869,149 5,449,571 12,132,493 9,158,615 4,647,966 36,257,793 2050 9,117,338 10,867,624 17,276,041 27,875,869 8,969,760 74,106,632 2051 9,042,508 10,867,624 19,231,125 27,875,869 9,069,752 76,086,878 2052 5,645,638 49,526,041 21,062,685 12,830,537 4,251,115 93,316,016 2053 2,770,902 82,076,990 20,920,365 287,034 106,055,291 2054 1,427,204 42,275.272 10,775,421 147,842 54.625,739 119,360,647 218,036,561 163,903,119 84,335,347 49,139,566 634,775,240 9

Dirbb Cznyon Pzwer Plznt Document P01-1252-002, Rev. 0

( Section 4, Page 1 cf10

4. SCHEDULE ESTIMATE The schedule for the decommissioning scenarios considered in this study follows 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 plan outlined for the DCPP inventory.

Figure 4.1 presents a schedule for the prompt decommissioning alternative; the assumptions supporting this schedule are listed in Section 4.1. The key activities listed in the schedule do not reflect a one to-one correspondence with those activities in the Appendix C cost tables, but reflect dividing some activities for clarity and combining others for convenience. The schedule was prepared using the "Microsoft l Project for Windows" computer eoftware (Ref.16).

4.1 SCHEDULE ESTIMATE ASSUMPTIONS The schedule estimate 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 durations used in the precedence network refleet the actual man hour estimates from the cost tables in Appendix C, 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.

. All work (except vessel and internals removal activities) is performed during an 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> workday, 5 days per week, with no overtime. There are 11 paid holidays per year.

. The fuel handling facilities located in the Fuel Handling Buildings will be isolated and serve as interim wet fuel storage facilities until such time that all spent fuel has been discharged from the spent fuel pools, i.e., within approximately 96 months from shutdown of each unit (DECON cption only). The pools are assumed to accommodate the final core discharge from each unit, allowing decontamination and dismantling to commence on each unit's power block structures without constraint. Decontamination and dismantling of the Fuel Handling Buildings are initiated once the transfer of spent fuel to the on site ISFSI or to the DOE high level waste repository is complete.

> . Reactor vessel and internals removal activitSs are performed by using separate crews for different activities working on different shifts, with a corresponding backshift charge for the second shift.

D:cument P01-1252-002, Rev. 0 Disbis Csnyon Power Pl nt Sectlen 4, Page 2 of10

. Multiple crews work parallel activities to the maxunum 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.

. 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.

Unit 1 DECON Period 2 decommissioning activities will begin 18 months after cessation of plant operations. Unit 2 will not begin DECON Period 2 activities until the completion of Period 2 activities at Unit 1 (with the exception of the fuel pool and supliart systems, which are required to remain operational for eight years following shutdown.) At the conclusion of Unit 2 DECON Period 2 activities, the fuel pools at each unit will be decontaminated and decommissioned. Sequencing the integrated decommissioning of the DCPP is assumed such that an even level of stafi resources will remain on site to accomplish the decommissioni ig of the nuclear site.

4.2 PROJECT SCHEDULE The period dependent costs presented in the cost tables in Appendix C are based upon the durations developed in the schedule for each decommissioning alternative. Durations are established between several milestones in each j

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 total costs for these period-dependent items.

Project timelines for the two decommissioning alternatives are included in this section as Figure 4.2a and 4.2b. . Milestone dates are based on a 30-year plant operating life from the start of commercial operations, a minimum of 96 months wet storage for the last core discharge of fuel, and a deferral of thirty years for license termination (SAFSTOR) and final site release.

s t

Dizbio C:nyon P:werPlznt Document P011252 002, Rev. 0

. Section 4, Page 3 of 10 FIGURE 4.1 DECON ACTIVITY SCHEDULE ID Task Name '16 l '1'i l '17 l '18 l *19 l '20 l '21 l *22 l '23 l '24 l *26 l *26 l *27 l '28 1 Shutdown Unit 1 g 2 Unit 50ipersiional

~

y 3 EpeciaIEquipment" Unit 1 g- '

4 Procure Ca's ksdiners' Unit i s ,

6 Piepare'Planiunit' i ~ g PYepare Distnantiing' seq' Unit 1" 6

g ,

7 ^cissy spees UWir g i  ;

8 NAtailed50cedureiUnk'i' g 8 NNd Product'Dedhan Uttt 1 g 16 Review i'lant bi, wings Unit 1~

g 11 5ngineering Preps'Unlis" y 12 Design Waier Cleanup Sys ntt i g

Define 5rk Se'quence UnE"1" 13 g

14 Nst'abiish By 505uct inventory Unh 1 g

16 Period 1 Licensing' Unit i p]

16 betajieh Radiation Survey Unit 1 y 17 DetaUed Bi-Product inventory' Unit 1 Q

18 P$riod15ste Unit t' gx 19 knd hehibiUniik" g 20 Period 55ste'U5tT gq; 21 Pe'riod 2 La.tr ung nit 1 ' pg 22 becor5 USA ',iti g

~

23 RPU Removal Prep Unit 1 0

24 Remove RPU'U51[ ] l Task l@MMSxWW{ Milestone $

CntcalTask l t

L.

Diablo C:nyon P:werPlant Document P01-1252-002, Rev. 0 Section 4, Page d ef10 i

FIGURE 4.1 DECON ACTIVITY SCHEDULE (Continued)

ID Task Name '16 l '16 l *17 l *18 l *19 l '20 l *21 l '22 l '23 l '24 l '26 l *26 l *27 l '2s 26 NSSS Pipe Removal Und 1 g i  !

l 26 Steam Generator Removal Unit 1. . . - . . . . .

!0 '

lI

~

i 27 RCP 5~MoioiRemovat'Uriit 1 i i l I i i

28 Remove PressurizeiU$it I" ji 29 Remove droup d Syst' ems'Und 1 gy 30 RemoveUroup"B Nys'tems' Unit 1 ;g

! I i

31 Remove Turbine-Genersi5IU5t'i' g

32 Remove Condenser Unit i. . . . . , . . . . . ,

33 Remove Non-$ss Struct'ures' Unit 1' g 34 Remove"TB165ystems il

~

35 R'emove CP Mrea 1'd Systems g 36 Removid dieiId 5ystims l

31 Decon CEIrea'5" g 38 Remove"RSTd' Systems

]

39 R'emove'RBi'D 5ysems l

40 Decor $ RBI

~

41 Remove XuxiC Systems

{

42 RemoveIU5iU5yst' ems l

43 End First Half briod 2 Unit 1 ' i g 44 Start Period i Unit 2 '

46 S'peciai Eq'uipmeniUr$lt 2 46 Procure CasEsUners Unit 2  ;

47 Prepare plant'O' nit'2 '  !

3 48 Prepare Ddmantiing Eeq Unit 2 '

I Task hN%iN%%s4 Milestone $

CrdicalTask l l I

i 1

f.

Diablo C:nyon P:werPlant

• Document P01-1252-00.?, Rev. 0 Secti:n 4, Page 5 of10 FIGURE 4.1 DECON ACTIVITY SCHEDULE (Contic" 10 Task Name '15 l *18 l '17 ) "20 l '21 l '22 l 13 l 14 l '25 l '26 l '27 l '28 49 Activtty Specs UnR 2 lg i j .

j

. . . . . . . . . . . . . _ . i

! l 50 Detailed Procedures Unn 2. . . . . . . . . . . . . . . . . . .lg' .  ;

s1 End Product'EsErhUoriU5tF g i  ;

5  !

52 Review Plant Drawings UnN 2 w  !

53 Engineenng Preps UnR 2 gj j 54 Design WethCleanup Sys UnR'2 ' jg 55neErk Sequence Und 56 ,g -

{

56 Establ$h"By2 Prod 5t' inventory'05t'2' ;q l 57 Period EUcensing' Unit '2 y 68 Detaiied Ra5Iation Survey' Unit 2~~

]

59 Deta'i led By-Prod'uctInventory bnt 2' 9  !

60 Penoi1hstiUnn'2~ Lg-l 61 End Period 1 Unit 2. . . . . . . . . . . . . . . . . .

4 82 Unit 2 Wet Layup pggqqq  !

53 Penod 2 Uste" Unit 2 ^

Q }

64 Licensing Period 2 Unit 2. . . . . . . . . . . . . . . . . . . . . . . .

NWg; j 55 Decon NSSS' Unit 2 l

86 RPV P' rep'Ohit'i' 0

67 kmv RPV Unit 2 l l

~68 'Arnv Steam Gens Unit 2 g (O Rmy RC Pumps Unit 2 l

70 Rmv Pressurizer Unit 2 71 Remove Group A Systems Unit 2 g  ;

72 Remove Group 'B 'Sys'tems Ure 2 "  !

Task %N@8x%N Milestone $

CrticalTask l l

Dl1blo C:nyon P:wer Pirnt Document POJ-1252-002, Rev. 1 Sectlan 4, Page 6 ej 10 FIGURE 4.1.

DECON ACTIVITY SCHEDULE (Continued)

ID Task Name '16 l *16 l *17 l '1B l '19 l '20 l '21 l *22 l *23 l '24 l *26 l '26 l *27 l '28 73 Remove Turtune-Generator Unit 2 g :

i

. t 74 Remove Uc~n' d enser Unit 2~ g 76 Remove Nondss5tbAdures UnU" j i  ;  ! i  ; j

~ ~~"

76 RemoveiB265y5tems gl l

77 Remove CEAreaiU5ystems l l

78 Remove CP Area 2 D Systems  ;  ; l ..

l; i

. . . . . . . . . i l l'

79 Decon CP Area 2 i

g . ,

50 Re'rnove'RBid Shs'tems

^

81 Remove R5 2 D Systems

~

l 82 Decon R$2 83 Remove A'ux2 C Systems 0

84 Remove AuiE6 Systems 86 Decon Aux 2. . - . . . . . . . .

[

36 Remove FB 1'C' Systems ,

0i 37 Remove FB 1 D5yste'ms l

88 Decon FB 1 59 Fmal Survey Unit i ;l 90 Remove FBid Shtems

~

l 91 Remove' FB ED Systems i jj 92 Decon FB 2 93 Final Survey Ordt 2 0

94 knd Pebod 2 Unit 2 '

End Perhod 2 Urft 2 95 96 Ts Eint'erior"De'molition g Task IM8MMMM Milestone $

CrttcalTask l 7

1

)

Dicblo Canyon P:werPl:nt D:cument P01-1252-002, Rev. 0 '

l Section 4, Page 7 of10 l

i l

FIGURE 4.1 DECON ACTIVITY SCHEDULE (Continued) i ID ' Task Name *16 l *16 l *17 l *18 l '19 l '20 l '21 l *22 l '23 l *24 l '26 l '26 l '27 l '28 97 TB 1 Extortor Demohten  ! i g

98 TB 1"BackU" g

~~

9. TB 2 niesDimsian  ;

i i jg j 100 Tlii2 rterioideNidilh5n g 101 TB 2 Backfili"  !

i g 102 FB 1 Interlor Demoliten ,

j i  ;

ig i g

103 FB 1 Exterior Demoliten 104 FB 1 Backfdl 106 FB 2 InterioiDemoNUon lg 106 FB 2 Exterior DemoNUon

]

107 FN 2 Backfill 108 ASIntenor Demo 5on ~ I y

109 AN dxterioiDemobtidn

]

110 AB Backfill g 111 CP Area'1'intirioidembilbAn

^

]

112 CP Area 1 ExterioiDemoUtion l

113 CP Area 1 Backtill  !

l 114 UP itali5tirioidemoinen ;g 116 CP drea i Exterior D'emoNtson i l

116 CP Area 2 BackfilI l

117 Ri1 ' Interior DemoUtion 3 118 RN 1 Exterior demoht' ion ,

] '

119 RD 1 BackTNI 120 R5 2 Interior Demoittion g Task h%9M5NSW4 Milestone $ )

CnticalTask l l ,

DI:bl2 Canyon P:wer Plant D:cument P01-1252-002, R:v. O Sectisn 4, Page 8ef10 FIGURE 4.1 DECON ACTIVITY SCHEDULE (Continued) 10 Task Name

'15 l '16 l *17 l *18 l '19 l *20 l '21 l '22 l '23 j '24 l '26 l '26 l "J7 l "28 i  ! i ..

121 RB 2 Exterior DemoIP. ion j  ;

I 122 RB 2 Backrdt. . . . . . . . . . . . . . . . ,

' 123 Edi*iinEsdaUon Bu5ing'DemoliiM )  ; q i

124 EaUs~caping 126 End j  ; ,

g Task Bx\%56%Ns#4 x Milestone $

I CritcalTask l I

r Dl;;blo Canyon P:wer Plant Docurnent P01-1252-002, Rev. O Section 4, Page 9 of10 FIGURE 4.2a DECON DECOMMISSIONING TIMELINES I

DCPP UNIT 1 p . , . . . . . . . . . . . . . . . . . . . . Wet Fuel Storage. . . . . . . . 4. . . . . . . . . . . . . . . . . Dry Fuel Storage . . . . . . . . . .q Stanup Shutdown Period 2 Post Period 3 i Period 1 Dmin Period 3 Preparations Deco ==inaioning Delay Restoration ISFSIOperation Operation 30 31 38 39 40 42 49 49 85 2015 2016 2023 2024 2025 2027 2034 2034 8Y May Nov Jun Jun Mar Mar Jul Dec DCPP UNIT 2 y . . . . . . . . . . . . . . . . . . . . . . Wet Fuel Storage. . . . . . 4r -

• -

• Dry Fuel Stora gs . . . . . . . . >\

up S W own Period 2 Period 3 Post Period 3 Period 1 Decommissioning Restoration ISFSI Operation Operation Preparations 30 34 38 39 41 48 48

' 2024 2025 2027 2034 2034 2016 3020 y,,

Mar May May Mar Mar Jul Dec NOT TO SCALE

D:cumsnt P01-1252-002, Rev. 0 DE:blo Canyon P:wer Plant Section 4, Page 10 cf 10 233552 FIGURE 4.2b SAFSTOR DECOMMISSIONING TIMELINES DCPP UNIT 1 p . . . . . Wet Fuel Storage . .e Startup Shutdown Period 3 Period 4 Dmin Period 6 Period 1 Preparations PeM 2 knnan Preparations D&D Delay Restoration Operation 49 61 63 66 67 69 30 31 2034 2046 2048 2051 2052 2054 1985 2015 2016 May Oct Jul Nov May Mar Jun Jul May DCPP UNIT 2 p . . . . . Wet Fue! Storage H Startup Shutdown Period 3 Period 4 Period 5 Period 1 Period 2 Donnancy Preparations D&D Restoration Operation Preparations 48 62 63 66 68 80 31 2034 2048 2049 2052 2054 1986 2016 2017 Aug Jul Mar Sep Jun Jul Mar Mar NOT TO SCALE l

1

Diebis Canyon Power Plant Document P01-1252-002, Rev. O \

. Section 5, P:ge i cf 3 1 I

i

5. RADIOACTIVE WASTES The goal of the decommissioning program is the removal of all radioactive material from the site which would restrict its future use and termination of the NRC license for the site. This currently requires the remediation of all radioactive material at the site in excess of applicable legallimits. Under the Atomic Energy Act (Ref.17), the NRC is responsible for protecting the public from sources ofionizing radiation. Title 10 of the Code of Federal Regulations delineates the production, utilization, and disposal of radioactive materials and processes. In particular, g61 controls the burial oflow-level radioactive material and g71 defines radioactive material.

The radioactive waste volumes generated during the various decommissioning )

activities at the site are shown by line activity in the cost tables in Appendix C. Waste l volume summaries, shown in Table 5.1, are quantified consistent with g61 classifica- I tions. The volumes are calculated based on the gross container dimensions or, for  !

components serving as their own waste container, the volume is calculated based upon the displaced volume of the component, i.e., steam generators and pressurizer.

l Most of the materials being transported for controlled burial are categorized as LSA or SCO material containing Type A quantities, as defined in 49 CFR gl73178 (Ref.

18). Shipping containers are required to be Industrial Packages (IP-1 or IP 2). For i

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, penetrations, etc.

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 in a deferred decommissioning alternative due to the presence of long-lived radionuclides. While the dose rates decrease with time, j radionuclides such as 37Cs will still control the disposition requirements.

2 l.

The' waste volume generated in the decontamination and dismantling of the nuclear L

Di:bb C:nyon P:werPlcnt D:cument P01-1252-002, Rev. O

~

Section 5, Page 2 cf 3 units is primarily. generated during Period 2 of DECON and Period 4 of SAFSTOR.

Contaminated and activated material will be characterized on site with a signi6 cant .

volume routed for additional processing. Components with low levels of removable surface contamination will be decontaminated on site, to the maximum extent possible. Components with low levels ofinternal contamination will be shipped to a waste recycling center for disassembly, decontamination, volume reduction, and/or repackaging. Heavily contaminated components and activated materials are gener-ally routed for controlled disposal after on site volume reduction.

For purposes of constructing the decommissioning cost estimate, a base burial rate of

$509 per cubic foot was used for low level radioactive waste disposal within the Southwest Compact. The value was derived from projections developed by the site developer, US Ecology, and through discussions with PG&E.

Non compactable.(metallic) radioactive waste generated from removal of the plant equipment is assumed to be sent to an off-site vendor for recycling as a means of reducing the ultimate disposal volume. Considering typical plant conditions and industry experience, the inventory of contaminated material at the DCPP was segregated based on the likelihood of volume reduction and decontamination for radiological free release. The burial volumes reported in Table 5.1 reflect the savings resulting from reprocessing and recycling. Off site processing of non compactable metallic waste was estimated to cost approximately $180.67 per cubic foot, based on industry experience, and appears as an "other" cost in the detailed decommissioning cost tables in Appendix C.

I I

l

Di blo Cznyon P:werPlznt Document P011252 002, Rev. 0

- Secti:n 5, Page 3 ef 3 ,

TABLE 5.1 DECOMMISSIONING RADIOACTIVE WASTE BURIAL VOLUMES Waste Volume '

Classi (Cubic feet)

DECON Unit 1 A 95,306 l B 16,002 C 612

>C 486 Subtotal 112,406 Unit 2 & Common A 98,936 B '14,416

-C 612

>C 486 Subtotal 114,450 TOTAL 226,856 SAFSTOR Unit 1 A 94,291 B 5,801 0 612

>C 486 Subtotal 101,190 i

Unit 2 & Common A 98,803 B 6,005 607 l

.C

>C 486 Subtotal 105,901 j l

TOTAL 207,091 l 1 Waste is classified according to the requirements delineated in Title 10 of the Code of Federal Regulations, Part 61.55 I

Disbb Cenyon Power PI:nt . > Document P01-1252-002, Rev. 0 ,

- Section 6, Page i cf 2 ,

6.: OCCUPATIONAL EXPOSURE

' Estimates ~of occupational radiation exposure were developed by TLG from the hours expended removing contaminated components and in the decontamination of site '

' structures. These estimates are' scoping in nature and are performed to provide an upper boundary to the exposure limits for comparison with NRC maximum dose limitations. Changes in the total occupational exposure estimates do not impact the cost model used by TLG.- The estimates are used to determine where exposure '

' reduction or control efforts are most effective.

Worker dose is calculated as the product of the direct personnel hours expended in radiation fields and the average area dose rate estimated for each decommissioning task. The calculation assumes that:  ;

e Only those personnel directly involved in the decontamination, removal, and packaging activities, as well as associated health physics personnel, are i considered in the exposure calculation. Casual exposures to the supervisory and plant staff are not included in the estimate.

. Personnel exposure to radiation is mimmized by utilizing shielding and remote

' handling techniques and avoiding higher radiation fields when personnel presence is not necessary.

I

. Locally high exposure rates near items such as tanks and pipes are reduced by chemical decontamination (DECON alternative only) prior to work in that area.

. Careful, prompt accounting of accumulated radiation exposure is maintained to ,

rapidly identify tasks causing excessive dose accumulation by workers so that corrective action can be taken.

. ' Exposures as the result of spent fuel storage activities are expected to be minimal, and therefore are not included.

. Cobalt-60 is the primary contributor to radiation exposure.

It should be noted that the radiation exposure rates used to calculate the exposures shown in Appendix C are based on optimum conditions; factors such as plant age, maintenance and operating history could cause the expected exposure rates to vary significantly at the time of decommissioning. Implementation of the DECON alternative yields potentially higher occupational radiation exposure because the work is performed soon after shutdown, without the benefit of any extended decay

Dl:bla C:nyon PowerPtznt Document P01-125 002, Rev. 0

. S:ction 6, Page 2 cf 2 time for the radionuclides on site, although this consequence can be mitigated by additional ALARA controls.

l i

\

l l

4 i

' Diablo Canyon PowerPIant Document P01-1252-002, Rev. 0 Sectlon 7,Page 1of 5

7. RESULTS 3 The projected costs to decommission the station, presuming the use of the DECON alternative, including the approximate 96. month operation of the Fuel Handling Buildings' fuel storage pools as interim wet fuel storage and approximately 17 years .

of ISFSI operation with ISFSI decontamination and demolition, is estimated to be

$1,048,699,456 in 1997 dollars. SAFSTOR costs are $1,081,984,672 in 1997 dollars.

The costs reflee the site-specific features of the Diablo Canyon Power Plant, the local cost of labor,.a schedule for spent fuel receipt,.and a projected cost' for low-level radioactive waste ' disposal at the regional compact site. Analyses of the major activities contributing to the total cost for each of the decommissioning alternatives are provided in Tables 7.1 and 7.2.

Staffing, including management, security, and health physics combine with the removal labor cost to represent the majority of the costs to decommission a nuclear station. This is a direct result of the laber-intensive nature of the decommissioning process, as well as the management contrcls required to ensure a safe and successful program. . Low level radioactive waste disposal (burial) represents the next largest cost component. These costs are indicative of the expense incurred in siting, developing,

.and licensing new disposal facilities. = Packaging and transportation costs are most sensitive to the waste volume generated in the decontamination and dismantling process, the volume reduction achieved, transport regulations for low-level radioactive waste, and the final destination (i.e., distance to the disposal site). "Other" costs include off site waste reprocessing expenses which can- also be considered as

" decontamination" expenditures, as well as true incidentals such as property taxes, engineering costs, insurance, and fees. 1 In most situations, the DECON alternative is the preferred mode of decommissioning.

This alternative is favored because it eliminates a potential long term safety hazard.

More importantly, the individuals familiar with the operation of the nuclear facility are available to support the dismantling effort, plant systems and services are fully functional, structural integrity is intact, and the licensee has a comprehensive management organization available to oversee / conduct the orderly decontamination and dismantling of the facility and site.

The construction of barriers and the general decontamination of plant areas in preparation for long term storage does not alleviate the need for continued

~

surveillance. The structural integrity of facilities must be maintained to support eventual decontamination and dismantling activities. ,

It is expected that a full time preventive and corrective maintenance staff will be needed to maintain essential site services and prevent the deterioration of the site

p' '

.Dicbia Ccnyon P:wer Plant Document P01-1252-002, Rev. 0 Section 7, Page 2 of 5 i

facilities. Peripheral structures will have to be maintained or remediated where

' asbestos and other hazardous and toxic material could enter the environment through degradation, weathering, or insufficient maintenance of site structures.

The NRC has become increasingly concerned over the maintenance, 'or lack of maintenance, at shutdown facilities. As such, the decommissioning estimates for placing a facility in dormancy have become increasingly more costly. The commitment to maintain fuel storage support facilities at the site during the first five years following the' cessation of plant operations is stipulated by DOE's transfer policy, irrespective of the intended decommissioning plans for the facility. This will require the continued operation of several plant systems and a cognizant operations staff.

Considerable progress in the decontaminatian and dismantling (of systems and facilities nonessential to spent fuel storage) can be made durirg the initial wet storage period in a program such as DECON. By comparison, at the conclusion of the transfer activity and the placement of the facility into safe storage (SAFSTOR), the physical plant is relatively unchanged, deferring the cleanup and dismantling of the facility to a later time.

The caretaking of a dormant facility has also become more costly. The NRC's review of current comparable facilities has resulted in a general increase in the level of maintenance required, as well as the on site presence of the owners / operators of the

. sites. Currently, licensees are required to complete the decommissioning process (culminating in the termination of the NRC site licenses) within a period of 60 years.

This translates into an available safe storage period of approximately 50 years during which the owner / operator would continue to maintain the property, replace roofing, and repair and upgrade surveillance and monitoring systems, lighting and communication equipment, rainwater collection, sampling and treatment equipment, etc. The dormancy selected for this analysis is 30 years. At the conclusion of this  !

phase, release of the facility from the jurisdiction of the NRC will still require remediation of the property. Tbc delay in decommissioning will not dramatically alter the cleanup requirements, in., the quantities of waste to be remediated will be

)

comparable to those addrewd in the DECON alternative. Although the radiation levels within the plant will have decreased substantially over the period of decay, the i presence of long lived radioisotopes will control the removal and disposal techniques used in the decontamination and dismantling of plant systems and facilities. As such, the cost savings in postponing decommissioning are relatively small and the risk that regulatory and waste disposal requirements will become more restrictive is relatively high.

Thus, for reasons provided above, the SAFSTOR cost estimate is shown t6 exceed that for a comparable DECON alternative (in the same year's dollars). The magnitude of the' differential is dependent on the length of the dormancy, caretaking, and other utility housekeeping costs, e.g., taxes, insurance and fees.

?. .. .. ..

Dlubls C:nyon Power Plant Docum:nt P01-1252-002, Rev. 0 Sectton 7, P:ge 3 cf 5 This study provides an estimate for decommissioning the site under current requirements based on present-day costs and available technology. Individual costs associated with decommissioning activities have increased at rates greater than generalinflation. For example, there has been significant volatility in the issues and policies surrounding waste disposal, i.e., access and cost oflow level radioactive waste disposal has been unpredictable and has escalated at rates historically greater than inflation (over the past ten years). The government's high level waste program has experienced a series of delays which have impeded the prompt deenmmissioning of the commercial reactors retired to date. Waste disposal has become the primary driver in the escalation of decommissioning costs. It is therefore appropriate that this cost estimate be reviewed periodically.

W I

DE:blo Cenyon P:wer Plant Document P01-1257-002, Rw. 0 Section 7, Pzge 4 cf 5 l

TABLE 7.1

SUMMARY

OF DECON DECOMMISSIONING COSTS Costs 97$ Percent of Work Category. (thousands)1 Total Costst l

l DECON 1

Unit 1 Decontamination 16,075 3.68 Removal 77,472 17.75 Packaging 7,409 1.70 l

Shipping 3,008 0.69 l

Burial (Off-Site) 88,902 20.36 Decommissioning Staffs 111,558 25.55 LLW Recycling 14,210 3.26 L

Other2 117,937 27.01 l Subtotal 436,571 100.00 Unit 2 & Conunon l

Decontamination 16,081 2.77 l

Removal 110,722 18.09 Packaging 7,280 1.19 l 2,952 0.48 Shipping 90,170 14.73 Burial (Off-Site)

LLW Recycling 13,360 2.18 Decommissioning StafTo 117,824 19.25 Breakwater Removal - 141,474 23.11 Other2 111,365 18.19 Subtotal 612,129 100.00 Station Total (with contingency) 1,048,699

1. Columns may not add due to rounding.

2. Other includes engineering & preparations, undistributed costs, NRC Fees, EP Fees and .

Maintenance Costs, etc.

r l

Dizbb C:nyon Power Picnt D:cument P011252-002, Rev. 0 Sectisn 7, Page 5 cf 5 -

233552 i

TABLE 7.2 l

SUMMARY

OF SAFSTOR DECOMMISSIONING COSTS Costs 975 Percent of Work Category (thousands)1 Total Costst SAFSTOR Unit 1 1 Decontamination 10,437 2.33 Removal 71,235 . 15.93 Packaging 6,456 1.44 Shipping 2,399 0.54 i Burial (Off Site) 81,370 18.20  ;

LLW Recycling 14,210 3.18 l Decommissioning Staffs 140,544 31.43 Other2 - 120,559 26.96

. Subtotal 447,209 100.00 Unit 2 & Common i Decontamination 14,369 2.26 Removal 105,505 16.62 Packaging 6,498 1.02 Shipping 2,368 0.37 Burial (Off-Site) 84,335 13.29 LLW Recycling 13,360 2.11 Decommissioning Staffs in,384 24.16 Breakwater Removal  : 2,474 22.29 Other2 113,482 17.88 Subtotal 634,775 100.00 Station Total (with contingency) 1,081,985

1. Columns may not add due te rounding.

2. Other includes engineering & preparations, undistributed costs, NitC Fees, EP Fees and Maintenance Costs, etc.

l

=

Digbis Canyon P:wer Plant Document P01-1252-002, R v. 0

. Section 8, Page 1 of 2

~8. REFERENCES

1. U.S. Code of Federal Regulations, Title 10, Parts 30, 40, 50, 51, 70 and 72,

" General Requirements for Decommissioning Nuclear Facilities," Nuclear Regulatory Commission, Federal Register Volume 53, Number 123 (p 24018+),

June 27,1988.

2. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.159, " Assuring the Availability of Funds for Decommissioning Nuclear Reactors," August,1990. j 1

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

" Decommissioning of Nuclear Power Reactors," Nuclear Regulatory ,

Commission, Federal Register Volume 61 (p39278+), July 29,1996. i l

4. " Nuclear Waste Policy Act of 1982 and Amendments," U.S. Department of Energy's Office of Civilian Radioactive Management,1982. I

5. DOE /RW-0457, Acceptance Priority Ranking and Annual Capacity Report, U.S. Department of Energy's Office of Civilian Radioactive Waste Management, March,1995.

1

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

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

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

Department of Energy, DOE /EV/10128-1, November,1980.

9. " Building Construction Cost Data 1997," Robert Snow Means Company, Inc.,

Kingston, Massachusetts.

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

11. "@ Risk Users Manual" Version 3.1, Palisade Corporation, Newfield, NY 1995.

12. Tri-State Motor Transit Company, published tariffs, Interstate Commerce Comn.ission (ICC), Docket No. MC 109397 and Supplements,1996.

Dicbio C:nyon PowerPl:nt Document P01-1252-002, R:v. 0

- Sectisn 8, Page 2 el2

8. REFERENCES (continued)

13. J.C. Evans et al., "Iong Lived Activation Products in Reactor Materials,"

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

14. 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 Commiasion, June,1978.

15. 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 Commis-sion, June,1980.

16. "Micrcsoft Project for Windows," Version 3.0, Microsoft Corporatisn, Redmond, WA,1093.

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

18. U.S. Department .of Transportation, Section 49 of the Code of Federal Regulations, " Transportation," Parts 173 through 178,1996.

l i' ' '

_a

F Diabis Canyon PowerPl:nt Document P01-1252-002, Rev. 0

. Appendix A, Page 1 of 4 i

APPENDIX A U'HT COST FACTOR DEVELOPMENT

DI: bis C:nyon Power Pl:nt Document P01-1252-002, Rev. 0 Appendix A, Page 2 af 4 APPENDIXA UNIT COST FACTOR DEVELOPMENT l

' 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 packing area.

2. CALCULATIONS Act Activity Activity Critical ID- Description Duration Duration 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 in plastic, send to packing area _SQ 60 Totals (Activity / Critical) 355 2F Duration adjustment (s):

+ Respiratory protection adjustment (50% of critical duration) 128

+ Radiation /ALARA adjustment (35.83333% of critical duration) .R1 Adjusted work btration 474

+ Protective clothing adjust me (dO'o of adjusted duration) _142 Productive work duration 616

+ Work break adjustment (8.33 % of productive duration) __ El Total work duration min 667 min

• • • Total duration = 11.117 hr ***

m Y DI::blo Canyon Power Pl:nt Docum:nt P01-1252-002, Rev. 0

- AppendEx A, Page 3 ef 4 1-APPENDIX A (continued)

3. LABOR REQUIRED Crew Number. Duration Rate Cost (hr) ($/hr)

Laborers 3.00 11.117 $28.65 $955.51 Craftsmen 2.00 11.117 $35.27 $784.1B Foreman 1.00 11.117 $37.18 $413.33 General Foreman 0.25 11.117 $39.04 $108.50 Fire Watch 0.05 11.117 $28.65 $15.93 1.00 11.117 $34.14 $379,53 Health Physics Technician Totallabor cost $2,656.99 i

4. EQUIPMENT & CONSUMABLES COSTS I 1

Equipment Costs none Consumables/ Materials Costs

. Blotting paper 50 @ $0.52 sq ft {2} $26.00

-Plastic sheets / bags 50 @ $0.12/sq ft {3} $6.00

-Gas torch consumables 1 @ $8.68/hr x 1 hr (1} S8.68 Subtotal cost of equipment and materials $40.68 S7,02 Overhead & profit on equipment and materials @ 17.250%

. Total costs, equipment & material $47.70 TOTAL COST Removal of contaminated heat exchanger <3000 pounds: $2,704.69 l

$2,656.99

. Totallabor cost:

Total equipment / material costs: $47.70 Total adjusted exposure man hours incurred: 45.860 Total craft labor man-hours required per unit: 81.154 .

I

Documsnt P01-1252-002, R:v. 0 Dishin C:nyon PawirPl:nt

- Appendix A, Page d ef 4 APPENDIX A '

(continued)

6. NOTES AND REFERENCES

1. Durations are shown in minutes. The integrated duration accounts for those activities' that can be performed in conjunction with other activities, indicated by the alpha designator of the concurrent activity.

This results in an overall decrease in the sequenced duration.

2. Work difficulty factors were developed in conjunction with the AIF program to standardize decommissioning cost studies and are delineated in the " Guidelines" study (Ref. 8, Vol.1, Ch. 5).

3. Adjusted for regional material costs for San Francisco, CA.

4.

References:

1. R.S. Means (1997) Division 016 Section 420 6360 pg 19

2. McMaster-Carr Ed.101

3. R.S. Means (1997) Division 015 Section 602 0200 pg 13

1 Di blo Canyon PowerPlant Document P01-1252-002, Rev. 0 1

- Appendix B, Page 1 of 8 l

l-l .  :

APPENDIX B UNIT COST FACTOR LISTING  ;

(DECON: Power Block Structures Only) 4 I

m Dizbb Cenyon P:wer Plant Document P01-1252-002, R:v. 0

. Appendix B, Page 2 cf 8 APPENDIX B UNIT COST FACTOR LISTING (Power Block Structures Only)

Unit Cost Factor Cost / Unit ($)

Removal of clean instrument and sampling tubing, $/ linear foot $0.31 Removal of clean pipe 0.25 to 2 inches diameter, $/ linear foot $3.87 Removal of clean pipe >2 to 4 inches diameter, $/ linear foot $4.71 Removal of clean pipe >4 to 8 inches diameter, $/ linear foot $9.08 Removal of clean pipe >8 to 14 inches diameter, $/ linear foot $17.62 Removal of clean pipe >14 to 20 inches diameter, $/ linear foot $22.90 Removal of clean pipe >20 to 36 inches diameter, $/ linear foot $33.70 Removal of clean pipe >36 inches diameter, $/ linear foot $40.04 Removal of clean valves >2 to 4 inches $48.81 Removal of clean valves >4 to 8 inches $90.78 Removal of clean valves >8 to 14 inches $176.19 Removal of clean valves >14 to 20 inches $229.02 Removal of clean valves >20 to 36 inches $336.98 Removal of clean valves >36 inches $400.41 Removal of clean pipe hangers for small bore piping $20.65 Removal of clean pipe hangers for large bore piping $ 74.37 Removal of clean pumps, <300 pound $151.37 Removal of clean pumps, 300 1000 pound $418.39 ,

Removal of clean pumps,1000-10,000 pound $1,666.97 Removal of clean pumps, >10,000 pound $3,213.26 Removal of clean pump motors, 3001000 pound $176.57 Removal of clean pump motors,100010,000 pound $695.12 Removal of clean pump motors, >10,000 pound $1,564.00 i Removal of clean turbine driven pumps < 10,000 pound $1,924.85 Removal of clean turbine-driven pumps > 10,000 pounds $4,299.34

g Diabb Canyon Power Pisnt D:cument P01-1252-002, Rev. 0

. Appendix B, Page 3 cf 8 APPENDIX B (continued)

Unit Cost Factor - Cost / Unit ($)

l Removal of clean PWR turbine-generator $101,989.18 i Removal of clean heat exchanger <3000 pound $897.85 Removal of clean heat exchanger >3000 pound $2,259.99 Removal of clean feedwater heater /deaerator $6,370.92 Removal of clean moisture separator / reheater $13,097.53 Removal of clean PWR main condenser $288,803.09 Removal of clean tanks, <300 gallons $196.93 Removal of clean tanks, 300 3000 gallon $62LO4 Removal of clean tanks, >3000 gallons, $/ square foot surface area $5.17 Removal of clean electrical equipment, <300 pound $83.20 Removal of clean electrical equipment, 300 1000 pound $287.49 i Removal of clean electrical equipment,1000 10,000 pound $574.97

. Removal of clean electrical equipment, >10,000 pound $1,363.28 l Removal of clean electrical transformers < 30 tons $946.78 Removal of clean electrical transformers > 30 tons $2,726.57 Removal of clean standby diesel generator, <100 kW $967.06 Removal of clean standby diesel generator,100 kW to 1 MW $2,158.54 Removal of clean standby diesel-generator, >l MW $4,468.60 Removal of clean electrical cable tray, $/ linear foot $7.81 -

Removal of clean electrical conduit, S/ linear foot $3.41 Removal of clean mechanical equipment, <300 pound $83.20 Removal of clean mechanical equipment, 300 1000 pound $287.49 Removal of clean mechanical equipment,1000 10,000 pound $574.97 Removal of clean mechanical equipment, >10,000 pound $1,363.28 Removal of clean HVAC equipment, <300 pound $83.20

m Disbb Crnyon P;werPlant D:cument P01-1252-002, Rev. O  !

Appendix B, Page 4 of 8 233552 i J

APPENDIX B (continued)

{

. Unit Cost Factor Cost / Unit ($)

Removal of clean HVAC equipment, 300-1000 pound $287.49 l

$574.97 i Removal of clean HVAC equipment,1000-10,000 pound '

- Removal of clean HVAC equipment, >10,000 pound $1,363.28 Removal of clean HVAC ductwork, $/ pound $0.61 Removal of contaminated instrument and sampling tubing, $/ linear foot $0.99 Removal of contaminated pipe 0.25 to 2 inches diameter, $/ linear foot $24.83 Removal of contaminated pipe >2 to 4 inches diameter, $/ linear foot $43.90 Removal of contaminated pipe >4 to 8 inches diameter, $/ linear foot $69.95 Removal of contaminated pipe >8 to 14 inches diameter, $/ linear foot $139.26 Removal of contaminated pipe >14 to 20 inches diameter, $/ linear foot $168.45 Removal of contaminated pipe >20 to 36 inches diameter, $/ linear foot $234.70 Removal of contaminated pipe >36 inches diameter, $/ linear foot $279.19 Removal of contaminated valves >2 to 4 inches $207.87 Removal of contaminated valves >4 to 8 inches $337.83 Removal of contaminated valves >8 to 14 inches $696.32 Removal of contaminated valves >14 to 20 inches $884.23

$1,173.49 Removal of contaminated valves >20 to 36 inches

$1,395.94 Removal of contaminated valves >36 inches Removal of contaminated pipe hangers for small bore piping $67.88 Removal of contaminated pipe hangers for large bore piping $223.81 Removal of contaminated pumps, <300 pound $598.46 Removal of contaminated pumps, 300 1000 pound . $1,380.44 Removal of contaminated pumps,1000-10,000 pound $4,472.45 Removal of contaminated pumps, >10,000 pound $10,867.02 l

Removal of contaminated pump motors, 3001000 pound $597.45 1

i l

i

j. . Ditblo Ccnyon Power Plant Document P01 1252-002, Rev. 0

- Appendix B, Page 5 of 8 l

l l

APPENDIX B i (continued) 1

- Unit Cost Factor Cost / Unit ($)

Removal of contaminated pump motors,1000-10,000 nound $1,823.68 l Removal of contaminated pump motors, >10,000 pound $4,103.29 Removal of contaminated turbine driven pumps < 10,000 pounds $5,500.74

- Removal of contaminated turbine driven pumps > 10,000 pounds $12,528.01 l Removal of contaminated heat exchanger <3000 pound $2,704.69 Removal of contaminated heat exchanger >3000 pound $7,850.94 Removal of contaminated tanks, <300 gallons $1,004.97 l Removal of contaminated tanks, >300 gallons, $/ square foot $19.40 4 Removal of contaminated electrical equipment, <300 pound $461.56 Removal of contaminated electrical equipment, 300 1000 pound $1,105.08 Removal of contaminated electrical equipment,1000-10,000 pound $2,129.85 Removal of contaminated electrical equipment, >10,000 pound $4,154.74 Removal of contaminaz ? electrical cable tray, $/ linear foot $33.19 Removal of contaminax tiectrical conduit, $/ linear foot $41.81 Removal of contaminated mechanical equipment, <300 pound $511.59 Removal of contaminated mechanical equipment, 300 1000 pound $1,222.64 Removal of contaminated mechanical equipment,1000-10,000 pound $2,358.70 Removal of contaminated mechanical equipment, >10,000T eund $4,154.74 Removal of contaminated HVAC equipment, <300 pound $511.59 Removal of contaminated HVAC equipment, 300-1000 pound $1,222.64 Removal of contaminated HVAC equipment,100010,000 pound $2,358.70 Removal of contaminated HVAC equipment, >10,000 pound $4,154.74 Removal of contaminated HVAC ductwork, $/ pound $2.16 Removal / plasma are cut of contaminated thin metal components, $/ linear in. $2.44 Additional decontamination of surfacc by washing, $/ square foot $5.24 l

t

Dirbis Canyon P werPlant Document P01-1252-002, Rev. 0

. Appendix B, Page 6 of 8 APPENDIX B (continued)

Unit Cost Factor Cost / Unit ($)

Additional decontamination of surfaces by hydrolasing, $/ square foot $21.52 Decontamination rig hook up and flush $4,355.22 Chemical flush of components / systems, $/ gallon $10.20 Removal of clean standard reinforced concrete, $/ cubic yard $316.85 Removal of grade slab concrete, $/ cubic yard $167.66 Removal of clean concrete floors, $/ cubic yard $217.87 Removal of sections of clean concrete floors, $/ cubic yard $689.89 Removal of clean heavily rein concrete wM9 rebar, $/ cubic yard $170.81 Removal of contaminated heavily rein concrete wM9 rebar, $/ cubic yard $1,395.05 Removal of clean heavily rein concrete wM18 rebar, S/ cubic yard $217.49 Removal of contaminated heavily rein concrete w/#18 rebar, $/ cubic yard $1,848.81 Removal heavily rein concrete wM18 rebar & steel embedments, S/cu yd $314.10 Removal of below-grade suspended floors, $/ square foot $217.87 .

Removal of clean monolithic concrete structures, $/ cubic yard $597.15 Removal of contaminated monolithic concrete structures, $/cu yd $1,393.29 Removal of clean foundation concreta, $/ cubic yard $469.51 Removal of contaminated foundation concrete, $/ cubic yard $1,296.64 Explosive demolition of bulk concreto, $/ cubic yard $23.60 l Removal of clean hollow masonry block wall, $/ cubic yard $67.14 l Removal of contaminated hollow masonry block wall, $/ cubic yard $213.19 Removal of clean solid masonry block wall, $/ cubic yard $67.14 Removal of contaminated solid masonry block wall, $/ cubic yard $213.19 Backfill of below-grade voids, $/ cubic yard $17.85

. Removal of subterranean tunnels / voids, $/ linear foot $100.76 Placement of concrete for below-grade voids, $/ cubic yard $86.45 l

l I

{

.Dizbla C nyon P:werPlant Documsnt P01-1252-002, Rev. 0 Appenaix B, Page 7 of 8 f

APPENDIX B (continued) l Unit Cost Factor Cost / Unit ($)

Excavation of clean material, $/ cubic yard $2.88 Excavation of contaminated material, $/ cubic yard $7.36 l Excavation of submerged concrete rubble, $/ cubic yard $9.57 Removal of clean concrete rubble, $/ cubic yard $75.48 Removal of contaminated concrete rubble, $/ cubic yard $24.59 >

Removal of building by volume, $/ cubic foot $0.20 Removal of clean building metal siding, $/ square foot $1.04 Removal of contaminated building metal siding, $/ square foot $3.34 Removal of standard asphalt roofing, $/ square foot $1.45 Removal of transite panels, $/ square foot $1.51

- Scarifying contaminated concrete surfaces (drill & spall) $10.48 Scabbling contaminated concrete floors, $/ square foot $1.54 Scabbling contaminated concrete walls, $/ square foot $5.97 Scabbling contaminated ceilings, $/ square foot $59.66 Scabbling structural steel, $/ square foot $4.96 Removal of clean overhead cranes / monorails < 10 tot. enty $398.65 Removal of contaminated overhe..d cranes / monorails < 10 ton capacity $1,139.46 Removal of clean overhead cranes / monorails >10 50 ton capacity $956.74 Removal of contaminated overhead cranes / monorails >10 30 ton capacity $2,725.66 Removal of polar cranes > 50 ton capacity, each $3,989.34 Removal of gantry cranes > 50 ton capacity, each $17,041.05 Removal of structural steel, $/ pound $0.25 Removal of clean steel floor grating, $/ square foot $2.22 Removal of contaminated steel floor grating, $/ square foot $6.80 Removal of clean free-standing steelliner, $/ square foot $7. 76 l

l

f Dirbis C:nyon Power PI:nt Documsnt P01-1252-002, Rev. 0 Appendix B, P, ge J cf 8 APPENDIX B (continued)

Unit Cost Factor Cost / Unit ($)

Removal of contaminated free-standing steelliner, $/ square foot $22.37 Removal of clean concrete anchored steelliner, $/ square foot . $3.88 Removal of contaminated concrete anchored steelliner, $/ square foot $26.23 Placement of scaffolding in clean areas, $/ square foot $4.41 Placement of scaffolding in contaminated areas, $/ square foot . $10.22 Landscaping w/o topsoil, $/ acre $2,743.03 Cost of CPC B-88 LSA b)x & preparation for use $938.63 Cost of CPC B 25 LSA box & preparation for use $879.39 Cost of CPC B-12V 12 gauge LSA box & preparation for use $775.91 Cost of CPC B 144 LSA box & preparation for use $4,441.30 Cost of LSA drum & preparation for use $97.51 Cost of cask liner for CNSI 14-195 cask $9,349.36

$9,275.27 Cost of cask liner for CNSI 8-120A cask (resins)

Cost of cask liner for CNSI 8120A cask (filters) $9,275.27 Decontamination of surfaces with vacuuming, $/ square foot $0.49

. . DI:blo Ccnyon P:wer Plant Document P01-1252-002, Rev. 0 Appsndix C, Page i cf 33 l

1 l

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