ML20065Q399
| ML20065Q399 | |
| Person / Time | |
|---|---|
| Site: | Clinch River |
| Issue date: | 09/30/1981 |
| From: | Allen R UNITED ENGINEERS & CONSTRUCTORS, INC. |
| To: | |
| Shared Package | |
| ML20065Q355 | List: |
| References | |
| COO-6411-1, UE&C-ANL-810930, NUDOCS 8210270060 | |
| Download: ML20065Q399 (421) | |
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U E&C-ANL-810930 COO-641 1 - 1 PHASE IV FINAL REPORT AND FOURTH UPDATE OFTHE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM
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PREPARED FOR THE U.S. DEPARTMENT OF ENERGY (ARGONNE NATIONAL LABORATORY) UNDER CONTRACT NUMBER 31-109-38-6411 VOLUMEIOFI BY - UPJB!!!e.ggineers - SEPTEMBER 1981 8210270060 821022 l PDR ADOCK 05000537 G PDR
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g mited engineersa-m 30 South 17th Street Post Office Box 8223 muoxvius Philadelphia, PA 19101 mLAostma vantyponot September 30, 1981 Mr. L. W. Fromm Office of International Energy Development Programs Building 362 Argonne National Laboratory 9700 South Cass Avenue Argonne, IL 60439
Dear Mr. Fromm:
Subject:
U. S. Department of Energy (Argonne National Laboratory) Energy Economic Data Base (EEDB) Program-Phase IV Contract No. 31-109-38-6411 We are transmitting herewith twenty-five (25) copies of " Phase IV Final Report and Fourth Update of the Energy Economic Data Base (EEDB) Program", dated September, 1981. By copy of this letter, these copies are distributed as indicated below, in accordance with the subject contract. (' This document is the final report for work done under Phase IV of the subject contract. The report discusses the Energy Economic Data Base and presents the results of the Fourth Update of the data base, for the effective ~ cost and regulation date of January 1, 1981. Section 4 in general, and Tables 4-1, 4-2, and 4-4, in particular, summarize the technical features and the capital, fuel and operating and maintenance costs of the 11 nuclear and alternative power generating stations in the data base. This final report contains all of the deliverables required under the subject contract, with the exception of the CONCICE AND PEGASUS cost commodity and equipment computer printouts. CONCICE/ PEGASUS cost / equipment and commodity computer printouts are bound separately because of their bulk. One (1) copy of each of 29 volumes of printouts were forwarded to Mr. R. J. Akin, ANL-GTN under cover of transmittal letter UE&C/ DOE-EEDB-IV-11, dated September 4, 1981, in accordance with the subject contract. Very truly yours, R & AlTen EEDB Program Project Manager REA/mab Enclosures Distribution L. W. Fromm, ANL-IL (2) Contract Administrator, ANL-IL (2) R. J. Akin, ANL-GTN (17) Reviewers (4) M END
CONTENTS PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM Legal Notice i List of Principal Contributors ii List of Tables iii List of Figures ix Title Section Introduction 1 Description df the Energy Economic Data Base 2 Assumptions and Ground-Rules for the Fourth Cost Update 3 Summary of Fourth Cost Update 4 Capital Cost Fourth Update 5 Fuel Cost Fourth Update 6 Operation and Maintenance Cost Fourth Update 7 References and Glossary 8 Appendices Description of Standard Hypothetical Middletown Site A-1 for Nuclear Power Plants Description of Standard Hypothetical Middletown Site A-2 for Coal-Fired Power Plants Fixed Charge Rates (without inflation) B i Technical Model Initial Update C-1 Technical Model Second Update C-2 Technical Model Third Update C-3 U.S. Nuclear Regulatory Commission Regulatory Guide Review p Description of Reactor Types and Their Fuel Cycles E
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l LEGAL NOTICE ( ' ( ~ PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM This report was prepared under the funding of the U.S. Department of Energy (Argonne National Laboratory) Contract No. 31-109-38-6411. Neither the United States Government or any agency thereof,'nor any person acting on behalf of the United States Government;
- a. makes any warranty or representation, expressed or implied with respect to the accuracy, completeness, or usefulness of the information contained in this report, or that the use o.f any .
Information, apparatus, method or process disclosed in this report may not infringe privately owned rights, or ( b. assumes any liabilities with respect to the use of, or for damage resulting from the use of, any information, apparatus, method, or process disclosed in this report. As used in the above " person acting on behalf of the United Stace.a Government" includes any employee or contractor thereof or any employee of such contractor to the extent that such employee prepares, disseminates, or provides access to, any information pursuant to his employment or contract with the United States Govern =ent, or his employment with such contractor. 1
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3 LIST OF PRINCIPAL CONTRIBUTORS PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM J. H. Crowley, Manager Advanced Engineering Department
*R. E. Allen, Program Project Manager Energy Economic Data Base Program R. G. Benedict
*P. E. Brown J. S. Hodson
*R. S. Kaminski R. J. Martin A. T. Molin
*M. H. Smith A. S. Woodhull
*E. J. Ziegler
- Principal Authors ii
9 Shsst 1 of 6 TABLE LIST PHASE 17 FINAL REPORT AND FOURTH UPDATE OF THE ENERG'Y ECONOMIC DATA BASE (EEDB) PROGRAM Table Number Title 1-1 Fourth Update Nuclear Power Generating Stations 1-2 Fourth Update Comparison Power Generating Stations 1-3 Technical and Capital Cost Models Base Data, Studies and Reports 1-4 Fuel Cost Models Base Data Studies and Reports 1-5 Operating and Maintenance Cost Models Base Data Studies and Reports 2-1 Mini-Specification - Circulating Water Pump 2-2 Mini-Specification - Circulating Water Pump Sv$tchgear 2-3 Code of Accounts Example of Levels of Detail 2-4 Relationship of " CONCEPT" to "CONCICE" 2-5 (. Example of Two-Digit Level Cost Estimate 1190 MWe Boiling Water Reactor 2-6 Input Nuclear Fuel Cost Components - PWR-US(LE)/U-T 2-7 Output Nuclear Fuel Cost Components - PWR-US(LE)/U-T 2-8 Summary of Annual Nonfuel Operation and Maintenance Costs for (PWR) Nuclear Plant 2-9 Summary of Annual Nonfuel' operation and Maintenance Costs for (HS12) Coal Plant 2-10 Cost Bases for Power Plant Capital Cost Estimates 4-1 Nuclear Plant Technical Models Base Parameter Summary 4-2 Comparison Plant Technical Models Base Parameter Summary 4-3 Mass Flows Selected for Nuclear Plant Fuel Cycles 4-4 Cost Update Sum =ary ($1981) 4-5 Normalized (1139 MWe) Cost Update Summary ($1981) 4-6 Normalized (3800 MWt) Cost Update Summary ($1981) iii , t
Shast 2 of 6 TABLE LIST PHASE IV FINAL REPORT AND FOURTH UDPATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM Table Number Title 4-7 Cost Update Summary ($1981) - Footnotes for Tables 4-4, 4-5 and 4-6 4-8 Commodity Summary of Nuclear Power Generating Stations 4-9 Commodity Su= mary of Fossil Power Generating Stations 4-10 Site Labor Summary for Nuclear Power Generating Stations 4-11 Site Labor Sum =ary for Fossil Power Generating Stations 5-1 Capital Cost Update Summary ($1981) 5-2 Normalized (1139 MWe) Capital Cost Update Summary ($1981) 5-3 Normalized (3800 MWt) Capital Cost Update Sun =ary ($1981) 5-4 1190 MWe Boiling Water Reactor NPGS Capital Cost Estimate 5-5 858 MWe High Temperature Gas Cooled Reactor - Steam Cycle NPGS Capital Cost Estimate [' 5-6 1139 MWe Pressurized Water Reactor NPGS Capital Cost Estimate 5-7 1260 MWe Pressurized Heavy Water Reactor NPCS Capital Cost Estimate 5-8 150 MWe High Temperature Gas Cooled Reactor - Process Steam NPGS Capital Cost Estimate 5-9 1457 MWe Liquid Metal Fast Breeder P.eactor NPGS Capital Cost Estimate 5-10 1240 MWe High Sulfur Coal FPGS Capital Cost Estimate 5-11 795 MWe High Sulfur Coal FPGS Capital Cost Estimate 5-12 1244 MWe Low Sulfur Coal FPGS Capital Cost Estimate 5-13 795 MWe Low Sulfur Coal FPGS Capital Cost Estimate 5-14 630 MWe Coal Casification Combined Cycle FPGS Capital Cost Estimate P 5-15 Commodity and Craft Manhour Su msry 1190 MWe Boiling Water Reactor Fuclear Power Generating Station iv
Sheet 3 of 6 TABLE LIST PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ~ ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM ~ Table Number Title 5-16 Commodity and Craft Manhour Summary 858 MWe High Temperature Gas Cooled Reactor - Steam Cycle Nuclear Power Generating Station 5-: ' Commodity and Craf t Manhour Summary - 1139 MWe Pressurized Water Reactor Nuclear Power Generating Station 5-18 Commodity and Craft Manhour Summary 1250 MWe Pressurized Heavy Water Reactor Nuclear Power Generating Station 5-19 Commodity and Craf t Manhour Summary 1457 MWe Liquid Metal Fast-Breeder Reactor Nuclear Power Generating Station 5-20 Commodity and Craft Manhour Summary 1240 MWe High Sulfur Coal-Fired Fossil Power Generating Sta' tion 5-21 Commodity and Craf t Manhour Summary ( 795 MWe High Sulfur-Coal-Fired Fossil Power Generating Station l 5-22 Commodity and Craft Manhour Summary 1244 MWe Low Sulfur Coal-Fired Fossil Power Generating Station 5-23 Commodity and Craf t Manheur Summary 795 MWe Low Sulfur Coal-Fired Fossil Power Generating Station 6-1 Fuel Cost Update Summary - 2001 Startup 6-2 Fuel Cost Update Summary - 1981 Startup 6-3 Fuel Cost Update Summary - Variable Startup 6-4a Input Nuclear Fuel Cost Components - PWR-US(LE)/U-T 1981 Startup 6-4b Outppt Nuclear Fuel Cost Components - PWR-US(LE)/U-T 1981 Startup 6-Sa Input Nuclear Fuel Cest Components - PWR-US(LE)/U-T 1987 Startup ' V
Shsst 4 of 6 TABLE LIST PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM Table Number Title 6-Sb output Nuclear Fuel Cost Components - PWR-US(LE)/U-T 1967 Startup 6-6a Input Nuclear Fuel Cost Components - PWR-U5(LE)/U;T 2001 Startup 6-6b Output Nuclear Fuel Cost Components - PWR-US(LE)/U-T 2001 Startup 6-7a Input Nuclear Fuel Cost Components - HTGR-U5/U/Th-20%-T 1995 startup 6-7b Output Nuclear Fuel Coct Components - HTGR-U5/U/Th-20%-T 1995 Startup 6-8a Input Nuclear Fuel Cost Components - HTGR-US/U/Th-20%-T 2001 Startup 6-8b Output Nuclear Fuel Cost Components - HTGR-U5/U/Th-20%-T 2001*Startup ( 6-9a Input Nuclear Fuel Cost Components - PHWR-US(SE)/U-T 1995 Startup 6-9b Output Nuclear Fuel Cost Components - PHWR-US(SE)/U-T 1995 Startup 6-10a Input Nuclear Fuel Cost Components - PHWR-US(SE)/U-T 2001 Startup 6-10b Output Nuclear Fuel Cost Components - PHWR-US(SE)/U-T 2001 Startup 6-11a Input Nuclear Fuel Cost Components - LMFBR-Pu/U/U/U-HT 2001 Startup 6-11b Output Nuclear Fuel Cost Cc~ pen;nts - LMFBR-Pu/U/U/U-HT 2001 Startup 6-12 Explanation of Fuel Cycle System Designation vi 1
Shsst 5 of 6 TABLE LIST [' 4 PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM Table , Number Title 6-13a Coal Fuel Cost Components, 1981 Startup 6-13b Coal Fuel Cost Components, 1987 Startup 6-13e Coal Fuel Cost Components, 2001 Startup 6-14 Projected U 0 Costs 38 6-15 Summary of Fuel Cycle Lead and Lag Times 6-16 Sum ary of 30-Year Levelized Fuel Cycle Costs - Variable Startups 6-17 Su= mary Breakdown of 30-Year Levelized Fuel Cycle Costs - -- Variable Startups 6-18 Base Reactors and Their Fueling Modes 30-Year Levelized Costs - Variable Startups 6-19 Fuel Cycle Cost Components Percentage Values - Variable Startups ' ( 6-20 Average Delivered Contract Prices of Steam Coal 6-21 High Sulfur Coal Analysis 6-22 Low Sulfur Coal Analysis l 6-23 Pittsburgh Steam (High Sulfur) Coal Analysis 7-1 Operation and Maintenance Cost Update (S1981) 7-2 Summary of Annual Nonfuel Operation and Maintenance Costs for BWR Steam-Electric Power Plants in 1981 7-3 Su= mary of Annual Nonfuel Operation and Maintenance Costs for HTGR-Steam Ccyle Steam-Electric Power Plants in 1981 7-4 Summary of Annual Nonfuel Operation and Maintenance Costs for PWR Steam-Electric Power Plants in 1981 7-5 Summary of Annual Monfuel Operation and Maintenance Costs for PHWR Steam-Electric Power Plants in 1981 7-6 Summary of Annual Nonfuel Operation and Maintenance Costs for HTCR-Process Steam Cogeneration Steam-Electric Power Plants in 1981 7-7 Su= mary of Annual Nenfuel Operation and Maintenance Costs for LMFBR Steam-Electric Power Plants in 1981 vii
Shast 6 of 6 TABLE LIST [ PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM Table i Number Title l 7-8 Summary of Annual Nonfuel Operation and Maintenance Costs for 1240 MWe High-Sulfur Coal-Fired Steam-Electric Power Plants with FGD Systems in 1981 ]
- 7-9 Summary of Annual Nonfuel Operation and Maintenance Costs for 795 MWe High Sulfur Coal-Fired Steam-Electric Power Plants with FGD Systems in 1981 7-10 Summary of Anr.ual Nonfuel Operation and Maintenance Costs for 1244 MWe Low-Sulfur Coal-Fired Steam-Electric Power Plants with FGD Systems in 1981 i 7-11 Summary of Annual Nonfeel Operation and Maintenance Costs for 795 MWe Low Sulfur Coal-Fired Steam-Electric Power Plants with FGD Systems in 1981 7-12 Summary of Annual Nonfuel Operation and Maintenance Costs for 630 MWe CGCC Steam -Electric Power Plants sith FGD Systems in 1981 7-13 Staff Requirement for LWR Power Plants
( 7-14 Staff Requirement for HTCR-Steam Cycle Power Plants 7-15 Staff Requirement for PHWR Power Plants 7-16 Staff Requirement for HTGR-Process Steam Cogeneration Power Plants I 7-17 Staff Requirement for LMFBR Power Plants 7-18 Staff Requirement for Coal-Fired Power Plants with FGD Systems t viii
Shsst 1 of 1 FIGURE ?.IST I P!!ASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM Figure Number Title 6.1 Nuclear Fuel Cycle Activities l l o l ix l l
SECTION 1
1.0 INTRODUCTION
1.1 AUTHORIZATION . The Energy Economic Data Base (EEDB) Program, which deals with the develop-ment of cost data for nuclear and comparison electric power generating stations, is authorized by the U.S. Department of Energy (USDOE) and fundad under Argonne National Laboratories (ANL) Contract Number 31-109-38-6411 with United Engineers & Constructors, Inc. 1.2 OBJECTIVE The objective of the USDOE EEDB Program is to provide periodic updates of technical and cost (capital, fuel and operating and mainte6ance) information of significance to the U.S. Department of Energy. This information is intended to be used by USDOE in evaluating and monitoring U.S. Civilian nuclear power programs, and to provide them with a consistent means of evaluating the nuclear option and proposed alternatives. 1.3 THE FOURTH UPDATE In achieving the objective of the EEDB Program, the first-order task of assembling the data base itself and of providing the Initial Update (1978) is complete. The second order task of providing periodic updates is initiated with the Second Update (1979) and continued with the Third Update (1980). This report presents the Fourth Update of the EEDB for a cost and regulation date of January 1, 1981, prepared during Phase IV of the EEDB Program. The intent of the format and structure of this and prior reports is to pro-vide a historical record of the evolution of the data base cost estimates and to provide convenience to the user. Therefore, the organization of the 1-1
first report is retained and the important descriptive and tutorial informa-tion concerning the structure and use of the EEDB, is repeated. This should minimize the necessity to refer to previous reports in the use of this report but simplify such reference when it is required. The data tables, which make up the bulk of the report, are updated to January 1,1981. The data in these tables and in the backup data file, described in Section 2, supercede the information presented in the Third Update (1980). Where required, new descriptive information is added in the text to supplement the data tables. 1.4 CHANGES TO THE DATA BASE FOR THE FOURTH UPDATE Zn general, the Fourth Update is a data base maintenance effort, because of a reduced availability of resources during FY 1981. This effort is consistent with and an extension of the major refinements made in the Third Update (1980). Specifically, the following activities are pursued in the Fourth Update, to improve the overall quantity of the data base:
- a. Individual components of the data base are reviewed for technical adequacy and internal consistency.
- b. Adjustments are made to the Nuclear Power Generating Station (NPGS) Technical, Capital Cost, and Operating and Maintenance Cost Models to reflect the lessons learned from the Three-Mile Island NPGS incident of March 28, 1979.
- c. Modifications initiated in the Third Update, to $mprove the technical consistency of the PHWR and LMFBR, are continued in l the Fourth Update.
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- d. Modifications initiated in the Third Update, to improve the technical adequacy of piping systems that are major cost drivers in various technical models, are continued in the Fourth Update,
- s. Capital, Fuel, and Operating and Maintenance Costs are adjusted to reflect the results of the activities listed in paragraphs "a" through "d" above and are updated to January 1, 1981.
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A more detailed discussion of each of these changes appears at the appropriate place in the text of this report. 1.5 DATA BASE COMPONENTS Currently, the EEDB contains six nuclear power generating station (NPGS) technical models and five comparison coal-fired fossil power generating station (FPGS) technical models. Each of these technical models is a complete, detailed, conceptual design for a single unit, steam electric power generating station located on a standard, hypothetical "Middletown" site. Tables 1-1 and 1-2 list respectively the six nuclear and five comparison electrical power generating stations and their associated capabilities. A description of the "Middletown" site is provided in Appendix A-1 for nuclear plants, and Appendix
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A-2 for coal-fired plants.
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Technical models and capital costs for these plants are based on evaluation of related capital cost studies prepared for the U.S. Department of Energy and its predecessor agencies, the Energy Research and Development Administration (ERDA) and the Atomic Eenrgy Commission (AEC), and for the Nuclear Regulatory Commission, (NRC) and its predecessor agency, the Atomic Energy Commission, l over the last 18 years. In addition, other studies, prepared for various t government agencies and other organizations, also contribute to the develop-ment of the capital, fuel, and operating and maintenance (0&M) costs data presented in this report. The Base Studies and Reports, from which this Fourth Update has evolved for the technical and capital,' fuel and O&M cost data, are l tabulated in Tables 1-3, 1-4, and 1-5. These and other associated studies and reports are tabulated more specifically in the list of references ( included in Section 8. I 1-3 l I
1.6 ORGANIZATION OF THE REPORT Section 2 of this report provides a description of the current Data Base, as of September 30, 1981. In Section 3, assumptions and groundrules for this cost update are identified. Section 4 summarizes the Fourth Cost Update, with cost results summarized in Tables 4-4, 4-5, and 4-6. Section 5 presents the details of the Fourth Update of the technical conceptual design, the capital cost, the quantities of commodities and their unit costs, and the craft labor manhours and costs for each EEDB Program model., Section 6 and 7 describe the details of the Fuel Cost Fourth Update and the Operating and Maintenance Costs Fourth Update, respectively. Section 8 contains a glossary of acronyms and abbreviations used in this report, as well as the complete list of references cited above.
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Effective Date - 1/1/81 TABLE 1-1 ENERGY ECONOMIC DATA BASE FOURTH UPDATE NUCLEAR POWER CENERATING STATIONS EEDB Model Net Number Plant Type Qpacity Al Boiling Water Rea.ctor Plant (BWR) 1190 MWe A2 High Temperature Gas Cooled Reactor Plant - Steam Cycle (HTGR-SC) 858 MWe , Y w A3 Pressurized Water Reactor Plant (PWR) 1139 MWe A4 Pressurized Heavy Water Reactor Plant (PHWR) 1260 MWe B1 High Temperature Gas Cooled Reactor Plant - Process Steam (!ITGR-PS) 150 MWe A5 Liquid Metal Fast Breeder Reactor Plant (LMFBR) 1457 MWe
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l Effective Date - 1/1/81 TABLE 1-2 EMERGY ECONOMIC DATA BASE FOURTH UPDATE COMPARISON POWER GENERATING STATIONS EEDB lbdel Net Number Plant Type Capacity C1 Comparison High Sulfur Coal Plant (HS12) 1240 MWe
- r. C2 Comparison High Sulfur Coal Plant (HS8) 795 MWe 1
C3 Comparison Low Sulfur Coal Plant (LS12) 1244 MWe C4 Comparison Low Sulfur Coal Plant (LS8) 795 MWe DI Comparison Coal Gasification Combined Cycle Plant (CCCC) 630 MWe
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Effective Date - 1/1/81 TABLE 1-3 ENERGY ECONOMIC DATA BASE TECilNICAL AND CAPITAL COST MODELS BASE DATA STUDIES AND REPORTS EEDB Model Model Number Type Base Data Study or Report
- Al BWR Commercial Electric Power Cost Studies - Capital Cost - Boiling Water Reactor Plant (NUREC-0242, C00-2477-6)
A2 IITCR-SC The llTCR for Electric Power Generation - Desien and Cost Evaluation (Cas Cooled Reactor Associates - CCRA/AE/78-1) A3 PWR Commercial Electric Power Cost Studies - Capital Cost - Pressurized Water Reactor Plant (NUREC-0241, C00-2477-5) A4 PIIVR Conceptual Design of a Large IIWR fot U.S. Siting (Combustion Engineering, Inc. - CEND-379) B1 IITCR-PS 1170 MWt liTGR Steamer Coueneration Plant - Design and Cost Study (UE&C/ DOE - 800716) AS LMFBR NSSS Capital Costs for a Mature LMFBR Industry and Addendum (Combustion Engineering, Inc. - CE-FBR-78-532 & CE-ADD-80-310 C1 IIS12 Commercial Electric Power Cost Studies - Capital Cost - High and Low Sulfur Coal Plants - 1200 MWe (Nominal) (NUREC-0243, C00-2477-7) C2 IIS8 Commercial Electric Power Cost Studies - Capital Cost - Low and liigh Sulfur Coal Plants - 800 MWe (Nominal) (NUREG-0244, C00-2477-8) C3 LS12 Same as EEDB Model C1 C4 LS8 Same as EEDB Hodel C2 DI CCCC Study of Electric Plant Applications for Low Btu Casification of Coal for Electric Power Generation (FE-1545-59)
- Refer to Section 8.1 for additional details
Effective Date - 1/1/81 TABLE l-4 ENERGY ECONOMIC DATA BASE FUEL COST MODELS BASE DATA STUDIES AND REPORTS EEDB Model Model Number Type Base Data Study or Report
- S Al BWR A2 HTGR-SC i A3 PWR a. Commercial Electric Power Cost Studies -
Fuel Supply Investment Cost: Coal and Nuclear (NUREG-0246, C00-2477-10) A4 PHWR
- b. Commercial Electric Power Cost Studies - Total
[ B1 HTGR-PS Generating Costs: Coal and Nuclear Plants (NUREG-0248, C00-2477-12)
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AS LMFBR
- c. Fuel Cost Projections (NUREG/CR-1041)
Cl HS12
- d. Fuel Cost Estimates for LWR, HTGR C2 HS8 CANDU Type HWR, LMFBR and GCFR (NUS-3190) i
- C3 LS12 C4 LS8
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D1 CGCC Study of Electric Plant Applications for Low Btu Gassification of Coal for Electric Power Generation (FE-1545-59) 0 l
- Refer to Section 8.1 for additional details 1
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Effective Date - I/1/gi IABLE l-5
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ENERGYECONOMIbDATABASE OPERATING AND MAINTENANCE COST MODELS BASE DATA STUDIES AND REPORTS EEDB Model Model Number Typ'e Base Data Study or Report
- Al BWR A Procedure for Estimating Nonfuel Operating and Maintenance Costs for Large Steam-Electric Power
, Plants; ORNL/TM-6467 A2 HTGR-SC Guidelines for Estimating Nonfuel Operating and Maintenance Costs for Alternative Nuclear Power Plants; ORNL/TM-6860 -
A3 PWR Same as Model Al A4 PHWR Same as Model A2 B1 HTGR-PS Same as Model A2 l AS LMFBR Same as Model A2 Cl HS12 Same as Model Al C2 HS8 Same as Model Al C3 LS12 Same as Model Al C4 LS8 Same as Model Al D1 CGCC Same as Model Al Refer to Section 8.1 for additional details 1-9
SECTION 2 l
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2.0 DESCRIPTION
OF THE ENERGY ECONOMIC DATA BASE 2.1 PURPOSE, CONTENTS AND USE OF THE DATA BASE The economics of the nuclear option have been examined for years and many comparisons have been attempted. Some investigators have demonstrated that the nuclear option can compete with alternatives, while others have concluded the opposite. It is difficult to draw broad :onclusions about the. nuclear option and its alternatives from these studies, because it is of ten not clear under what circumstances the nuclear option is or is not competitive with alternatives. This uncertainty occurs because of conflicting claims, low visibility of study groundrules and assumptions, and differences or inconsis-tencies in what is included in the costs of the options that are compared. In order to assess the economic viability of the nuclear option in a reason-( S able manner, relative energy costs must be evaluated for a variety of nuclear and alternative power generating stations on a common and consistent basis. The Energy Economic Data Base (EEDB) Program meets this objective for nuclear and comparison coal alternatives. i The EEDB contains capital, fuel and operating and maintenance costs for different types of nuclear and comparison coal-fired power generating stations. Each cost estimate is based upon a detailed technical model which includes system design descriptions for over 400 systems, a detailed equipment list containing over 1250 mini-specifications and up to 10,000 lines of commodity, material and equipment quantities, labor hours and costs. The technical
'models are based on actual power plant designs and over 50 years of power plant design and construction experience. Site related factors are normalized by locating each technical model on a common hypothetical "Middletown" 2-1 h
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site, for which there is a detailed written, geological and environmental description (refer to Appendices Al and A2). Costs are given in constant (inflation-free) dollars of the date of the estimate. The EEDB user may make credible cost comparisons among alterna-tives based on the data as presented. Additionally, the baseline data may be used to develop comparable and reliable life cycle costs and cash flow requirements, through the uniform application of the required factors, such I 1 as contingency and allowance for funds used during construction. The EEDB approach promotes greater understanding and acceptance of comparisons, because all components of " bottom-line" numbers in the different estimates are readily identified. Consequently, differences or similiarities in com-( pared alternatives may be identified as controllable or uncontrollable costs, as inflationary costs or as discretionary costs. The depth of detail fur-nished is the key to providing the necessary consistency to allow comparison of commodities and components among diverse alternatives and, thereby, to determine the reasons for cost differences. 2.2 SELECTION OF TECHNICAL MODELS FOR THE DATA BASE Selection of power generating station types and associated fuel cycles to be included in the EEDB is based on the USDOE objectives discussed in Section 1 and the availability of existinc cost information. Nuclear power generating station types are selected to provide a cross-section of current and developing ' technology experience in the United States. Current technology experience is represented by light water reactor (LWR) power generating stations of intermediate capacity. Converters and breeders 2-2
are included to represent high potential developing technologies. Cross Section of Nuclear Technology Experience (See Table 1-1) Current Technology Developing Technology Light Water Reactors Converters Breeder . PWR HTGR LMFBR BWR PHWR
- Other plant types are selected to provide alternatives for comparison with the nuclear plant types. Current technology experience is represented by coal-fired power generating stations of appropriate size, including plants which burn either high sulfur or low sulfur coals. A coal gasification com-bined cycle plant is included to provide a basis for comparison to developing technologies.
k Cross Section of Comparison Technology Experience (See Table 1-2) Current Developing Technologv Technology High Sulfur Coal Low Sulfur Coal 800 MWe 800 MWe Coal Gasification Combined Cycle 1200 MWe 1200 MWe . Fuel cycles are selected for the nuclear power generating stations that represent current technology and policies. The LWR's and converters are provided with " throwaway" fuel cycles, while the breeders are provided with plutonium recycle fuel cycles. 2.3 COMPOSITION OF THE DATA BASE The data base is composed of the following five elements for each of the power generating stations listed in Tables 1-1 and 1-2: 2-3
- a. A Technical (Conceptual Design) Model
- b. A Capital Cost Model ,
- c. A Fuel Cycle Cost Model
- d. An Operating and Maintenance Cost Model
- e. A Back-up Data File 2.3.1 Technical Models The Technical Models are detailed conceptual descriptions of the plants in the data base, and appear in the Base Data Studies and Reports referenced in Table 1-3. They provide the basis for the level of detail found in the capital cost models and, consequently, to the degree of accuracy for the comparative results reported in the data base.
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- a. Heat Cycle Diagram
- b. Major System Flow Diagrams
- c. Electrical One Line Diagram -
- d. Plot Plan
- e. Major Building and Equipment Arrangement Drawings
- f. Detailed Equipment List Revision of the detailed equipment lists is the means for updating the tech-nical models in the data base. The diagrams, plans and drawings in the base data studies and reports serve as resources for support of the equipment list revisions.
2.3.1.1 Ecuipment Lists The detailed equipment lists are developed from PEGASUS (Power Plant Economic 2-4
Generator and Scale-Up System), a proprietary computer program of U,nited Engineers & Constructors Inc. of Philadelphia, PA. PEGASUS utilizes an expanded Code-of-Accounts derived from " Guide for Economic Evaluation of Nuclear Reactor Plant Design," USAEC Report NUS-531 (1969), developed for the U.S. Atomic Energy Commission (now Department of Energy and Nuclear Regulatory Commission) by NUS Corporation of Rockville, MD. The PEGASUS program tabulates engineering data, which describes the equipment and material used in the plant design and their quantities. This is accom-plished through use of a mini-specification.of standardized format developed for each account in the equipment listing. Mini-specifications are not used for material (e.g., concrete) listings. Samples of two mini-specifications, f one for a circulating water pump and its motor and one for medium voltage
'(' electrical switchgear, are provided in Tables 2-1 and 2-2.
Additionally, the PEGASUS program contains unit cost data for material and equipment and associated labor data, such as craft manhours, composite craft I mixes and craft labor rates. PEGASUS also has the capability of developing technical models for various capacity plants by scaling a known plant capacity model, in accordance with the procedure described in Section 4. I PEGASUS, as the basic Technical Model in the Data Base, directly supports the ( Capital Cost Models as discussed in Section 2.3.2. l 1 2.3.1.2 Maturity of Technical Models The structure of the expanded cost Code-of-Accounts, used in the Equipment List, ! permits the degree of detail entered in the model to vary according to the amount of information that is available. Consequently, nature models, where 2-5
considerable information is available, are detailed to the "nine-digit" level, whereas less mature models are detailed to the "three-digit" or summary level. Table 2'-3 shows the significance of the various levels of detail, as related to the information provided. Nuclear power generating station models detailed to the "nine-digit" level, contain approximately 10,000 lines of information, while comparison power generating station models detailed to the same level, contain approximately 5,000 lines of information. The difference is primarily due to the greater complexity and redundancy of systems in the nuclear power generating station models. The current update of the EEDB contains technical models of varying degrees of detail. In Tables 1-1 and 1-2, the "A" and "C" models are detailed f to the "five-digit" to "nine-digit" levels, and the "B" and "D" models to the (
"three-digit" or summary level.
2.3.2 Capital Cost Models The Capital Cost Models for the plants in the data base.are developed from CONCICE (Conceptual C,onstruction Investment C,ost Estimate), a proprietary computer program of United Engineers & Constructors Inc. of Philadelphia, PA. The CONCICE program utilizes extensive technical and unit cost data from PEGASUS, by means of an interface program, to develop capital cost models. Consequently, the more detailed the Technical Mcdel in PEGASUS, the more detailed the Capital Cost Model developed by CONCICE can be. CONCICE is similar to and compatible with the U.S. Department of Energy C'ONCEPT code, as illustrated in ; fable 2-4. CONCICE contains information for each account in the Technical Model in terms of Factory Equipment, Site Labor and Site Material costs. It categorizes these accounts into Direct and Indirect capital costs, and sums them into a 2-6
total Base Construction Cost. Table 2-5 illustrates a typical C0NCICE Capital Cost Model for a Boiling Water Reactor Plant at the "two-digit" level. When required, the CONCICE computer program can provide a number of economic analyses of the cost models in the dat'a base, as follows:
- a. Comparative Economics
- b. Cost Projections
- c. Cost Analysis
- d. Cash Flow Analysis
- e. Trend Analysis
- f. Parametric Analysis 2.3.3 Fuel Cost Models Two different fuel cost models are utilized in the EEDB; the Nuclear Fuel Cycle Cost Model and the Coal Fuel Cost Model. The two models are structured differently, as follows:
- a. The nuclear fuel cycle model covers a complete reactor fuel cycle from mining of uranium ore through reprocessing of irradiated fuel, recovery of uranium, plutonium or thorium from spent fuel and shipment of high level waste to permanent storage,
- b. The coal fuel model includes only the mining of coal and trans-portation to its point of use. Storage and disposal of wastes are accounted for in the coal plant Operating & Maintenance Cost models.
2.3.3.1 Nuclear Fuels Nuclear fuel cycle costs are developed from the EEDB Approximation Factors Method (AFM). The AFM generally follows the methodology presented in " Guide for i Economic Evaluation of Nuclear Reactor Plant Designs," USAEC Report NUS-531 (1969) and " Fuel Cycle Cost Estimates for LWR, HTCR, CANDU Type EWR, LMFBR and GCFR", Initial Update Report NUS-3190 (1978). 2-7 I _ _ _ _ _
/
Nuclear fuel cycle costs for the EEDB Initial Update are based on cost anslyses performed by NUS Corporation (NUS) of Rockville, Maryland, under contract to United Engineers. The current update of the nuclear fuel cycle costs extends the work done in the initial and succeeding updates by following a similar methodology, but utilizing data from more recent reports. Recent market costs are~ taken from " Fuel Cycle Cost Projections", NUREG/CR-1041 published by Bate 11e Pacific Northwest Laboratory in December, 1979. Mass flow data are taken from " Nuclear Proliferation and Civilian Nuclear Power Report of the Non-Proliferation Alternative Systems Assessment Program (NASAP)", DOE /NE-0001/9, Volume IX, published by USDOE in June, 1980. 5 The utility economics of using nuclear fuel for the generation of electricity is simulated by:
- a. Providing Direct costs for materials, processes, and services as input,
- b. Estimating Indirect costs by an " interest rate" approach which is derivable from a discounted cash flow approach.
The input values for direct costs are selected and adjustments are made to reflect the time-value of money spent before and after utilization of the fuel in the reactor. The net direct costs are amortized in proportion to the amount of energy generated over a fixed calendar time (usually one year). Indirect costs are treated like an interest cost on borrowed money. Such an interest rate may be considered as the composite cost of money, including such parameters as borrowing costs and the rate of return on equity and tax'es. 2-8
The fuel cycle costs, both direct and indirect, are levelized over a 30-year period using an appropriate discount rate, as stated in the groundrules. The input nuclear fuel cost components are given with appropriate account designations as unit costs by calendar years, shown typically in Table 2-6. The output nuclear fuel costs are given as 30-year levelized costs in cost per energy unit for appropriate account designations, shown typically in Table 2-7. 2.3.3.2 Coal The costs of coal as fuel are based on a number of complicating factors which strongly affect the costs to the user. The preponderant coal cost factors are mine-mouth costs and transportation costs. t k The quality of coal, as regards both heating value and sulfur content, in-fluences the cost of use, but is so dependent on site specific factors that generalizations are not attempted. Typical costs for high and low sulfur content coals shipped to the representative "Middletown" site are derived, with the extraction and the transportation costs given explicity. The reagent cost for desulfurization products, are traditionally charged against operation and maintenance rather than attributed to the fuel costs. In the EEDB, these costs are included in the appropriate Operating and Maintenance ( Cost Models. 2.3.4 Operating and Maintenance Cost Models The Operating and Maintenance (0&M) Cost Models in the EEDB are based on the Oak Ridge National Laboratory report ORNL/TM-6467, "A Procedure for l Estimating Nonfuel Operation and Maintenance Costs for Large Steam-Electric Power 2-9 l
Plants." The cost estimating procedure involves the application of empirical functions that represent historical cost experience plus new factors arising from regulatory and economic considerations. Oak Ridge National Laboratory (ORNL) provides O&M data in the form of staf fing and material requirements for each of the EEDB technical models. The 0&M costs are generated by OMCOST, a digital computer program developed by ORNL, based on the procedures given in report ORNL/TM-6467. Although the intent is not to reflect specific operating philosophy or experi-ence, data from published and private sources are examihed to insure that the reference plants are realistic. Factors considered in formulating guidelines are plant design, staff training, personnel motivation, outage planning, regulatory provisions, operating load, hours of service, and number of out-ages and startups. Tables 2-8 and 2-9 are typical outputs from the OMCOST program with a standard set of accounts for nuclear and fossil power generating stations. 1 2.3.5 EEDB Back-up Data File The Back-up Data File contains all of the information and documentation acquired or developed, including the documents listed in Tables 1-3 through 1-5, for the successive updates to produce the data contained in the Data Base Reports. In the interest of keeping the EEDB reports to a manageable size, the following information is omitted from the reports, but is included in the Back-up Data File:
- a. Technical Data, including the detailed Equipment Lists, other than the Base Parameter Summaries.
l 2-10
. . _ _ _._. ._. -~~
- b. Capital Cost Data below the three-digit level,
- c. Inflated Operating and Maintenance Cost Data.
- d. Resource Data, including all of the documents listed in Tables 1-3, 1-4, and 1-5 and in Section 8.1.
Questions concerning information contained in the Back-up Data File may be addressed to: United Engineers & Constructors Inc. 30 South 17th Street P.O. Box 8223 Philadelphia, PA 19101 Attention: R. E. Allen EEDB Program Project Manager
! (215) 422-3734 2.4 APPROACH TO PRESENTATION OF COST DATA The capital, fuel and operating and maintenance costs developed and presented in the EEDB reports are in constant January 1 dollars of the year covered by the report. The objective is to present comparable baseline costs in the three cost areas of interest that are unencumbered by controversial factors, such as the effects of future inflation, and non-uniform factors, such as costs arising from owner options or utility system configuration. The user of this data may add whatever factors may be desired to the base costs, in order to make reliable comparisons based on unique requirements. This approach promotes greater understanding and acceptance of disputed comparisons, because all components of " bottom-line" numbers are readily identified. Consequently, differences or similarities in compared alternatives may be identified as base costs, inflationary costs or preferential costs. Where comparisons are l
made of the capital costs of the various alternatives, unit costs, based on tabulated quantities of co=modities, can be compared as credibility checks. l 2-11' r.- - - . , - . . . _ _ - . - . -
2.4.1 Items Not Included in Capital Cost Data Preferential and utility system related cost components that are NOT included in the capital cost data presented in this report are tabulated in Table 2-10. Many of these non-uniform cost factors are dependent on the choice of the - owner rather than on the intrinsic characteristics of the plant. These cost factors, especially those which are related to the time-value of money, are ~ significant fractions of the total costs involved. Because of the variability of these cost factors, they are deliberately excluded from the costs pre-sented herein. The user of the EEDB may include these costs by making a consistent application 4 of the necessary adders and multiplying factors to the Base Construction Costs for the alternatives of interest. Information related to owner's costs appear ( in NUREG-0248, " Commercial Electric Power Cost Studies - Total Generating Costs: Coal and Nuclear Plants." 2.4.2 Inflation, Escalation and Discount Rates Certain time-value terms are used in the EEDB Program. These terms are defined as follows in accordance with their usage in the EEDB: Inflation Rate (i) - the rate at which the average price of all goods and services in the economy increases. Escalation Rate (e) - the rate at which the price of a commodity or service increases, independent of any changes due to inflation. Real Interest Rate (r) - the rate above inflation that is required to attract investment. 2-12
Revised 10/06/81 Discount Rate (d) - the opportunity cost of capital seen by a firm when used in finding the present value of a series of future cash flows, where d = (1 + 1) (1 + r) - 1. Levelized Cost (CL ) - a constant annual cost of a commodity or service over the lifetime of a facility, in which the commodity or service is utilized, whose stream of payments has a present
' value equal to the..present value of the actual or predicted annual ~
costs (which may be variable) of the commodity or service ove'r that period. The capital, fuel and operating and maintenance costs are developed on an inflation-free (constant dollar) basis for the EEDB.- Therefore, the inflation rate is zero (i = 0) for these cost components. The scarcity of material is negligible for capital and operating and maintenance costs, but may be significant for the cost of coal and nuclear fuels. Therefore, escalation for scarcity is considered to be zero (e = 0) for capital and operating and maintenance costs, but equal to or greater than zero (e 2 0) for coal and nuclear fuel costs. 2.4.3 Total Generating Costs and Life Cvele costs The base capital, fuel and operating and maintenance costs in this report cannot be summed directly to obtain Total Generating and Life Cycle Costs. A simple summation of the capital, fuel, and operating and maintenance-constant dollar unit costs can only give cost data which are useful for comparison of the relative costs of alternatives. These totals are n't intended to represent the Total Generating or Life Cycle Costs. 2-13
1 To prepare Total Generating and. Life Cycle Costs from data in this report, the excluded items described in paragraph 2.4.1 and the effects of inflation i discussed in paragraph 2.4.2, must be combined with the base costs presented 4 herein, in accordance with consistent and documented groundrules and assump-tions. Preparation of Total Generating Costs and Life Cycle Costs is beyond the scope of the EEDB Program. l 4 a ( i 4 o }
=
2-14 J
- - , - , , - . , , . , , . . , - , . _ . - . . - - . , _ , . . - - , - - . . . . - . . = - - - , _ , - --- - ,,
<m TABLE 2-1 ENERGY ECONOMIC DATA BASE MINI-SPECIFICATION - CIRCULATING WATER PUMP PROG. CM-791 *PEGO30* O E QU I PME N T LIST - REPORT t ,
o MODEL 148 - 1139 MwE/3425 MWT PWR - 2.5 IN HG AV - MIDDLETOWN. USA ACCOUNT DESCRIPTION NUMBER ITEM 262.1291 CIRCULATING WATER PUMPeMTR 262.12ft1 CIRC WATER PUMP QUANTITY 4 X 25 PCT TYPE MlXED FLOW ta ORIENTATION VERTICAL Ln FLOW RATE SPEED 147.500 GPM 320 RPM TDH 105 FT BHP 4.414 HP NPSH 30 Fi EFFICIENCY 88.6 PCT DESIGN PRESS 150 PSIA DESIGN TEMP 900 F MATERIAL NI-RESIST COL. AND BOWL S.S. IMPELLER SAFETY CLASS NNS SEISMIC CAT. NONE DESIGN CODE 262.121i2 CIRC WATER PUMP MOTOR OUANTITY - 4 X 25 PCT TYPE - AC INDUCTION HORSEPOWER 5.000 HP SPEED 320 RPM VOLTAGE 13.2 KV. 3 PHASE 60 HZ
._ _ _ _ _ _ _ _ m r
f TABI.E 2-2 l ENERGY ECONOMIC DATA BASE MINI-SPECIFICATION - CIRCULATING WATER PUMP SWITCilCEAR PROG. CM-781 *PEGO30* (Cost Basis 01/80)
- EQUIPMENT LIST - REPORI t j MODEL 14R - 1939 MWE/3425 MWT PWR - 2.5 IN HG AV - MIOOLETOWN USA ACCOUNT DESCRIPTION NUMBER gggg 1 241.2139 NON-CLASS 1E 4.16 KV TWO 4.16 KV BUSES CONSISTING OF INDOOR METAL CLAO SWITCHGEAR NOMINAL VOLTAGE - 5 KV NOMINAL MVA CLASS . 350 MVA CONTINUOUS CURRENT -
INCOMING LINE ACB 1200 A
. FEEDER ACR 1200 A l BUS 1200 A RATED SHURI CIRCUIT CURRENT: 41000 A.
RMSe4.76 KV N INTERRUPTING TIME - 5 CYCLES j [ m CLOSING AND LATCHING CAPABILITY 78000 A. RMS OUANIIIIES - INCOMING LINE 4 FEEOER
- 17 SPACE . 2 PT COMP *iS 2 EACH BUS IS COMPLFTE WITH METERING.
PROTECTIVE RELAVING. AND CONTROL LOGIC
+
8
% '.p s,
1
TABLE 2-3 ENERGY ECONOMIC DATA BASE CODE OF ACCOUNTS EXAMPLE OF IEVELS OF DETAIL No. of No. of Digits Account Name of Account Function / Level 2 26 Main Condenser Heat Rejection Name/ Account System 3 262 Mechanical Equipment Name/Sub-Account 4 262.1 Heat Rejection System Name/ System 5 262.15 Main Cooling Twoer Make-up and Name/Sub-System Blowdown System C 6 262.151 Make-up Water System Name/Sub-Sub-System 7 262.1511 Rotating Machinery Class / Equipment
, Category t 8 262.15111 Make-up Pump and Motor Cleas/ Equipment Sub-Category 9 262.151111 Make-up Pump Class / Component
< Note: The final account, in this case the 9th digit, is the line item where specific equip-
' ment and material technical and/or cost information is recorded. At levels above the 9th digit,< cost information is collected from lower level accounts and recorded as the surunation of the lower level accounts. Depending on the complexity of the. system, or the level of
' detail available, the final account may appear at any digit level from the 5th digit to the 9th digit.
- i n
'/
4 TABLE 2-4 4 ENERCY ECONOMIC DATA BASE RELATIONSl!IP OF " CONCEPT" TO "CONCICE" s
" CONCEPT" PROGRAM EVOLUTION DATA BASE INCORPdRATED INTO "CONCICE" PROGRAM Year of Publication Name 1971 CONCEPT I EXPERIMENTAL VERSION 1973 CONCEPT II WASil 1230 1974 CONCEPT III -
WASil 1345 [ (Unpublished) ' c. 1975 CONCEPT IV WASH 1345 MODIFIED 1978/1979 CONCEPT V NUREG 0241 TliROUCll 0248 AND EEDB-1 (1978) 1981 CONCEPT V EEDB-II (1979) AND EEDB-III (1980) (Unpublished) Notes: 1. The numbers used in CONCEPT II are those developed in WASil 1230, and similarly for each succeeding CONCEPT.
- 2. CONCEPT V cost models are revised annually as EEDB updates are completed and released.
~
TABLE 2-5 ENERGY ECONOMIC DATA BASE (EEDB) UNITED ENGINEERS & CONSTRUCTORS INC. EXAMPLE OF WO-DIGIT LEVEL COST ESTIMATE 1190 MWe Boiling Water Reactor SLRD1ARY PACF* - 1 PLANT CODE COST BASIS 208 01/80 FACTORY SITE SITE SITE TOTAL ACCT NO ACCOUNT DESCRIPTION EQUIP. COSTS LABOR HOURS LABOR COST MATERIAL COST COSTS 20 LANE AND LAND RIGHTS 2.694.000 2.614.000 21 . 5TRUCTURES & IMPROVEMENTS 5.948.078 8622946 Mt i19.192.472 62.838.649 187.979,199 22 REACTOR PLANT EQUIPMENT 842.955.969 2947200 24 45,524.169 12.239,234 200.719.364 23 TURBINE PLANT E'OUIPMENT 129.929.083 2650597 mt 40.221.462 7.964.066 178.114,681 g 24 ELECTRIC PLANT EOUIPMENT 22.966,220 2128879 Mt 29.751,7p? 9.356,756 62,074.773 e g 25 . MISCELLANEOUS PLANT EOUIPT 9.556.191 483240 WI 7.405.770 l.563.436 18.525.317 26 MAIN COND HEAT REJECT SYS 20.775,764 487365 Mt 7.039.313 f.769.782 29,584,859 TOTAL DIRECT COSTS 332.131.225 17321227 El 249.134.975 98.345.923 679.612,923 99 CONSTRUCTION SERVICES 49.907.710 2851800 mi 41.025.600 35,453.000 126.386.310 92 It0ME OFFICE ENGRO.& SERVICE 156.465.100 156.465,100 93 FIELD OFFICE ENGRG& SERVICE 70.613,400 2.744,500 73,357.900 TOTAL INDIRECT COSTS 276,986,210 2851800 24 49.025.600 38.197.500 356.209,310 TOTAL BASE COST 609.117,435 20073027 MH 290.860,575 136.543.423 1.035.821.433 a to
.m Effective Date: Januar d ,_1980_
TARLE 2-6 (1) Systes : PWM-US(LE)~/U-T Start Up ~Ia'n ua ry_l, l yd 7 ENERCY f.tDNOMIC DATA SASE INPUT NUCLEAR FUEL COST COMPONENTS No Escalation Constant January 1,1980 Dollars SUP9tARY OF INPUT QUANTITIES SY CALENDAR YEAR (FIVE YEAR PERIODS) Accoun t No. Accoun t Description Units 1987 3992 1997 2fm2 20G7 2012 2017
.10 Initital Fuel Loaded $/KgH
.11 Uranium Supply $/KgU
.111 U03 8 Supply
.112 $/lb U 038 43 43 44.1 53.0 64.4 UF6 Conversion Services $/KgU as UF6 78.4 88.2
.313 5.7 5.7 5.7 5.7 5.7 5.7 Enrichment Services $/SWU 99 5.7
.114 Depleted U Supply 105.6 116.6 123.2 124.3 123.2
$/KAU 122.1
.12 Flutonium Supply Parity value
.13 U-2 33 Supply Parity value
.14 Thorium Supply $/KgH
.20 Fabrication $/KgH 132 134.2 134.2 134.2 133.1
.21 Core Fabrication $/KgH 132 135.3 w .22 Axial Blanket Fabrication $/KgH
/.,
.2) Radial Blanket Fabrication $/KgM
.30 Shipping to Temporary Storage $/KgH
.40 Temporary Storage $/KgH
.50 Shipping to Repository $/KgH
.60 26.4 24.2 22 22 19.3 19.8 Disposal of Spent Fuel $/KgH I40.8 17.6 140.8 140.8 140.8 140.0 11.0.3 140.8 3
(1) See Table 6-13 for System Designation
_ . - . - . - _ -- - _ _ . _. _ . _ -- ___.m . . . ___ _ . . _ _ . 1.___-. __ . _ ._ - _ _ - 4 TABLE 2-7 Effective Date: Januar n 1980 (1) System + PWR-US LrJ[$T Start Up : January l l987 ENERCY ECONOMIC DATA BASE OUTPUT NUCI. EAR FUEL COST COMPONENTS No Escalation 4 Constant January 1.1980 fullars ) j OUTPUT QUANTITIES, 30- YEAR LEVELI2ED $/MBtu I
' Direct Indirect Total Account M . Account Description Cost Cost Cost *
.00 Total .66 0.06 0.20
.30 Initial Fuel loaded
.11 Uranium Supply I,
.111 U30g Supply 0.33
! .312 0.61 0.36 UF6 Conversion Services 0.01 0.00 } .113 Enrichment Service
- 0.01
.314 Depleted U Supply 0.21 0.23
.32 Plutonium Supply
.13 U-233 Supply #
.14 Thorium Supply
.20 Fabrication 0.06 0.M 0.06
% .21 rare Fabrication b
~
.22 Axial Blanket Fabrication
{ .23 Radial Blanket Fabrication L i i
.30 Shipping to Temporary Storage
.40 Temporary Storage l .50 Shipping to Repository 0.01 i
.60 Disposal of Spent Fuel (0.00) 0.01 0.04 (0.01) 0.03 4
1 (1) See Table 6-13 for System Designation. i I l I
TABLI: 2-8 ENERGY ECONOMIC DATA BASE SLM'.ARY OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR (PWR)' NUCLEAR PLANT
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR BASE-LOAD STEAM ELECTRIC POWER PLANTS IN 1980.0 PLANT TYPE IS PWR w!TH EVAPORATIVE COOLING TOWERS NUMBER OF UNITS PER STATION 1 THERMAL INPUT PER UNIT IS 3412. MwT PLANT NET HEAT RATE 10221. PLANT NET EFFICIENCY. PERCENT 33.38 EACH UNIT IS 1139. WWE NET RATING ANNUAL NET GENERATION. MILLION KWH 6989. WITH A PLANT FACTOR OF O.70 STAFF. $1000/YR 9377. (331 PERSONS AT $28328.) MAINTENANCE MATERIAL. $1000/vR 3201. FIXE 0 3201 VARIABLE O. SUPPLIES AND EXPENSES. $1000/YR 5589. FIXE 0 5082. VARIABLE 507. INSUR ANCE AND FEES. $1000/YR 494 COMM. LIAB. INS. 344
\ GOV. LIA8. INS. 22.
RETROSPECTIVE PREM!UM 7 INSPECTION FEES & EXPENSES 121 ADMIN. ANO GENERAL. $1000/YR 2649. TOTAL FIXED COSTS. $1000/YR 20802. TOTAL VARIABLE COSTS. $1000/YR $07 TOTAL ANNUAL 0 & M COSTS. $1000/YR 21310. FIXEO UNIT 0 & M COSTS. MILLS /KWH(E) 2.98 VARIABLE UNIT O & M COSTS. MILLS /KwH(E) 0.07 TOTAL UNIT 0&M COSTS. M!LLS/xwH(E) 3.05 3 i 2-22
TABLE 2-9 ( ENERGY ECONOMIC DATA BASE SUMM.ARY OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR'(HS12) COAL PLANT
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR BASE-LOAD STEAM-ELECTRIC P0mER PLANTS IN 1980.0 PLANT TYPE IS COAL WITH EVAPORATIVE COOLING TOWERS NUWBER OF UNITS PER STATION 1 WITH FGO SYSTEMS THERMAL INPUT PER UNIT IS 3298. MWT PLANT NET HEAT RATE 9134 PLANT NET EFFICIENCY. PERCENT 37.36 EACH UNIT IS 1232. WWE NET RATING ANNUAL NET GENERATION. MILLION KWH 7560. + WITH A PLANT FACTOR OF O.70 STAFF. StOOO/YR 7018. (259 PERSONS AT S27096.)
~
MAINTENANCE MATERIAL. 51000/YR 2964 Flxt0 2295. VARIABLE 669. SUPPLIES AND EXPENSES. 51000/YR 15579. FIAE0 . 1694 VAR. - PLANT 457. *
- ASH & FGO SLUDGE 13428.
s ADMIN. AND GENERAL. StOOO/YR 1101. TOTAL FlxED COSTS. 11000/YR 12107. TOTAL VARIABLE COSTS StOOO/YR 14555. TOTAL ANNUAL 0 & M COSTS. StOOO/YR 26662. FIXE 0 UNIT 0 & M COSTS. MILLS /KWHIE) 1.60 VARIABLE UNIT 0 & M COSTS. MILLS /KWH(E) 1.93 TOT AL UNIT 0 & M COSTS. MILLS /KWH(E ) 3.53 l HEATING VALUE OF COAL. BTU /LE 11026. COAL BURNE0, TONS / YEAR 3131333. PERCENT ASH 11.60 COST OF ASH O!SPOSAL. S/ TON 4.84 PERCENT SULFUR 3.50 SULFUR (ORIGINAL). TONS /YR 109597
- TONS LIMESTONE PER TON SULFUR 4.00 TONS / YEAR LIMESTONE 438387.
COST OF LIMESTONE. S/ TON 12.10 ) COST Of SLUDGE O!SPOSAL. S/ORY TON 14.52 i 2-23 i
TABLE 2-10 ENERGY ECONOMIC DATA BASE COST BASES FOR POWER PLANT CAPITAL COST ESTIMATES l Include: Exclude: Site Characteristics - Middletown, USA Owner's Cost (Consultants, Site Selection, etc.) Code of Accounts - NUS-531 (Expanded) Fees and Permits (Federal, State, Local) Detailed Statement of Bases: State and Local Taxes i i Cost Date Allowance for Funds Used During Construction .; 'f Applicable Regulations Escalation U Applicable Codes & Standards Contingency
- Plant Design Description Owner's Discretionary Items Switchyard and Transmission Costs Generator Step-up Transformer Waste Disposal Costs Spare Parts Initial Fuel Supply Nuclear Liability and Other Insurance Special Coolant Initial Inventory (e.g. helium for IITCR, heavy water for PHWR and sodium for LMFBR) e e
k SECTION 3 3.0 ASSUMPTIONS AND GROUND-RULES FOR THE FOURTH COST UPDATE 3.1 EFFECTIVE DATE OF THE EEDB FOURTil UPDATE
- The effective (cost and regulatory basis) date of this report is January 1, 1981.
3.2 COST PARAMETER GROUND-RULES 3.2.1 Base costs Base costs are developed in constant January 1,1981 dollars, and are pre-sented in the following forms: , a. Capital Costs e Present Costs ($) = Direct plus Indirect Costs (1) Present Costs ($) (2) ; e Capacity Costs ($/kWe) " (CAP) k e Electric Energy Costs (m/kWh) = ( resent Costs ($))(1000 mills /$) 3 (CAP)(CF)(365 d/y)(24 h/d)
- FCR (3)
- b. Fuel Costs e Thermal Energy Costs (TEC) (c/M3tu) e Electric Energy Costs (m/kWh) = (TEC)(HR)(10 mills /c)/(106) 4)
- c. Operating and Maintenance Costs e Present Annual Costs (PAC) ($/y) e Electric Energy Costs (m/kWh) = -
LF (5) (CAP) CF)(3 d y) 24 ti/d) 0 i 3-1
- t. - _ . _ _ _ _ ___,-__. __ _ _ -__ __-- _____ _ _ -. _ _ _ . _ . - _ . - - - -- _ _ - - -. -
/ whdre:
CAP = Net Electrical Capacity in kWe* - (Net Power' to Generator Step-Up Transformer) CF = Capacity Factor in %+ FCR = Fixed Charge Rate in %/y+ HR = Net Station Heat Rate in Btu /kWh*
+
LF = Levelization Factor
- These values are summarized for each model in Tables 4-1 and 4-2.
+ These values are given in Section 3.2.2.
3.2.2 Cost Parameters ( Cost parameters used are as follows: Capacity Factor 70.0% (assumed) Fixed Charge Rate 8.7%/y( } Inflation Rate i = 0%/y s Escalation Rate e = 0%/y( ) Return on Investment ROI = 3.5%/y( Discount Rate d = 3.5%/y(2) Levelization Period (Fuel Cycle and O&M) ^ 30 years (assumed) Levelization Factor (0&M) 1( Notes:
- 1. Costs reported in this update are derived on an inflation-free basis (i = 0%/y, c = 0%/y, d = 3.5%/y) as discussed in Section 2.4.2.
l
- 2. A discussion of the development of these eccnomic parameters are
, found in Appendix B. l 3. The escalation rate is equal to or greater than zero for fuels, as ! discussed in Section 2.4.2.
- 4. A discussion of the development of this economic parameter may be found in Section 7.
3-2 l t L
3.2.3 Commercial Operation Dates A commercial operation date is selected for each plant model to provide a basis { for selecting fuel costs for the fuel cost models. This is necessary because fuel costs may escalate due to scarcity, as discussed in Section 2.4.2. Commercial operation. dates are assumed to be January 1 of the year indicated below. Case I represents a sequential scenario with start-up of plants occur-ring in the year when the technology is assumed to be ready. Case II is a scenario for the earliest year when all of the technolo'gies are assumed to i
- be ready.
EEDB J , Model Model Commercial Operation Dates
; Number Type Case I Case II Al BWR 1981/1987 2001 i
A2 HTGR-SC 1995 2001 A3 PWR 1981/1987 2001 ] A4 PHWR 1995 2001 B1 HTCR-PS 2001 2001 A5 LMFBR 2001 2001 Cl HS12 1981/1987 2001 C2 HS8 1981'/1987 2001 C3 LS12 1981/1987 2001 l C4 LS8 1981/1987 2001 D1 CGCC 1987 2001 4 The BWRs and PWRs are the only full scale nuclear plants currently operating on a commercial basis in the United States. For this reason, the costs of i 3-3 i
the Light Water Reactors are included for the earliest study date, January 1, 1981. Fo'ur of the coal-fired generating stations are currently operational and the costs for these are also given for January 1, 19'SI. It is assumed that the technology supporting the other nuclear plant types will mature at later dates. Data are also provided for the Light Water Reactors and the coal-fired plants in 1987, because it is assumed that the CGCC coal plant option will be operational by that date. Costs projected to 2001 are given for all of the nuclear and coal comparison plants. Comparisons of alternatives having significantly different capital and fuel costs need to be considered in terms of common startup dates. This is especial-ly important if low fuel costs of a given alternative tend to of fset h.gh f capital costs, because capital cost escalation is zero on a constant dollar \ basis, while fuel cost escalation is driven by scarcity. 3.3 TECHNICAL MODEL GROUND-RULES 3.3.1 General Ground-Rules General assumptions and ground-rules for the Technical Models in the Base Data Studies and Reports listed in Table 1-3, and in the EEDB Initial and following updates, are given below. Except for the cost and regulation effective date cf January 1,1981, the same assumptions and ground-rules apply to the Fourth Update of the EEDB.
- a. Cost data is based on prices effective as of January 1,1981.
- b. A full complement of licensing and design criteria, circa January 1, 1981, are utilized. Safety classifications, seismic categories and design codes for major structures and equipment are given in the Base Data Studies and Reports listed in Table 1-3.
- c. The detailed technical models are developed for a single unit with sufficient land area to accommodate an identical second unit.
3-4
I
- d. The design of the main heat rejection systems are based upon the use of mechanical draft vet cooling towers, and natural draft cooling towers (CGCC only). 11e nuclear plant ultimate heat sinks are based on mechanical draft wet cooling towers and mechanical draft dry cooling towers (HTGR only).
- e. Each conceptual design utilizes two independent offsite sources of power; one at 500 kV and the other at 230 kV.
- f. The design life for nuclear power generating stations (NPGS) is 40 years and for fossil power generating stations (FPGS) is 30 years; however, useful operating life is considered as 30 years for each.
! g. Generating stations are base-loaded during the first part of their design life.
3.3.2 Specific Ground-Rules Specific assumptions and ground-rules for each of the technical models of the Base Data Studies and Reports listed in Table 1-3 and for the EEDB Initial and following updates are given below. The same assumptions and, ground-rules apply to the Fourth Update of the EEDB, with some modifications. Details of these modifications are given in Section 5.4. 3.3.2.1 Boiline Water Reactor (BWR) NPGS - Base Data Study
- a. Plant design is based on the General Electric Technical Reference Plant Design, the General Electric Standard Safety Analysis Report (GESSAR), the General Electric 238 Inch Reactor Pressure Vessel (RPV) Nuclear Island Study Arrangements, and United Engineers' experience.
The reactor plant design is based upon the General b. Electric documents listed in paragraph a. above. 3.3.2.2 High Temperature Gas Cooled Reactor - Steam Cycle (HTGR-SC) NPGS - Base Data Study
- a. Plant design is based on "The HTGR for Electric Power 3-5
I Generation - Design and Cost Evaluation" study, September, 1980, performed by United Engineers for Gas Cooled Reactor Associates.
- b. Reactor plant design is based on a 2240 MWe, 858 MWe, 10000F, 2400 psig HTGR Nuclear Steam Supply System, developed by General Atomic Company for the study
- listed in paragraph a. above,
- c. Helium inventory is not included.
- d. This HTGR NPGS is located on a site in Eastern Pennsylvania.
The EEDB incorporates the necessary modifications to meet the ground-rules that the HTGR NPGS is located on the "Middletown" site. 3.3.2.3 Pressurized Water Reactor (PWR) NPGS - Base Data Study
- a. Plant design is based upon principal technical features corresponding to the Public Service Ccmpany of New Hamp-shire Seabrock Station, circa, July, 1976.
- b. The reactor plant design is based upon the Westinghouse
( Reference Safety Analysis Report (RESAR-3S). 3.3.2.4 Pressurized Heavy Water Reactor (PHWR) NPGS - Base Data Study
- a. Plant design is based upon the " Conceptual Design of a Large Heavy Water Reactor for U.S. Siting", report number CEND-379, September, 1979.
- b. The reactor concept is a two-loop, pressure tube design, heavy-water cooled and moderated type developed by Com-bustion Engineering and United Engineers for the study listed in paragraph a. above.
- c. Where insufficient informatica is available, application design data from the Base Data Study (See Table 1-3) for
, the Pressurized Water Reactor NPGS is utilized.
- d. The inventory of heavy water for moderator and coolant is not included.
3.3.2.5 High Te=perattre Gas Cooled Reactor-Process Steam (HTGR-PS) NPGS Base Data Study
- a. Plant design is based upon the "1170 MWt HTGR Steamer Co-generatien Plant - Design and Cost Study", report number UE&C/
DOE 800716, August, 1980, performed by United Engineers 3-6 l 1 [
and General Atomic Company for USDOE. o
- b. Reactor plant design is based upon a 1170 MWt, 150 MWe, 750 F, 650 psia HTGR Nuclear Steam Supply System, developed by General Atomic Company for the study listed in paragraph a. above.
- c. Helium inventory is not included.
- d. This HTGR NPGS is located on a site in Eastern Pennsylvania.
The EEDB incorporates the necessary modifications to meet the ground-rule that the HTGP. NPGS is located on the "Middletown" site. 3.3.2.6 Liquid Metal Fast Breeder Reactor (LMFBR) NPGS - Base Data Study
- a. Plant design is based upon the target economic design described by Combustion-Engineering, Inc. in the Base Data Study (See
. Table 1-3) for a 1457 MWe LMFBR.
l b. The reactor plant design is based upon the Combustion-Engineer-ing, Inc., concept listed in paragraph a. above.
- c. The inventory of sodium and NAK for primary and intermediate lk heat transport system coolant is not it.cluded.
3.3.2.7 High and Low Sulfur Coal-Fired (HS12, HS8, LS12 and LS8) FPGS - Base Data Studies
- a. Plant designs incorporate a once-through, supercritical pressure, single reheat type, steam generator to supply steam to cross-compound, eight-flow turbines for the 1200 MWe units (HS12 and LS12) and to tandem-compound, four flow turbines for the 800 MWe units (HS8 and LS8.)
- b. The steam generators for both the high sulfur coal-fired plants (HS12 and HSS) and the low sulfur coal-fired plants (LS12 and LS8) are designed for either a high sulfur Eastern coal er a low sulfur Western coal.
- c. Each plant coal handling system is designed to unload a 100-car, unit train in five hours. The design provides indoor coal storage silos with a capacity sufficient for eight hours consumption at maximum rated capacity and an outdoor storage area with a capacity sufficient for 60 days consumption at maximum rated capacity.
i d. Plant design for each high sulfur coal-fired plant (HS12 and HS8) includes a wet lime scrubber system for removal i of sulfur-dioxide (S0 3 ) and an electrostatic precipitator for removal of particulates from the flue gas. 3-7 l }
\ }
- e. Plant design for each low sulfur coal-fired plant (LS12 and LS8) includes a dry lime scrubber and bag-house for removal of sulfur-dioxide (SO 2). and particulates from the flue gas.
l l 3.3.2.8 Coal Casification Combined Cvele (CGCC) FPCS - Base Data Study
- a. Plant design is based on the reference process given in Table 1-3.
3.4 FUEL CYCLE COSTS GROUND-RULES 3.4.1 Nuclear Power Generating Stations
- a. Operating life of nuclear plants are taken to be 30 years. Costs of individual expense items are given in the year of their occurrence i and are levelized over the plant life.
- b. Mass flow and related data are based upon NASAP (Non-Proliferation Alternative Systems Assessment Program) information.
- c. Costs of current interest are those'for " throwaway" cycles for the thermal reactors and plutonium recycle for the breeder reactors.
- d. It is assumed that reprocessing of spent fuel is introduced when breeders are phased into use. Prior to that time, spent fuel elements from " throwaway" cycles are assumed to be shipped to a Federal repository.
- e. Costs of onsite storage facilities for spent fuel are included in
, the plant capital costs in the Capital Cost Models, as described in
- Table 4-1.
- f. It is assumed that plutonium bred from U-238 in breeder cycles has
, no economic value.
- g. It is assumed that tails assay for enrichment is 0.2 percent by weight of U-235.
- h. No credit is given for advanced isotope separation processes.
i 1. Uranium costs are used for Thorium costs in this update, because there is no current Thorium market from which to derive Thorium
! costs. When such a market develops, Thorium costs will be included in the update.
l 3-8 i l
3.4.2 Fossil Power Generating Stations
- a. Coal costs for plants starting up on January 1, 1981 reflect the results of the 1978 first quarter compensation settlement of the United Mine Workers contract. These additional cost effects are included in coal costs for plant startups in 1987 and 2001,
- b. Coal cost data are derived from the sources listed below:
- 1. Messing, R. F. and Harris, H. E.: " Comparative Energy Values to 1990," Report No. R770602, Impact Securities Corp.,
(Subsidiary), Arthur D. Little, Inc., Cambridge, MA 02140, June, 1977.
- 2. Browne, Thomas E., et al. (Seven Authors): " Supply 77-EPRI Annual Energy Supply Forecasts," Report No. EA-634-SR, Electric Power Research Institute, Palo Alto, CA 94304, May, 1978.
- 3. Private Communication " Estimates of Baseline Delivered Coal Costs" (PWC Job No. 3592) - Paul Weir Co., 20 North.Wacker Drive, Chicago, IL 60606, October 13, 1978.
- 4. Monthly Energy Review, U.S. Department of Energy, Energy
- Information Administration, Washington, D.C. 20461 (Monthly Through September 1981).
4 l i i 3-9
-1 . l 1
l SECTION 4 4.0 SUMMAP.Y,OF Fot'RTH COST UPDATE 4 .1, TECHNICAL
SUMMARY
The current status of the Technical Models Ba.se Parameters for the Fourth Update is summarized in Table 4-1 for Nuclear Power Generating Stations and Table 4-2 for Comparison Plants. These summaries present a listing of importart or key parameters that establish the technical envelope of each plant. 4.2 FUEL CYCLE
SUMMARY
Mass flows selected for each of the nuclear plants are presented in Table 4-3. Much of this data was derived from Non-Proliferation Alternative Systems A<ssessment Program (NASAP) information. NASAP mass flow calculations are based on a capacity factor of 75 percent, while the capacity factor selected for the EEDB is 70 percent. However, review of sensitivity of Fuel Cycle Costs to sech a change in capacity factor reveals that the impact on comparison of alternatives is negligible. 4.3 COST
SUMMARY
Capital, Fuel, and Operating and Maintenance Costs are sunnarized for all - plants, for their respective capacities, in Table 4-4. Tables 4-5 and 4-6 summarize the same data, except that the capital and OSM costs are normali:ed to the same net electrical and thermal capacities respectively. Table 4-7 lists footnotes for Tables 4-4, 4-5, and 4-6. The direct cost for each plant account at the two-digit level is normalized by using the followin; relationship and the appropriate scaling factor: 4-1
l C Cg 1 P 1\ (6) g; where: C y= Plant 1 Account Cost C = Plant 2 Account Cost 2 P y = Plant 1 Capacity P = Plant 2 Capacity 2 n = Scaling Factor For the Fourth Update, values of "n" are estimated ba'se'd'on past experience. Values derived are 0.41 for Bk'R, Pk'R, and PHWR; 0.47 for HTGR and LMFBR; and 0.85 for HS12, HS8, LS12, and LS8. Since the indirect costs are directly proportional to the direct costs, the indirect costs are normalized by
/ applying the following relationship:
1 C C 73 D1 _ (7) C I2 D2 where: C = Plant 1 Total Indirect Cost 71 C = Plant 2 Total Indirect Cost 77 C - Plant 1 Total Direct Cost D1 C D2
=
pn a eet st Operating and Maintenance costs are normalized by recalculating the O&M costs from OMCOST with adjusted staffing and material inputs. Care must be exercised in using the values developed in Table 4-6. At 3800 MWt, current domestic tandem-compound or cross-compound turbine technology is exceeded by the net electric capacityof 1456 MWe for the HTGR-SC plant, 4-2 i
and is questionable at 1418 MWe and 1363 MWe respectively for the HS12 and LS12 plants, becayse the largest domestic steam turbine units presently available are approximately 1300 MWe. Design of such plants in 1981 would require twin-turbines with associated increased capital costs for the turbines, turbine pedestals, turbine building, auxiliary systems and equipment and additional steam header piping and valves. Therefore, for 1981, the capital costs in Table 4-6 for these two plants should be increased by 10-20 percent of their respective base direct costs. However, it is anticipated that at some point in the future, required turbine technology will be available for all of the base plants and the costs in Table 4-6 will apply, providing they are adjusted to current dollars of the year the technology is availab'le. 4.4 COMMODITY AND MANHOUR SUMMARIES Commodity summaries for nuclear and fossil power generating stations are given in Tables 4-8 and 4-9 respectively. Site labor summaries by craft are given for nuclear and fossil power gsnerating stations in Tables 4-10 and 4-11 respectively. This information is derived from the data included in the Capital Cost Models for the base plants, which are presented in Section 5. 4.5
SUMMARY
OF SIGNIFICANT COST PERTURBATIONS The Fourth Update of the EED3 has evolved from the studies referenced in Tables 1-3 through 1-5 and the EEDB Initial and following updates, as discussed in Sections 1 and 2. Significant cost perturbations have occurred between the preparation of the Third Update and the cost and regulation date of . this Fourth Update. These perturbations are addressed separately below for capital, fuel, and operating and maintenance cost. 4.5.1. Capital Costs The direct costs of all of the base plants are escalated to January 1, 1981 4-3
in accordance with EEDB Capital Cost Update Procedure described in the Initial Update Report. Individual accounts are modified and improved in definition as discussed in Section 5.4. In the Fourth Update, the Technical and Capital Cost models for each of the Nuclear Power Generating Stations have been adjusted to account for the current industry response to the lessons learned from the Three-Mile Island NPGS incident of 1979. These adjustments are described in detail in Section 5.4.2.1. Additionally, labor costs are increased, as discussed in Section 5.5.1. In the Third Update, the 1162 MWe, three loop CANDU type PHWR plant model is replaced with a 1260 MWe, two loop, U.S. design. The replacement is based upon a study for the conceptual design of a large heavy water reactor for U.S. siting. In this Fourth Update, modifications to the Base Data Study are continued, in order to improve the PHWR plant model relative to ( cohformity with EEDB ground-rules and consistency with the conceptual designs of alternative Nuclear Power Generating Station Technical Models. The LMFBR Plant model is based on a "Ta get Economics" approach, as described in the EEDB Initial Update. In the Second and Third Updates of the EEDB, i significant improvement is made in definition and detail in the Nuclear Steam Supply System and the Balance-of-Plant. These improvements and refinements allow the LMFBR model to be reported at the nine-digit code-of-accounts level of detail for cost, equipment and commodity tabulations. Additional improve-ment is made in this Fourth Update of the EEDB. Resultant target costs reflect a commercial reactor deployed in the year 2001, utilizing unit costs and quantities that represent a lower bound of possible LMFBR capital costs. 4-4
4.5.2 Fuel Costs The cost of raw U 0 in e ear e y e except for bree ers) accounts 38 for roughly 50% of the total cycle cost. The behavior of the market in U0 * '#* '* ** * * ** **I # *
"E
- 38 embargo of 1973, the forward price of U 03 8 r se steadily, reaching a point about six times its price in 1973. However, new discoveries in Australia and Canada and the virtual elimination of new nuclear utility plant orders are currently causing the market to drop precipitiously.
In the Initial Update, concern is expressed that the price for U 38 0 may . understate the fuel cycle costs, especially in projections to later years. For the Second, Third, and Fourth Updates, it is thought that the initial values may be reasonably correct, and that the most recent long range projections may overstate the U 0 c st. Predictions of U 03 g costs, especially 38 those that extend int,o the next century, should be treated as educated guesses. For the Fourth Update, this view is tempered by the fact that U 03 8 costs declined frem 1980 to 1981, relative to the general advance in inflation. The remaining portions of the nuclear fuel cycle are more stabic; however, those portions of the cycle involving fuel reprocessing and recovery are based on predictive analyses from gcvernment weapons operations, rather than on commercial experience. Coal costs used for plants that start-up on January 1, 1981, include the impact of the 1978 coal strike settlement. The coal costs projected for 4 future years also take account of the results of the contract settlement. Effects of the coal strike settlement of 1981 will be included in future updates. 4-5
i 4 l 2 ; 4.5.3 Operating and Maintenance costs O&M costs reported from OMCOST are refined on a continuous basis by ORNL to
~
reflect the latest factors arising from regulatory and economic considerations. O&M cost projections for the Fourth Update are based on increased staffing to account for the current industry response to the lessons learned from the ! Three-Mile Island NPGS incident of 1979. - I 1 i l il i d i 4-6 1
. . - . , , . , - - . . . . - . - . - - - . - . .,_ , - - , . - - . _ - - , - - ~ . . - . . - . _ . - . . - .
Effectivs Da ./1/01 A II H Sheet 1 of 4 ENERGY P.CONOMIC DATA BASE NUCLEAR PLANT TEOL1ICAL MODELS BASE PARAMETER
SUMMARY
Hodel B3 HTCR-SC M PHWR HTCR-PS IMFBR Key Elements General Site _ _Middletown* ~_
' Appendix A-1 Operation -c Base Load :
Cost Estimate Ref. Data < January 1, 1981 r Plant Life, Years c 30 Years : Nasaber of Unite Single Single Single Single Single Single Net Power to CSU+ 1190 MWe 850 MWe 1139 MWe 1260 MWe 150 MWe 1457 MWe Net Plant Heat Rate, 10,261 8,440 10,224 10,338 21,571 8,994 Bru/kWh Net Plant Efficiency, % 33.26 38.30 33.38 11,16 12.82 ! 38.34 Fuel (Initial Core) UO 2 UO2 + Th UO2 UO y UO2 + Th UO2 + Pu02 3% Enriched 20% Enriched 3% Enriched Slightly Enriched 20% Enriched 0.88% Enriched Nuclear Fuel Storage 5/4 Core 1.3 Core 4/3 Core 4/3 Core 1.3 Core 4/3 Core I.ICENSING Codes and Standards January 1, 1981
- Reference Year CIVIL / STRUCTURAL, Flooding Provision
- No Special Provisions r Turbine Building Enclosed r Seismic
- SSE 0.25g >
- CoE 0.125g -- -
- Foundations Rock a) Cat I-Mat b) Non-Cat I-Spread Ptgs.
- Modified to reflect January 19 81 criteria
+Cencrator Step-up Transformer e
l
_ _ _ _ - _ _ _ _ _ _ _ _. - . - . - . - - - _ _ - . - . _ . _ - _ - ~_ . -- . ..-- - - . _ _ . _ . . ~ _ . - - f 4-1 Effective Date - Is a ENESCT ECONOMIC DATA BASE Sheet 2 of 4 l l NUCLEAR PLANT TECHNICAL MODELS BASE PARAMETER SLNMART i Model BWM HTCR-SC PWR PHWR HTGR-PS INFBR I Key Elements 4 l Containment Steel Containment Reinforced Reinforced Reinforced Reinforced Reinforced ! w/Reinf. Concrete Concrete w/ Concrete w/ Concrete w/ Concrete w/ Concrete w/ } Steet Liner Steel Liner Steet Liner Steet Liner Steet Liner l - 1 Turbine Pedestal < High Tuned m-- Grade Elevation c + 18' 0" -- l Water Table c + 10' 0" - 100 Tear Maximum c + 8' 0" r , 100 Trs. flood i Esternal Missiles : Tornadoes Only - HECHANICAL ,
- c. Steam Cenerator Type None Helical Coil Shell & Tube Shell 4 Tube Helical Coil Single Wall Straight
' Tube Once Through
/n Economizer / Heat Exchanger Heat Excbanger Economizer /
a Evaporator / Evaporator / Combined Evaporator / Superheater Superheater Superheater Primary Coolant Pumps , Number 2 4 4 4 2 4/4**
- Drive Motor Electrge Motor Motor Electr Motor / Motor **
Fluw 42,000 gpm 9.3x10 lb/h 94,400 gpm 70,300 gpe 4.9x10gelb/h 86,200 gpm/76,700 gpm** Turbine Generatnr Tandem Compound Tandem Compound Tanden Compound Tandem Compound Cross Compound Tandem Compound j 6 flow 1800 r/ min 6 flow, 3600 r/rtn 6 flow, 1800 r/ min 6 flow, 1800 r/ min 2 flow. 3600 r/ min 6 flow, 1800 r/ min j 43" LSB .U " LS B 43= tsa 43" LSB 6" 13 8 43" 135 , LP Turbine - 29% flow Haln Steam Conditions at HP Turbine Inlet s Pressure, psia 960 2415 975 1085 2415
- 2200 f Temperature, F 544 1000 544 554 1000 850 Flow, 1061b/h 13.9 7.3 13.7 16.3 3.8 14.39 i
j Turbine Generator Rating 1235.4 MWe 9 935 MWe 1192.4 MWe 9 1343.6 MWe @ 187 MWe 9 1547 MWe 9 I 2.5 in-HgA 2.5 in-HgA 2.5 in-HgA 2.5 in-HgA 2.5 in-HgA 2.5 in-HgA 3 Condensers 3 Single Shell 3 Single Shell 3 Single Shell 3 Single Shell 1 Single Shell 3 Single Shell Transverse arrg. Im gitudinal Transverse arrg. Transverse arrg. Longitudinal Transverse arrg. Two pass Teo pass Two pass Two pass One pass 1%o pass l Split water box Split water box 5:ilit water box Split water box Split water box Spilt water box I Single Pressure Single Pressure Single Pressure Single Pressure Single Pressure Single Pressure
** Primary loop / Secondary loop I
1 i i b
1 .- l Effective Date /21 D4ERCY ECONOMIC DATA BASE Sheet 3 of 4 NUCLEAR PLANT TECHNICAL MODELS BASE PARAMETER St29tARY Mode 1 BWR HTCR-SC PWR PHVR llTCR-PS _DiJBR, Irey Elements MECHANICAL. (Cont'd) Cooling Tower Design : Mechanical Wet Evaporation Cooler : Conditions Approach c 18F s > Range 4 26F r Wet Bulb : 74F > Ultimate Heat Sink Mechanical Wet Mechanical Wet Mechanical Wet Mechanical Wet Mechanical Wet Air Blast (Conting Tower Type) Evaporative Evaporative Evaporative Evaporative Evaporative Heat Exchangers Cooling Tower Cooling Tower Cooling Tower Cooling Tower Cooling Tower and Air Blast and Air Blast Heat Exchanger Heat Exchanger Boiler Feed Pumps M.ain : Number-Drive 2-Turbine 3 -Turbine 2-Turbine 2-Turbine 2-Hotor 2-Turbine other: Number-Service-Drive 1-Start-up-Motor 3 -Booster Turbine 2-Emergency 2-Emergency-Motor 2-Booster-Turbine 2-Booster Motor 1-Motor 3- Boos t er-flot o r p 1-Turbine + l-Start-up-Motor Boller Feed Water Heater No. of Open Stages None ! @ l train None None I @ l train 1 @ 1 train No. of HP Closed Stages ! @ 2 trains 1 9 2 trains and I @ 2 trains 2 @ 2 '.r .09s I @ 2 train 1 @ 3 trains
- No. of LP Closed Stages 4 @ 3 trains and 4 @ 2 trains 4 @ 3 trains and 4 @ 3 trains 2 @ 2 train 4 @ 2 trains 1 9 2 trains 1 @ 2 trains Stages of Reheat One-Steam Reheat None One-Steam Reheat One-Steam Reheat None Two Steam Reheat o
ELECTRICAL _ Connection to Offsite Power : 1 @ 500 kV I @ 230 kV Cenerator Power Factor 0.9 0.9 0.9 0.9 0.9 0.9 0.50 0.58 Short Circuit Ratio < O.58 0.58 0.50 0.58 Rating 1,400 MVA 1,040 MVA 1,350 MVA 1,400 MVA 155 MVA 1718 MVA 52 MVA Cenerator Disconnect 4 Load Break Switch ;
- IP Closed Stage
_ . .__ _ - . _ - _, . _ _ _ . . _ _ . . . m m_ _ _ _ _ _ . . . _ _ _._ _ ~ _ _ - _ . _ . . _ _ _ _ . m f ~, Effective Date - 1/. Sh*** ' *I ' TABLE 4-1 DERCY ECtwiOMIC DATA BASE i NUCLEAR PLANT TECHNICAL tt)DELS BASE PARAMETER SUt9tARY PWR PHWR HTCR-PS IJtFBR Model BWR HTCR-SC Key Elements i EtF.CTRICAL (Cont'd) 13.8 kV and 480 Volts 13.8 kV, 4.16 kV 13.8 kV, 4.16 kV 13.8 kV and 480 Volts 13.8 kV, 4.16 kV Austitary Power System , 13.8 kV, 4.16 kV and 480 Volts Voltage and 480 Volts and 480 Volts and 480 Volts i 90 MVA 130 MVA 103 MVA 131 MVA
! Unit Auxiliary Trans- 80 MVA 103 MVA l
former N;uneplate Rating *** 90 MVA 55 MVA 103 MVA 73 MVA Reserve Austliary 80 tNA 103 MVA i Transformer Nameplate y Rating *** Control Room Wiring = Wired Directly to Panels in Control R mm Mone 2 Hultiplexing of = BOP Cables
~-~-
4 Independent Sensors for Computer Input a Instrumentation J 4
*** Total of all transformers at top class of cooling rating.
1
?
4 e-2
- Effsettvs Data - .I F.NERGY E02HTtlC DATA BASE Sheet 1 of 4 01MPARISON PIANT TEGINICAl. HohE1.5 BASE PARAMETER
SUMMARY
3 Model HSl2 HS8 LSl2 LS8 CCCC Fey Elements } Ceneral Site
- Middletown* -
~
Appendix A-2 Operatton a Base Load - .- - - - - - - - - - - - - : Cost Estimate Ref. Date + January 1, 1981 - ----- ' O Plant Life, Years c 30 Years ; i Number of Units c Single > Net Power to CSU4 1249 MWe 795 HWe 1244 IfWe 795 MWe 630 MWe Coa t Firing Rate, Tons / Day 12.264 8,20.4 17,328 11,592 4,680
- 9,079 Net Pit Pt 3 ate, Bi /htii 9,488 9,444 9,901 8,250 Net Plant Efficiency, 37.59 35.97 36.14 34.46 41.37
, y Fuel Eastern Coal Same as 11S12 Western Coal Same as LS12 Pittsburgh Stgan Coal g Moisture (% hy wt) Moisture (% by wt) tloisture (% by wt)
! 11.31 31.8 2.4 Ultimate Analysis Ultimate Analysis Ultimate Analysis
- (% by we dry) (% by wt dry) (% by wt dry)
Carbon 69.33 Carbon 69.3 Carbon 75.6 i Hyd rogen 4.90 Hydrogen 5.2 Hydrogen 5.2 Nitrogen .86 Nitrogen 0.9 Nitrogen 1.3 Chlorine 04 C*ilorine - Chlorine - Sulfur 3.61 Sulfur 0.5 Sulfur 2.6 Oxygen 9.64 Oxygen 16.8 Oxygen 8.0 Calorific Value Calorific Value Calorific Value (Ftu/lb) (8tu/lb) (Btu /lb) l As Received II,026 As Received 8,164 As Received 13,156 Dry 12.432 ]f Dry 11,970 ' f Dry 13,480 Coal t* livery 100 Car Unit Train 100 Car Unit' Train 100 Car Unit Train 100 Car Unit Train Train
@ 5 hr. Max. Turn. to 5 hr. Max Turn- @ 5 hr. Max Turn- @ 5 hr. Man. Turn. Unlosjing 8 hrs / day around around around around , Coal Storage _
60 Itays @ Full Imad - 90 Days @ Full Imad 8 hrs. In Ellos 16 hrs. In Silos
- Modified to reflect coal plant siting and January, 1981 criteria.
40enerator Step-up Transformer
r. TABL Ef f ect ive lista - 1/. ENERGY ECONOMIC DQTA BASE Sheet 2 of 6 COMPARISON PLANT TECHNICAL N0DELS BASE PARAMETER
SUMMARY
Phfel HS!? HS8 LS12 LS8 CCCC Key Flements CIVII./STRUCTUR AL Floswling Provision _ No SPecial '__ Provisions I C Enclosed 5 Turbine Building s Baller House c Enclosed Seismic Uniform Bldg. 7 Code Zone 1 Foundations Spread Footings on Rock
~
I Turbine Pedestat
- High Tuned *
- e. Crade Flevation C 18'0" b
" r Water Table < +10'0" 100 Year H.szimum ,'
+8'0" 7 W. iter level ,,
100 yrs. Flood i , MECl!^.N_i,,L, AL t .
,,. , )
Ste.am Generator Type Pulverleed Coal Ptiverized Coal' Pulv'erited Coal Pulverized Coal Waste Heat Boiler Pressurized Furnace Bal'anced Draft. ' Pressuri5ed Furnace Balanced Draft and Coal Casifier j ( r (Pulverized Coal) l Forced Draft Fan Rumber 1 2 3 2 2%' ' ' Drive Hotor Motor Motor Motor Hoter Flow, scfm 680,000 680,000 701,000 700,000' 167.d00 ' ' l
/
l . 1 s Induced Draft' Fan
- Number None 2 None 2 None . ' \ g l V i Drive Motor ,
Ntor , a Flow, scfm 900,000 1.100,000 , 's Number of Pulverizers 7 7 *8 8 4 Stack Height c 750 ft. I 270 ft. - Main Stack 3. 250 ft. - Vent + Flaie Stacks 4
m Effective Date -l/1/8. TAlt.E 4-2 Sheet 3 of 4 F.NE RCY ECONattlC DATA BASE OPtPARISON PLANT TECHNICAL. MODELS BASE PARAMETER SlHMARY Mode 1 Hy12 Hj8 LSI2 LSS CGC_C Eey Element {lttHAN1( AL (G>nt'd) If 502 bcrubber Lime (Wet)f line (Wet)f Line (Dry)II Lime (Dry) 112 S Scrubber - 5tretford Slu.lge Fixation On-Site On-Site Not Bequired Not Required Not Required Spent Product Disposal Trucked off-Site Trucked Off-Site Trucked Off-Site Trucked Of f-Site Not Bequired Turbine Generator Cross C.= pound Tandem Compound Cross Compound Tandem Compound Tandem Compound 8 Flow 4 Flow 8 Flow & Flow 2 Flow
%00/3MK3 r/ min. 1600 r/ min. 3600/3600 r/ min. 3600 r/ min. 3600 r/ min.
30" 1.58 33.5" 1.55 30" LSB 33.5" LSB 33.5" LSB ttain Steam Conditions at IIP Turbine inlet Superrritical Supercritical Supercritical Supercritical Superheated Prewure, psia 1515/600 3512/637 3515/600 3512/637 2535/455 c Temperature, F 1000/1000 1000/1000 1000/1000 1000/1000 10(4/1000 .', Flow. 10h Ib/h 9.1 5.8 9.1 5.8 2.0 w Cross Turbine Generator 1317 MWe 9 854 MWe @ 1317 MWe @ 854 MWe @ 655 MWe** Output 2.5/l.7 in-HgA 2.5/1.7 in-HgA 2.5/1.7 in-HgA 2.5/1.7 in-HgA 2.0 in-pgA Condensers 2 Single Shell 1 Single Shell 2 Single Shell 1 Single Shell 1 Single Shell longitudinal Arrgt. tongitudinal Arrgt. longitudinal Arrgt. tongitudinal Arrgt. Longitudinal Arrgt. One Pass one Pass one Pass one Pass Two Pass Split Water Box Split Water Box Split Water Bom Split Water Box Split Water Dual Pressure Dual Pressure Dual Pressure Dual Pressure Mllti-Pressure M.atn Heat Sink : Mechanical Wet Evaporative Cooling Tower n Natural Draft Wet llyberbolic Cooling Tower Cooling Tower c Approach 18"F/ Range 260F/ Wet Bulb Temperature 748F = Approach 16 F/ Range 240F Design Con.iltions Wet Bulb Temperature 74*F lioller teed Pu ops Main: Number - Drive : 2 . Turbine & Other: Number - Service Drive c 2 - Booster - Motor n 2 - Startup - Motor
** Steam Turbine - 1 @ 372 MWe @ 2.0 in-HgA and Cag Turbine -4@ 79.S MWe f With Electrostatic Precipitator i# W!th Baghouse
_ ~ _ .- _ _ . . ._ _ - _ a. - . ji il , il ik il
- as 80 -
0
%.e >
0 o e g 4 4 E4
, 2 E. E. >>
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- i. w w o ec : n.
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m TABLE 4-3 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE MASS FLOWS SELECTED FOR NUCLEAR PLANT FUEL CYCLES Model No. Nuclear Plant NASAP Reactor Fuel Type Identification Raw Data Source Al BWR Same as PWR 1 A2 IITGR-SC llTCR-U5/T/Th-20%-T (Throw-away) CAC A3 PWR PWR-US(LE)/U-T (Throw-away) CE A4 PIIWR PIIWR-US(SE)/U-T(CANDU) (Throw-away) CE T C; B1 IITGR-PS Same as llTGR-SC A5 LMFBR LMFBR-Pu/U/U/U-HT HEDL LEGEND t CE - Combustion Engineering, Inc. CAC - General Atomic Company llEDL - llanford Engineering Development Laboratory NOTES: (1) Non-Proliferation Alternative Systems Assessment Program (2) BWR data is not available; therefore, PWR date is used for BWR (Model Al) fuel cycle costs i
TABLE 4-4 Effective Date - 1/1/81 Sheet 1 of 2 ENERGY ECONOMIC DATA BASE COST UPDATE SIM1ARY ($1981)(I) (See Table 4-7 for Footnotes) Capital Cost I) Fuel Cycle Costs O&M Costs 1981 VariaMe 2001 Startup(3) Startup Startup(6) Model MWt HWe $106 $/kWe m/kWh c/MBtu m/kWh c/MBtu m/kWh c/MBtu m/kWh $106/y m/kWh BWR 3578 1190 1158 973 13.8 67(d) 6.9(d) 7t(e) 7,3(e) 88 9.0 36.5 5.0 llTCR-SC(a) 2240 858 1021 1190 16.9 *
- 83(f) 7.0(f) 89 7.5 35.7 6.8 PWR 3412 1139 1135 996 14.1 67 6.9 71(*) 7.3(e) 88 9.0 36.5 5.2 Pi!WR(b) 3800 1260 1301 1033 14.7 *
- 38(f) 3.9(f) 42 4.3 35.7 4.6 IITCR-PSI *) I170 150 798 # # * * *
- 89 # 21.7 #
IJ1FBR 3800 1457 1764 1211 17.2 * * *
- 44 4.0 42.6 4.8 IIS12 3299 1240 860 694 9.8 187 17.0 225I *) 20.4(*) 292 26.5 34.9 4.6 IIS8 2210 795 592 745 10.6 187 17.7 225(*) 21.3(*) 292 27.7 29.4 6.0 ,
LSl2 3442 1244 809 650 9.2 272 25.7 320(e) 30.2(e) 378 35.7 23.3 3.1 LS8 2307 795 558 702 10.0 272 26.9 320(*) 31.7(*) 378 37.4 21.0 4.3 CCCC 1523 630(C) 493 783 11.1 *
- 219(*) 18.l(*) 288 23.8 11.5 3.0
- Not Applicable
# Not Applicable for Cogeneration Facility
TABLE 4-4 Effective Dato - 1/1/81 Sheet 2 of 2 ENERGY ECONOMIC DATA BASE COST UPDATE
SUMMARY
($1981)(I} (See Table 4-7 for Footnotes) Total Energy Costs by Year of Start-up (m/kWh) Mode,1 MWt MWe 1981 1987 1995 2001 BWR 3578 1190 25.7 26.1
- 27.8 IITCR-SC(a) 2240 858 *
- 30.7 31.2 PWR 3412 1139 26.2 26.6
- 28.3 PINR(b) 3800 1260 *
- 23.2 23.6 IITCR-PS(a) 1170 150 f f f f IRFBR 3800 . 1457 * *
- 26.0 IIS12 3299 1240 31.4
- 34.8
- 40.9 IIS8 2210 795 34.3 37.9
- 44.3 LS12 3442 1244 38.0 42.5
- 48.0 LS8 2307 795 41.2 46.0
- 51.7 CGCC 1523 630 "
- 32.2
- 37.9
- Not Applicable
- Not Applicable for Cogeneration Facility
s TABLE 4-5 Effectiva Dzte - 1/1/81 Sheet 1 of 2 ENERGY ECONOMIC DATA BASE NORMALIZED ( } COST UPDATE
SUMMARY
($1981)II) (See Table 4-7 for Footnotes) Capital Cost ( } Fuel Cycle Costs O&M Costs 1981 Variable 2001 Startup(5) Startup Startup (6)
- 6 $106/y m/kWh Model MWt MWe $10 $/kWe m/kWh C/ mbt $ m/kWh C/MBtu m/kWh C/MBtu m/kWh ,
BWR 3425 o 1137 998 14.2 67(d) 6.9(d) 7a(*) 7.3(*} 88 9.0 36.5 5.2 IITCR-SC I *) 2974 1166 1024 14.5 *
- 83(f) 7.0(f) 89 7.5 35.7 5.1 PWR 3412 1135 996 14.1 67 6.9' 71
- 7.3(*) 88 9.0 36.5 5.2 PIIWR(b) 3435 1139 1248 1096 15.5 *
- 38(f) 3.9(f) 42 4.3 35.7 5.1 INFBR 2971 1571 1379 19.6 * * *
- 44 4.0 42.4 6.1 IIS12 3030 800 702 10.0 187 17.0 225(*) 20.4(*) 292 26.5 33.5 4.8 LS12 3151 " 750 658 9.3 272 25.7 320(*) 30.2(*) 378 35.7 22.2 3.2 1
- Not Applicable .
I
s TABLE 4-5 Effectiva Date - 1/1/81 Sheet 2 of 2 i ENERGY ECONOMIC DATA BASE NORMALIZED (2) COST UPDATE
SUMMARY
($1981)(I)
; (See Table 4-7 for Footnotes)
Total Energy Costs by Year of Start-up (m/kWh)
- Model MWt MWe 1981 1987 1995 2001 BWR 3425 n 26.3 26.7
- 28.4 IITCR-SC(a) 2974 *
- 26.6 27.1 PWR 3412 26.2 26.6
- 28.3 PHWR(h) 3435 1139 *
- 24.5 24.9 s~
' LMFBR 2971 * *
- 29.7 e
HS12 3030 31.8 35.2
- 41.3 LS12 3151 ' 38.2 42.7
- 48.2
- Not Applicable s
4 1
TABLE 4-6 Effective Date - 1/1/81 Sheet 1 of 2 ENERGY ECONOMIC DATA BASE NORMALIZED (3) COST UPDATE
SUMMARY
($1981)(I) (See Table 4-7 for Footnotes) Capital Cost (4) Fuel Cycle Costs O&M Costs 1981 Variable 2001 Startup(5) Startup Startup(6) Model HWt(3) gg, gio6 $/kWe m/kWh c/MBtu m/kWh c/MBtu m/kWh C/MBtu m/kWh $10 /y m/kWh BWR o 1264 1187 939 13.3 67(d) 6.9(d) 71(*) 7.3(*) 88 9.0 36.7 4.7 IITCR-SC(a) 1456(R) 1308 898 12.7 *
- 83(f) 7.0(f) 89 7.5 ~ 35.9 4.0 PWR 1269 1187 935 13.3 67 6.9 71(*) 7.3(*) 88 9.0 36.7 4.7 PIIWR(b) 3800 1260 1301 1033 14.7 *
- 38(f) 3.9 42 4.3 35.7 4.6 LMFBR 1457 1764 1211 17.2 * * *
- 44 4.0 42.6 4.8 IIS12 1428(R) 970 679 9.6 187 17.0 225I *) 20.4(*) 292 26.5 37.6 4.3 LS12 "
1373 880 641 9.1 272 25.7 320I *) 30.2(*) 378 35.7 24.6 2.9
- Not Applicable I
j TABa -6 l Effectiva Date - 1/1/81 ENERGY ECONOMIC DATA BASE Sheet 2 of 2 NORMALIZED ( ) COST IIPDATE
SUMMARY
($1981)II) 1 (See Table 4-7 for Footnotes) Total Energy Costs by Year of Start-up (m/kWh) Model HWt HWe 1981 1987 1995 2001 t BWR a 1264 24.9 25.3
- 27.0 IITCR-SC(a) 1456(R) *
- 23.7 24.2 PWR 1269 24.9 25.3
- 27.0 PHWR(b) 3800 1260 *
- 23.8 23.6 i LHFBR 1457 * *
- 26.0 e4 1428 IE} 40.4 HS12 30.9 34.3
- LS12 ' '
1373 37.7 42.2
- 47.7 -
- Not Applicable i
i L l t i
TABLL 4-7 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE COST UPDATE
SUMMARY
($1981)(I) FOOTNOTES FOR TABLES 4-4, 4-5, AND 4-6
- 1. Data in Constant 1981 Dollars (Inflation-Free)
- 2. Normalized to a Plant Size Providing 1139 MWe (Net); Not Applicable to HTGR-PS, HS8, LS8, and CGCC
- 3. Normalized to a Plant Size Providing 3800 MWt (Net); Not Applicable to HTGR-PS, HS8, LS8, and CCCC
- 4. Total Base Cost - Direct Cost + Indirect Cost s
- 5. Based on Plant Commercial Operation Date of January 1, 1981
- 6. Based on Plant Commercial Operation Date of January 1, 2001 i
N
- a. SC = Steam Cycle; PS = Process Steam Cogeneration
- b. Reported costs do not include cost of the initial inventory of Heavy Water, which is estimated to be of the order of $75 x 106 for the 1260 MWe PHWR NPCS.
- c. Four Gas-Turbine-Generators and One Steam-Turbine-Generator
- d. BUR Fuel Cycle Data not available; PWR data are used for BWR Fuel Cycle Costs
- e. Based on Plant Commercial Operation Date of January 1, 1987
- f. Based on Plant Commercial Operation Date of January 1, 1995
- g. Tandem-Compound or Cross-Compound Turbines are not available in this capacity in 1980; therefore, if Twin-Turbines are utilized, higher capital costs accrue for structures and Turbine Plant Equipment accounts.
Ef fective Date - 1/1/81 , TABLE 4-8 ENERGY ECONOMIC DATA BASit ! CONHODITY
SUMMARY
OP NUCLEAR POWEP. CENERATING STATIONS # t i
~Model/ Rating (MWe) BVR/Il90 HTCR-SC/858 PWR/Il39 PituR/1260 LMFBR/1457 i g
Consmod it y Qty.xt03 $/ Unit @ gty.x101 $/ Unit 9 Qty.al03 $/ Unit 9 Qty.midl $/ Unit 8 Qty.ul01 1/ Unit @ Excavation CY 536 14.10 423 6.77 529 14.22 523 16.01 780 16.'73 ReinforcinR Steel and TN 31 1,647.00 31 1,619.00 33 1,675.00 ' Structural Steel 35 1.616.00 56 1,667.00 Conc ret e CY 206 108.32 169(A) 104.00I *I 175 106.75 175 106.07 264 110.78 B(e Pumps HP 57 98.17 84 72.71 56 95.61 86 144.90 99 55.81 (1000 IIP and UP)
, Piping LB 6,89) 13.78 2,413 14.96 7.011 14.87 6,917 11.96 6,840 15.47 Wire and Cable LP 4,550 5.44 4,062 5.95 4,608 6.41 5.170 5.10 6,474 5.21 Turbine-Cencrator LT -
87.47* - 65.06* - 84.65* - - 85.88* 75.17* Nuclear Steam LT - 104.30* - 200.148 - 110.94* - - Supply System 131.92* 268.85* 1 1 I i HTGR-PS: Data not available from three-digit level Capital Cost Model
- Cost per Unit is in DcIlars per Kilowatt ($/kW) j + Includes Carbon Steel and Stainless Steel Piping l 9 1981 Constant hallars
- i
! (a) Does not include pre-stressed concrete reactor vessel (PCRV) I I { = 1 i 1
.m.
1 Ff fective Date - l/1/81 TABLE 4-9 ENERGY ECONOMIC DATA BASE Coret0DITY StNetARY OF FOSSIL POWER CENERATING STATIONSI l l Model /Ra.t inz (MWe) l hS12[,l240 HS8/795 L512/1244 LS8/795 i Comm>dity lini t Qty.x101 $/ Unit @ Qty.x103 $/t'ntt6 Oty.xt03 $/ Unite Qty.ul03 $/ Unit 0 i > Excavation CY 220 7.22 108 7.50 254 6.63 198 6.82 Reinforcing Steel and 25 1,353.00 f TN 31 1,322.00 24 1,270.00 33 1,322.00 Structural Steel ' l I Concrete CY 108 90.8) 89 90.76 117 88.68 93 89.54 i BOP Pumps IIP 104 43.83 66 51.58 104 43.83 66 51.58 j (1000 HP and UP) j Piping La 7.892 6.30 4,250 5.83 7,892 6.16 4,226 5.83 h Wire and Cable LF 3,986 3.73 3,421 3.75 3,989 3.73 3,423 3.75 Turbine-Cenerator LT -- 68.76* --- 56.36* -- 69.87* --- 56.36* i Fossil Steam 1.T 86.40* --- 91.63* --- 88.26* -- 92.65* Supply System j f CCCC: Data not available inom three-digit level Capital Cost Model i
- Cost per Unit is in ikillars per Kilowatt ($/kW)
@ 1981 Constant Do!!ars i
w
. .- _ . ~ . - . _ .. _-, .-. - . .. . _
t i l l 4 i i Ef fective Date - t/1/81 l I TABLE 4-10 l j ENERCY ECONOMIC DATA BASE I SITE LABOR
SUMMARY
FOR NDCLEAR POWER GENERATING STATIONS # l
- Model/HWe BWR/1190 NTCR-SC/858 PWR/ll39 PHWR/1260 LHFBR/1457 Craft MHx103 $x t Dl* mul03* $x103* MMx103 $x10Je Pelul03 $alola MHul03 $xt03*
Botter Hakers 618 11,045 669 11,947 916 16,361 994 17,766 1,396 24.949 Carpenters 2,257 34,419 I,908 29,060 2,114 32.231 1,997 30,448 2,449 37,343 Elec t r ic ians 2,618 43,40% 2,314 38,370 2,581 42,797 2,903 48,139 3.950 65,494 Ironworkers 2.467 38,875 2,045 32.234 2,051 32,318 2,222 35,018 4.087 64,414 L la bo rer s 2 . 2 34 25,381 1,686 19,150 2,088 23,723 2,039 23.162 2,859 32,480 Operating Engineers 1,515 24.153 9 30 14,821 1,263 20.135 1,275 20,126 1,975 31,478 Pipe Fitters 4.358 76,268 2.190 38,327 4.293 75,128 4.067 71.172 5,705 99,835 Others lypfl 24,519 1,805 27.367 1,368 19,855 13,412, 19,196 2,244 32,999 TOTAL 17,742 278,064 13.545 211,276 16,673 262,548 16,949 265,227 24,665 388.992 NH/kW I4.9 15.8 14.6 13.4 16.9
# HTCR-PS: Data not available from three-digit Capital Cost Model 1
@ These nusbers do not include the labor hours for erection of the Pre-stressed Concrete Reactor Vessel
- 1981 Constant Dollars l
]
. -.. . ~ .- .. . . _ - - _ - __ . . . _ . . -._ _ -_ _ - .- . .
t Effective Date - t/3/81 , TABLE 4-11 i ! ENERGY ECON 0 Hic DATA BASE SITE 1 ABOR StkttARY FOR FOSSIL POWER CENERATING STATIONSI I Model/HWe HSl?/l240 HS8/795 LS12/1244 LS8/795 i craft PGtx103 $x10l* HHx103 $x10l* HHal03 $x103* Mix 103 $x10l* l Botter Makers 290 5.188 209 3,742 158 2.953 116 2,0i6 Carpenters 448 6,828 367 5,591 448 6,837 352 5,374 El ec t ricians 1,830 30 ,3 34 1,515 25,120 1,664 27,585 I,400 23,219 fronworkers 942 14,849 717 11,297 918 14,463 720 11,353 s
'. Laborer s 66-i 7,542 ,535 6,075 794 9,021 617 7,011 l
j Operating Engineers 651 10,387 470 y,496 583 9.299 425 6.780 l 1 Pipe Fitters 3,783 66,196 2,488 43,536 3,598 62,964 2,321 40,619 1 others 2,385 36,818 1,671 25,679 2,464 38,466 1,725 25,741 TOTAL 10,993 178,142 7,972 128,536 10,627 171,588 7,676 122,173 MH/kw 8.9 10.0 8.5 9.7 1
# CGCC: Data not available f rom three-digit level Capital Cost Model f
- 1981 Constant Dallara l
i i l O I e
SECTION 5 5.0 CAPITAL COST FOURTH UPDATE The Fourth .Undate of the Capital Costs in the Energy Economic Data Base is accomplished in two distinct steps. The first step is the evaluation and adjustment of the technical models to assure that they reflect current changes in state-of-the-art designs, regulations, codes and standards. The second step is the adjustment of the capital cost models to reflect escala-tion, and to accommodate the technical model revisions. This section of the report presents the detailed results of the capital cost update, followed by a des'cription of the changes to the technical and capital cost models which support it. 5.1 CAPITAL COST UPDATE PROCEDURE ( A specific capital cost update procedure is developed for the EEDB, and is described in the Initial Update Report.* This update procedure is utilized for the selected technical models given in Tables 1-1 and 1-2 to develop
'he t Fourth Uodate o'f the Caoital Cost.
5.2 CAPITAL COST
SUMMARY
Capital costs are prepared for the EEDB as Base Construction Costs, which are the sum of the Direct and Indirect Capital Costs. Base costs include those cost elements listed in Table 2-10, as discussed in Section 2. Direct, In-direct and Base Capital Costs are summarized for all plants in Table 5-1. Tables 5-2 and 5-3 also summarize the same data for all plants, except that the capital costs are normalized to the same net electrical and thermal capacities, respectively. The normalization process is discussed in Section 4.3. The net electrical capacity chosen for this process is that of the
- Refer to Section 8.1 for additonal details 5-1
4 Pressurized Water Reactor Nuclear Power Generating Station (NPGS) Technical Model, so that capital costs of the other technical models can'be compared to this most frequently chosen industry cost base. The net thermal capacity chosen for the normalization process is the maximum licensable NPGS thermal rating of 3800 MWe, so that costs can be compared on the basi.s of maximum economy of scale. 5.3 DETAILED CAPITAL COSTS, COMMODITIES AND MANHOURS
~ '
Results of the Capital Cost Fourth Update are presented for each technical plant model at the two-digit and three-digit cost-code-of-accounts level in Tables 5-4 through 5-14 as follows: Nuclear Fossil Plant Table Plant Table Models Number Models Number BWR 5-4 HS12 \ 5-10 HTGR -SC 5-5 HS8 5-11 PWR 5-6 LS12 5-12 PHWR 5-7 LS8 5-13 HTGR-PS 5-8 CGCC 5-14 LMFBR 5-9 The first sheet of each table is a two-digit level cost tabulation and the following four sheets are the three-digit level cost tabulation for each plant model. Additional detail, down to the nine-digit cost-code-of-accounts level, is available in the Backup Data File, as discussed in Section 2.3.5. A total on the order of 10,000 computer sheets of cost and commodity detail is avail-5-2
able from this file. Commodities, including materials, equipment and craft labor manhours are tabulated for each technical plant model in Tables 5-15 through 5-23 as follows: Nuclear Fossil Plant Table Plant Table Models Number Models Number BWR 5-15 , HS12 5-20 HTCR-SC 5-16 HS8 5-21 PWR 5-17 LS12 5-22 PHWR 5-18 LS8 5-23 LMFBR 5-19 ( Tabulations for the HTGR-PS Nuclear Plant Model and for the CGCC Fossil Plant Model are not included, because they have not yet been sufficiently detail'ed to produce this information. When necessary information becomes available to expand the technical models for HTGR-PS and CGCC to the required degree of detail, they will be included in the data base. 5.4 TECHNICAL MODEL UPDATE The Base Data Studies and Reports listed in Table 1-3 are reviewed and modi-fled in accordance with the EEDB update procedure. Section 3.3 gives the assumptions and ground-rules for each of the technical models of the Base Data Studies and Reports. Appendix C1 contains Section 5.4 of the Initial Update (1978), Appendix C2 contains portions of Section 5.4 of the Second Update (1979) and Appendix C3 contains Section 5.4.2 of the Third Update (1980). These sections discuss the detailed modifications made to the Technical Models in the Base Data Studies and Reports for the Initial and following updates of the EEDB. 5-3
l This section discusses additional modifications to the Technical Models re ' quired for the Fourth Update of the EEDE to the cost and regulation date of January 1,1981. The applicable Base Data Study or Report, togetherwith the appro-priate modifications. listed in Appendices C1, C2, and C3 and this section, comprise the Technical Models for the Fourth Update of the Energy Economic Data Base. 5.4.1 ceneral Modifications A general review is done for each Technical Model in the Data Base, as modified for the Initial and following updates, to improve internal consistency among models and to assure that technical features and cost drivers are current. This review is accomplished in two phases. During the first phase, checks are made to assure that system, equipment, commodities and manhours track from model to model according to the Code-of-Accounts. Additionally, spot checks are made on cost significant items to assure that data has not been lost, 4 misplaced or incorrectly entered in the update. During the second phase of the general review, each model is modified, as required, to improve licensability, system performance, operability and constructability. As a first step in this phase, a review is made of the US Nuclear Regulatory Commission Regulatory Guides. New guides and revisions that have been issued since the Third Update cost and regulation date (1/1/80), but prior to the Fourth Update cost and regulation date (1/1/81) are identified. Each is evaluated for requirements necessitating addition or revision to existing design features. Modifications to Technical and Cost Models are then made based on this evaluation. Appendix D contains a tabulation of the results of the Regulatory Guide Review. Following incorp-oration of these modifications, a general review is made of the current state-of-the-art for nuclear and fossil-fired power generating stations. Where 5-4
._ . - .. __ m - . _ _ . __ _-. ____ __ ,__ -.
1 i
=
i required, modifications are made to those Technical Models that are not in accord with current practice. 5.4.2 Specific Modifications The following pages discuss the specific Technical Model modifications made during the Fourth Update. For convenience, the discussion of each plant model is started at the top of a new page. , i t 1 f t ! 5-5 1
, - - - , - , . , ,y, -- - , .- - , ., - > - , , - - - - - - - . --_ - _ - , _ , . , , . - - . - -
5.4.2.1 EEDB Model Number A1, Model Type BWR, EEDB Fourth (1981) Update EEDB Model Number A2, Model Type HTGR-SC, EEDB Fourth (1981-) Update EEDB Model Number A3, Model Type PWR, EEDB Fourth (1981) Update EEDB Model Number A4, Model Type PNWR, EEDB Fourth (1981) Uposte EEDB Model Number B1, Model Type HTGR-PS, EEDB Fourth (1981) Urdate EEDB Model Number AS, Model Type LMFBR, EEDB Fourth (1981) Update Base Data Studies: Commercial Electric Power Cost Studies - Capital Cost 4 (A1) Boiling Water Reactor Plant (NUREG-0242, C00-2477-6) (A3) Pressurized Water Reactor Plant (NUREG-0241, C00-2477-5) (A2) The HTGR for Electric Power Generation - Design and Cost Evaluation (GCRA/AE/78-1) (A4) Conceptual Design of a Large NWR for U.S. Siting (Combustion Engineering, Inc. CEND-379) (B1) 1170 hWe HTGR Steamer Cogeneration Plant - Design and Cost Study (UE&C/ DOE-800716) (AS) NSSS Capital Costs for a Mature LMFBR Industry and Addendum (Combustion Engineering, Inc. - (CE-FBR 532 & CE-ADD-80-310) The following codifications are common to all of the nuclear power generating stations in the data base. These modifications take the form of additional i' design features that reflect the current industry response to lessons learned at the Three-Mile Island NPGS incident of March 28, 1979. ACCOUNT 218L Technical Support Center A Technical Support Center (TSC) is added to meet the criteria promulgated in NUREG-0696, " Functional Criteria for Emergency Response Facilities". The TSC is housed in a separate building for the BWR, HTGR-SC, PWR, and HTGR-PS. In the PHWR and LMFBR, the TSC is located in an existing building expanded ! for that purpose (refer to Sections 5.4.2.2 and 5.4.2.3 respectively). i 1 i ACCOUNT 227 Instrumentatien and Control Instrumentation is added for the following: r l a. Relief and Safety Valve Testing
- b. Direct Indication of Valve Position
- c. Detection of Inadequate Core Cooling
- d. Diverse Containment Isolation
- e. Hydrogen Control
- f. Plant Shielding Review 5-6
- g. Auto-initiation of Auxiliary Feedwater
- h. Auxiliary Feedwater Flow Indication
- 1. Post-Accident Sampling ,
- j. High-Range Radiation Monitoring .
- k. Improved Iodine Monitors
- 1. Transient and Accident Analyses
- m. Systems Integrity for High Radioactivity ACCOUNT 242 Station Service Equipment A non-Cleas IE emergency power supply and auxiliaries is provided to support the Emergency Response Facilities.
ACCOUNT 243 Switchboards Systems consoles are added for the Technical Support Center and the Operations Support Center. Power distribution panels are added to control and distribute normal and emergency power to the Emergency Response Facilities. ACCOUNT 245 Electrical Structures and Wiring Containers ACCOUNT 246 Power and Control Wiring Wiring and wiring raceways are added to interconnect the additional instru-mentation (refer to Account 227), control consoles (refer to Account 243), emergency power supplies (refer to Account 242) and power distribution panels (refer to Account 243). i I l 5-7
5.4.2.2 EEDB Model Number A4, Model Type PHWR, EEDB Fourth (1981) Update Base Data Study: Conceptual Design of a Large HWR for U.S. Siting (Combustion Engineering, Inc. CEND-379) ACCOUNT 218A Control Room / Diesel-Generator Building ' The Control Room / Diesel-Generator Building is revised to include the. function of the Technical Support Center (TSC) to meet the criteria promulgated in NUREG-0696, " Functional Criteria for Emergency Response Facilities". In the Fourth Update, an allowance is made in the Structures and Improvements Account capital costs. ACCOUNT 218C Component Cooling Water Building The Component Cooling Water Building is added to house the component cooling
~
i water heat exchangers and the pumps required for normal and emergency operating conditions (refer to Account 226). The building is a reinforced concrete Seismic Category I structure, located at grade. It is a one-story building, measuring 150 feet long, 150 feet vide, and 20 feet high, with a volume of approximately 450 x 103 cubic feet. Walls and roof are 2-feet thick and the base slab $s 4 feet thick. ACCOUNT 222A Main Heat Exchange Transport System The equipment and piping system supports are modified. Auxiliary heat transfer , equipment is modified to reflect design changes required to convert the refrigeration cooling system to a water cooling system (refer to Account 226). ACCOUNT 222B Moderator Circuit Piping supports are modified. The moderator pumps and moderator heat exchangers are redesigned to accommodate the changes from a refrigeration cooling system to a water cooling system (refer to Account 226). 5-8
. ACCOUNT 226 Other Reactor Plant Equipment The heavy water cooling water heat exchangers, pumps, and piping design is incorporated to provide a closed loop to contain any tritiated water from the moderator system. These exchangers are furnished cooling water from the service water system.
The primary component cooling water system pumps and heat exchangers are designed and inccrporated in this updata. These components replace the refrigeration cooling system incorporated in the Base Data Study. The nuclear service water system pumps and the ultimate heat sinks are redesigned on the basis of the change from the refrigeration cooling to water cooling. ACCOUNT 234 Feedwater Heating System The main boiler feedwater pumps and turbine drives are changed from 3-50 percent to 2-50 percent units to be consistent with the EEDB PWR and BWR NPGS. ACCOUNT 241 Switchgear ACCOUNT 242 Station Service Equipment ACCOUNT 245 Electric Structures and Wiring Containers ACCOUNT 246 Power and Control Wiring The electrical distribution system is modified to support the required design changes to accommodate the conversion frem a refrigeration cooling system to a water cooling system and design changes related to other auxiliary systems (refer to Accounts 222A, 222B, 226, 234, 252, & 262). ACCOUNT 252 Air, Water, and Steam Service Systems
~
The service water syste= is redesigned in this update to furnish cooling water to all plant services, including those previously furnished from the refrigeration 5-9
cooling syste= (refer to Account 226). Service water pumps are changed from 2-100 percent pumps, each having a capacity of 11,000 gallons per minute, to 5-25 percent pumps each having a capacity of 30,000 gallons per minute. ACCOUNT 262 Mechanical Ecuipment The circulating water pumps are changed from 5-25 percent pumps, each with a capacity fo 161,500 gallons per minute, to 5-25 percent pumps, each with a capacity of 165,700 gallons per minute. The main cooling towers are changed from 3-33 1/3 percent towers, each with a capacity of 307,670 gallons per minute, to 3-33 1/3 percent towers, each with a capacity of 276,167 gallons per minute. a 5-10
/ 5.4.2.3 EEDB Model Number AS, Model Type LMFBR, EEDB Fourth (1981) Update Base Data Study: NSSS Capital Costs for a Mature LMFBR Industry and Addendum (Combustion Engineering, Inc. - CE-FBR-78-532 & CE-ADD-80-310) ACCOUNT 214 Security and Technical Support Center Building The Security Building is revised to include the function of the Technical Support Center (TSC) to meet the criteria promulgated in NUREG-0696,
" Functional Criteria for Emergency Response Facilities". The structure is revised to that of a two-story building with one floor (the TSC) located below grade.
ACCOUNT 218A Control Building The control building is revised to reflect the new arrangement required by ( the present fuel handling system and revised auxiliary heat transport system hav, and the recuirement for " rattle-space" between the control buildin[ and the steam generator building. ACCOUNT 224 Radwaste Processing Two changes are incorporated in the gaseous waste processing systems. The tritium removal capability is deleted from the radioactive argon processing system (RAPS). Filters are added downstream of the tritium absorption units of the cell atmosphere processing system (CAPS). ACCOUNT 262 Mechanical Eculpment The circulating water system is revised to reflect the revised water flow and the piping arrangement resulting from a change from three to two cooling towers. The cooling towers are recosted to reflect a decrease in heat lead requirement 5-11
I 5.4.2.4 EEDB Model C1, Model Type HS12, EEDB Fourth (1981) Update EEDB Model C3, Model Type LS12, EEDB Fourth (1981) Update Base Data Study: Commercial Electric Power Cost Studies - Capital Cost - - High and Low Sulfur Coal Plants - 1200 ML'e (nominal) (NUREG-0243, C00-2477-7) 4 ACCOUNT 231 Turbine-Generator The turbine-generator is reviewed for conformance with current manufacturers' quotations. Recent improvements in turbirs design provide a small increase in turbine generator unit output for t he Fourth Update. 5-12
.I 5.4.3 Ongoing Modifications During the course of preparing the Third Update of the EEDB, it became apparent that general piping systems modifications were required for some of the Technical Models that would take more effort than could be allotted to the resources available for a single update. Development of the piping systems changes continued in the Fourth Update. Although the modifications are initiated in the Third Upeace, the results will not be reported until the Fifth Update is completed.
5.5 COST MODEL UPDATE . 5.5.1 Direct Costs Modifications to equipment, material and craft labor man-hours and associated costs are made, as required, to reflect the Technical Model modifications described in Section 5.4 above. Additionally, adjustments are made 'to reflect January 1,1981 construction labor man-hours to arrive at new labor costs based on both the modified and unmodified labor hours. Total direct ! costs are revised accordingly. 5.5.2 Indirect Costs Construction Services (Account 91), Heme Office Engineering and Services
-(Account 92) and Field Office Engineering and Services (Account 93) are reviewed to assure that they continue to reflect direct Factory Equipment Costs, direct craft labor hour costs, direct craft labor hour costs and current field practice.
5-13
r Effective Date - 1/1/81 TABl.E 5-1 ENERGY ECONOMIC DATA BASE CAPITAL ($1981COST x 106UPDATE
)(a )
SUMMARY
Nuclear Plant Models Comparison Plant Models Model BWR llTCR-SC PWR PHWR(b) IITGR-PS LMFBR HS12 115 8 LS12 LS8 CCCC MWt 3578 2240 3412 3800 1170 3800 3299 2210 3442 2307 1523 MWe 1190 858 1139 1260 150 1457 1240 795 1244 795 630 T'
- g Direct Cost 761 654 745- 884. 480 1215 711 490 677 465 395 Indirect Cost 397 367 390 417 318 549 149 102 132 .
97, 98 Base cost 1158 1021 1135 1301 798 1764 860 592 809 558 493 - f . 9
$/kWe 973 1190 996 1033 (c) 1211 694 745 650 702 783
, ' 1 .
- a r s
(a) Data in Constant $1981 (Inflation-Free) , (b) Reported costs do not include cost of the initial inventory of heavy water, which is estimated to be of the order of $75 x 106 for the 1260 MWe PHWR NPCS (c) Not Applicable for Process Steam / Cogeneration Plant
\
9 m O J
Ef fective Date - 1/1/81 TABLE 5-2 ENERGY ECONOMIC DATA BASE NORMALIZED (8) CAPITAL COST UPDATE
SUMMARY
($1981 x 106 )(b) Nuclear Plant Models(C) Comparison Plant Models(d) Model llTCR-SC PWR PIIWRI ') LMFBR HS12 LS12 _BWR int 3425 2974 3412 3435 2971 3030 3151 PNe : 1139 , c 1139 : Y U. Direct Cost 747 747 745 848 1082 661 628 Indirect Cost 390 419 390 400 489 139 122 Base Cost 1137 1166 1135 1248 1571 800 750
$/kue 998 1024 996 1096 1379 702 658 PWR Cost Ratio 1.00 1.03 1.00 1.10 1.38 0.70 0.66
$/kWe (a) Normalized to a plant size providing 1139 MWe (Net)
(b) Data in Constant $1981 (Inflation-Free) (c) Normalization not App 11 cable to HTGR-PS (d) Normalization not Applicable to HS8, LS8, and CCCC (e) Reported costs do not include cost of the initial inventory of heavy water
- s-Effective Date - 1/1/81 TABLE 5-3 ENERGY ECONOMIC DATA BASE NORMALIZED (a) CAPITAL COST UPDATE SIR 2tARY
($1981 x 106)(b) Nuclear Plant Models(C) Comparison Plant Models( } Model BWR llTCR-SC PWR Pl!WR(*} LMFBR llS12 LS12 MWt : 3800 : 3800 > HWe 1264 1456(f} 1269 1260 1457 1428(f) 1373 Direct Cost 780 838 779 884 1215 802 736 Indirect Cost 407 470 408 417 549 168 144 Base Cost 1187 1308 1187 1301 1764 970 880 $/kWe 939 898 935 1033 1211 679 641 PUR Cost Ratio 1.00 0.96 1.00 1.10 1.30 0.73 0.69 $/kWe (a) Normalized to a plant size of 3800 MWt or its equivalent (b) Data in Constant $1981 (Inflation-Free) (c) Normalization Not Applicable to llTGR-PS (d) Normalization Not Applicable to IIS8, LS8, and CCCC (e) Reported costs do not include cost of the initial inventory of heavy water (f) Tandem-Compound or Cross-Compound Turbines are not available for this application in 1981; therefore, if Twin Turbines are utilized, higher capital costs accrue for Structures and Turbine Plant Equipment accounts
\ -
, Effective Date - 1/1/81 T
c TABLE 5-4 . ENENGY ECONOMIC DATA BASE \ __ 1190 We' BOILING WATER REACTOR NPGS CAPITAL COST ESTIMATE s 9 F e 1 5-17
- - __ m
-m PLANT CODE UNIIE D E NGINE E RS & CONSIRUCIORS INC.
SUMMARY
PAGE f COSI BASIS E NE RGV E 00tJOMIC OA I A DASF (EtD88 PetASE IV 20t 09/81 1990 MwE SO l t. l eM'. W A f E R RE ACIO54 08/21/88 FACIORY SIIE SITE SITE. IOIAL ACCI NO ACCOUNI OESCRIPilON EQUIP. COSTS LAROR HOURS LABOR COS1 M&fERIAL COST COSIS 20 LANO AND L AM) RIGHTS 2.750.000 2.750.000 29 STRUCIURES & IMPROVEMENIS 6.734.092 8987849 Mt 932.372.467 70.998.376 250.804.935 22 REACIOR PLANT EOUIPMENT 159,267.737 2996968 M4 50.403.762 92.806.546 222.478.045 23 . IU9BINE PL ANI EQUIPMENI I4G.080.455 2680270 Me 44.859.964 9.099.929 899.332.345 24 ELECIRIC PIANf EQUIPMENT 26.580.697 2966089 Me 35.298.078 99.109.*990 72.908.678 25 MISCELEANEOUS PLANI EOUIPT 90.890.994 485867 Met 8.850.004 9.653.279 20.693.389 26 MAIN COrJO ltE AT REJECT SVS 23.173.977 495395 Mt 7.759.750 1.983.008 32.996,835 IOTAL DIRECT CtlSIS 37..'26.992 87742400 Mt 278.064.005 180.393.220 764.984.227 94 CONSTRUCTION SERVICES 58.808.30t 2920244 M4 45.948.674 38.998.300 143.755.275 92 HOME Of F ICE E NGRG.&SE RVICE 172.It1.610 172.It9,6to 93 FIELO OFFICE ENGRG4 SERVICE 77.674.740 3.048,950 80.693.690 IOTAL IM)IRECT COSTS 308.594.659 2920244 Mt 45.948.674 42.087.250 396.560.575 TOTAL BASE COSI 688.321.643 20662644 Mt 324.092.689 152.440.470 1.057.744.802 Y
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SUMMARY
PAGE 3 COSI BASIS ENtRGY ECONOMIC 04fA BASE (TEOR) PilASE IV 201 08/89 1:40 MwF HoltING WAIER REACIOR 08/2t/89 FACIORY StIE SITE Sit [ 10IAL ACCI NO ACCOUNI OfSCRIPilON foulP. COSIS EAOOR leOURS LABOR COSI MAIERIAL COSI COSTS eeeeeeeeee eeeeeeeeeeeeeeeeeeeeeeeeee ,,eeeeeeeeeee eeeeeeeeeeee eeeeeeeeeeeee eeeeeeeeeeeee eeeeeeeeeeeeee 22O4 NUCtfAR SIEAM SUPP1V(NSSS) 988.800.000 198.800.000 2200. NS$$ OPflONS 224. RFACIOR'EQUIPMfNI 772.858 770888 hl 83.084.795 4.20.078 17.997.024 222. MalN ffF AI AFER RPURI Sv5. 445.923 253977 Mi t 4.302.236 430.053 5.878.292 223. SAFEGtfAROS }VSIEM 7.994.745 627577 Mit 10.590.896 0.051.255 19.636.896 224. RAOWASTE PROCESSING 92.291.204 415974 Mi t 7.088.528 f.610.743 20.920.475 225. FUEL Bf4NDLING + STORAGF l.158.752 9 96 t ? Maf 1.529.130 166.606 2.847.488 226. OllifR REACIOR EOulP. 6.t90.854 484954 Me t 8.184.460 2.634.749 87.080.063 227. INSIRUMENIAllON
- CONTROL 18.629.000 128142 Mel 2.080.729 178.180 93.880.000 228. RfACIOR PLANI MISC ITEMS 224239 Mt 3.682.988 2.524.889 6.207.877 22 REACIOR PLANT EQUIPMENT 959.267.737 2996968 Met 50.403.762 12.80G.546 222.478.045 230. IURRENE CfNFRAIOR 96.550.715 640288 Mit 10.892.783 1.934.426 108.677.854 233. COrJOENSING SYSIE MS 98.842.880 415583 Met 6.995.103 1.354.250 26.492.163 234. F E E D lie AT ING SYSIE N '94.192.583 549666 Met- 9.289.908 927.369 24.409.860 235. Ollif R IURRINE PLANT EOUIP. 15'666.390 827679 Me t 13.733.924 t.633.696 34.034.007 23G. INSIRUMENIAllON
- CONIRDL 9.527.957 74425 Mil 1.207.690 107.479 2.843.826 237. IUROINE PLANT MISC IIEMS ~
173437 Mit 2.748.626 3 t34.709 5.883.335 23 1URBINE PEANT E QUIPM8 NT 846.080.455 2680270 Met 44.059.960 9.099.929 899.332.345 i
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Q w e=2 =e-2 < *
=
C
=
=
w u w w u u w u w
'= v e v =0 3 3 2
w v
=
w 2
=
U w 30 = = = w c N v 3 Os a u a u w w w
=
w w c < >
< w a e 4 3 w e= Q O w m m m Q w 2 e U* a a= a = c c O o o o 7 0 e C = c ue O 0 = e =
<
- A e 2 X 2 e w w w w O C O = C a J e 2 2 > a < = w a 2 w < <
i
- w C Z Z E 2 2 w w w < w =
l
* = U 4
a w 4 3
= U 0 g .g g = = = w = C
=
C w . .Q . w w w a w = = 8 U
=c g
m Zn .
< m . . . .
w U9
- m w @
l L - -N - - - -
- n m
- n m T v .e N n n m a m m
! . e e e e e e e e e .a . e e e m
.e i
i t l
4 Effective Date - 1/1/81
. TABII 5-5 ENERGY ECONOMIC DATA BASE
(\ . 858 MLie HIGH TEMPERATURE GAS COOLED REACTOR-STEAM CYCLE NPGS CAPITAL COST ESTIMATE
\
5-18
=
- . . - - , , e e e
e , e
- e. e. e. n. n.
e e n e 8ee e o e e
. e. . e. n. n. n. n. ,
N se* o. e N , e e o - e n > e w * <> @ e > ,c - n M @ e e n =o c n -e > e, o
< N co*
- n. e. e. e. e. e. n. e. o.
E e *v* n oe e e.* W n e >
,. e n %* * -
Q
- a e
N = e - n e e - M e n n g e O. I o e
*. n n e - , - N O
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- e n O e n ms e e o e n n n N
e n n e n o o n
-** n e-. e. e. n. e. n. n. m. e. o. C. o. >
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~ - -
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= c aw , e e e ~ n n e e o
=ew e<a
=w$*
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~
e n e n n ( ges ec. e e e- oe eoe nee, e ~ n e, n e n n o v.. . .e n - - e e e -
== s n n a e ew . -
e Q4E auw w== wx e. n e e , 2- - . o e , a n n, ~ e o
, e e o e e a
=f3 ee > e, e e
>o* o. e. e. e.
EG-ww v: av = e. e , e e ~ n
- e- e n n.
- e. n.
n en o e
- n. e.
e o.
=
~ = * .
, e e n o>> e. e.
was <=us e eo oe -e a e
- e. n. o. . . . a.
n -
- n. n. e.
=a w. e, -
-we 5 n n
n n 8 m g2c w e n e
.we .
- e . .
. = e, u
- u 2 = = e > >
2* w 2 2 O* a w w = m m a
=* w 1 w w 3 1 U w e e e
=.
ao > a= 4 = w U d = e O =
- 7 e e.
U -3 > c aO
- e e ~*
- a. *- a G O 3 2 o w L w a
=
e o
=
e W* O 2 w w o a w q e y me > 4 w* a = = 2 = <
= o = y @ h 2w > @
e-e C. e 2 2 e w = 2 w w y w o
* *
- 4 a w 2 u o w u u
=N e*
y* I e a a a 2 w = v - a
- w w & L g ^ a = = w Co w a U s U m e v 5 *. 2 a w - c 5" o s w w w a 2 e U* * = c 2 a y a o
- e U* y u - = =
=* g -
* . a e e
a vw c e-= 2 a e w e w c w w a
* * = w : 2 2 w = =
- w e a -
s w I g 1 o C Q. = c o w = v = = =
-E
- W
- e M
=n 2 .
2n 4 =e e s W. A U* o - n n , e e = n n 4 . n n n n n n n e e e
m
]
twds t f D INGINE f RS & CONSINOClORS INC.
SUMMARY
PACf 2 PLANT CODE COSI HASIS ENfRGW (CDNUMIC DAIA BASE (EEDO) PHASE IV 338 09/8e 85n Mwf HIGH IE MPE R A f tsut GAS CDOLfD REACIOR-SC 08/29/89 - FACIORY SITE SITE SITE TOTAL ACCI NO ACCutwJT DESCRIPTION EQUIP. COSTS L Af40R 88043R5 LAttOR COSI MAIERIAL COST COSTS 20 (ANO e L A ND R I G818 5 2.750.000 2.750.000 219. WARDwORM 241.793 464894 Mel 6.439.223 6.035.490 12.716.506 292. REACIOR CONT A I NME NT BLOG M61.358 2048905 Met 34.50s.967 28.623.228 53.986.546 283. IllkBINE HulLDING 597.934 3 9 4 706 Me t 4.839.940 4.774.258 10.212.925 294 SECURRIY tlultOING 49.924 19944 Me t 307.260 185.678 534.862 215. AUX RFACIOR SERVICE BLDG 778.446 554275 MH 8.886.960 4.220.729 93.916.135 296. MAIN CIRC CONTROL BtDG 3t5.545 12364 Me t 183.543 149.098 648.186 287. L ONG T E RM FUE L STORAGE BLO 64.473 465745 Mel 6.834.159 3.142.582 10.041.144 2184 CONTROL, AUMIL & D.G.BtDG 10G2568 MH 15.676.845 t.697.889 5.392.814 22.687.548 2180. ADMIN
- SE RV BLOG 403.800 224846 Met 3.480.246 2.344.294 6.228.350 298D. FIRE PUMP HOUSE 34.759 9099 MH 839.800 66.203 240.762 288E. L.P. ItElluM STORAGE AREA 43816 MH 627.843 644.360 f.272.203 298F. NON-VIIAL SWITCHGEAR HLOG 6065 Met 90.865 78.667 169.532 2 f Rel. DIES ctg
- FL OIL SIG BL OG 92.377 192465 Mel 2.766.900 986.070 3.765.347 2181. W A R E HotlSE 8300 MH 123.521 990.795 234.316 288J. CONI AINME NT ANNULUS BtDG 15.503 236165 MH 3.422.094 8.453.000 4.890.597 2tBK. CONIAIN PENETRAllON 8tDG 484.568 426582 Met 6.934.654 s.799.413 8.488.628 288L. I E CIINIC AL SUPPORI CENT E R 42.303 433.408 28668 Met 205.733 688.444 2185. HOLDING PUMP + CONTRL llSE 19517 MH 279.600 116.279 395.879 218i. ULTIM HEAT SINK SIR +TUNNLS 44.960 534693 Met 7'.655.460 2.192.999 9.892.531 218V. CTL RM ENG AIR IN STR 24.868 7167 MH 103.336 25.845 154.099 28 SIRUCIURES & IMPROVEMENIS 5.589.703 6680084 Mi t 99.157.624 55.547.333 160.286.660
I T1 3 . 0 0 6 8 6 0 0 4 4 l 0 4 5 5 9 7 1 f
. 0 7 7 3 2 0 3 0 0 4 0 5 5 7 0 9 9 1 . 0 0 4 9 9 4 3 6, 8. , 5 0 7 6 8 6, 9 8 8 .
/ L$. 0 4 5 3 2 0 7 2 0 7 3 0 4 8 9 5 4 F 1 Ai 2 4 6 9 4 6 8 9 7 7 3 3 7 4 1 5 5 G 2 TS 7 2 1 3 5 8, 4 8 t 4, 8 5 7, 3 t 0 6 A /
P 8 OO. I C. 9 5 5 9 4 7 2 6 3 6 9 3 5 2 2 2 7 0 7 3 2 6 6 1 1 2 8 Y . 1 2 1 R A M . M U S I . 2 9 3 9 3 3 8 6 3 8 6 G 4 3 8 5 S.
- 8 8 8 0 6 4 3 4 5 7 8 2 6 0 4 0 O 5 2 5 0 4 7 5 7 9 4, 5 9 1 2 3 7 E C. 8 6 6 0 9 0 2 9 8 9 9 8 0 2 2 2 T L 9 9 5 0 5 5 4 0 5 0 8 7 1 2 6 I A 7 2 3 2 1 00 3 3 2 7 5 7 6 SI . . 3, R . 8 2 2 2 1 5
E 1 2 T A M C . 0 8 7 7 5 7 8 8 3 2 7 7 4 9 9 0 S I 7 5 0 6 5 3 7 5 2 0 4 5 1 3 4 0
- S 5 3 8 9 8 4 2 1 3 9 6 R O 8, 1 4 6 1 O EC 2 9 5 8 4 9 8 6 9, 9 4 5 0 7 3 1 VT T 8 8 7 0 0 3 4 7 1 2 0 4 6 5 3 3 I C I R 8 9 2 4 7 6 2 6 3 9 A SO 9, 3, 7, 8
. 3, 1 EE R 5 2 3 l 4 5 I 2 5 8 3 5 0 0 4 8 SR A 1 3 4 3
.A L CHD NPE .
I L
) O St f O RDC Of S. t i i i t t II t i
0 6 t i i t t e H H t e t e t i i t t MM MM i I ES R . M M M M M M M MM M M M C( A U U G O 7 9 5 9 9 4 6 0 9 8 8 5 6 9 6 5 RF F H 5 3 4 9 8 8 4 3 8 0 2 t 5 2 7 0 I SE I 6 2 0 4 3 6 0 3 9 4 8 2 3 6 4 SA R IR. 7 8 4 3 89 4 9 9 5 1 4 5 1 0 m 1 9 NRd l SO 9 7 9 8 0 3 9 4 5 5 0 1 5 7 9 9 O CAA T R R.. A 9 1 1 1 3 1 8 8 2 5 2 3 6 8 1
&AE I .
DP S M RCf EI f E M S 0 8 9 0 0 2 0 5 0 5 9 9 2 7 5 6 INOH I 0 9 2 4 5 8 5 9 0 6 2 2 7 9 7 8 NG S 0 9 3, 0 0 9 7, 5 8 4 7 0 9 0 . GOl YO 4, 8, NCt e RC 0 9 9 2 4 3 6 8 4 9 4 6 9 8 4 9 IE O 2 6 7 6 2 0 4 9 4 4 4 1 3 8 4 6 E I .. 7 5 8 7 9 0 7 8 4 9 8 2 8 0 9 8 DYw fGM i R CP. Al 8 7 l 5 2 6 4 4 8 0 9 9 0 0 Fu. I 0 5 1 8 lNN5 U( 8 E 8 fo. . 1 2
. ) T S S P L L S I O S O S
. S + U R M T R M I N. N O T E N P T E N O ( .
G E N T E I N T E l V . S G N O I M U O I M i L S Y N l I C P O C P P Y S I t N C I E C I IP . P T S S O A + S U R + S U S R U N S N L I Q 0 T I Q I S E S L E A P N M N N M S C. S. M N O C t i O f 1 A S S A O E A E M P A O O R l I T R Y Y L I T I R9 8 D. . A ( S N l s t R I C R P L f O I l A N A N A E N S S P T A N A N A T/ I . T O O S u C T L L E G . R T L L S9 O0 C N. U O.
. S R
l i P E T A D R E T f E A N E P P G N I T A R U N E P P 4 Fl A S R R M R R E S E T M E E C A O 0 t U A A U O O N N t t U N N C E f G W E R R I I I E R R I 4 A L S C N E L E T C C B O D E T B C S A I F O C t i S A A R N E H S R Rit u S f A A A u t N E E U O E T N U U _ N N R M S R N O I R R T C F O I T I E D . - O . C . T 3 8 O. N. N3 . . A I A l f L C O O 1 2 ~ 4 5 6. 7 8 8 3 4 5 6. 7 P C 2 2 2 2 2 2 2 2 2 2 3 3 3 3 3 3 3 A 2 2 2 2 "! 2 2 2 2 2 2 2 2 2 2 2 2 2
1 (
- f g *
- e e M M e w & N e N w w n @ @
* @ @
- N N m w e @ @ e e C O @ F
* @ =
- v. W. n. @
- e e . . . . N. . n. N. N. e. .
% Je* * @ @ @ M. @ @ m n e - W @ M O. =
w
- 4=
- O w m m
- e
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V N mee Q
- w w
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4 *% QQ* . v. c. e. C. o. e. e. . e. . . . . . O.
& e = U ** e M
- N @ M M n @ = * @ M w m v Q * *
- N @ ~ N n @
m * *@ 4
- 1 M
>* N M M M @ @ * @
- M w w @ n
- N e* O e M & w * @ = * > W = M w e M c*
y*
- e. w
- e. n. e. Q
- v. n. e. M.
. . . @. O. .
w
- m @ c. = = N O @ m * @ m w m @ m.
>Je w N m *
- M N w a w v. W mO M o
=g *
- M M N @
p=* M. M. M. =. M. Q. N. . g* n e M = = = = = w* = C
=*
- t o 1*
U *
- c 0 o m m e e e m
- M @ m m n e >
- m @ e e n m w e @ @ ~ w o n m o
- e* *
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C wve C e *
- n e. > w w e w C @. M C. e
>=
=U
= *
=@
- e a w e
- O e e @ m @ e o @ C m
- N M e *
- e O *
- e w n 4 eC* . n. O* * * = * + @- *
- ww e*
- N N n M* N w @ = @ M
- M3 d e *
- M, *
>4 se n 0: 0
- e 24w
=
a mg eCG UCW . . . . gwd w# * * .. I E E I. I I. I E E E E E E E E I
- c am w _g ' e e @ o = e n e e n n n e n n mes
. y ee ~n ~n *n e
- e e w < = o
- w e ~
e43
= *
=3* O s
O e M M O
~
e c m e e wo m e n n n O n e @ M M (\ 2CC C v44
=
WC* c* 4
- O w = N
*
- e
@ w e
e N @ N n
- M
@ h
=
w M w c w
-g so M ed.
- CL M 2 RUw w==
w3 @
- mO @ @ w C e N % % @ m N W
=q-2 **
e* e
- e* n w * *
- e* n Om
- w e $ =3 wee c. e. n. e. e. e. e. e. c. e.
2v ww au* O
- w
?
m C
.m e e O
n C hm O
@ e & M
. M.
=
w
@ @ @ C M m e M T
=
- gg
- e. e. h.
e Q N * * = g>3 N. M. C. M. N. . . . . wc3 4- * @
-O
= @ N M = = e e *
.a w** . e. = w
-we 22c 5*
w* M Owe *
- e e
a L @
= >
* =2
- e 2
Co a z oZ y 5 e> w e w
=*
w *
= = & W M = U 3 Q G = = &= 3 2 w
=to* O . =
- w > w 7 e w M*
w - 3 3 5 w
= a w
3 w
=4 a x w =
y e w 1= a.
= = 4 2 e
=
e s e w * = c ee v
- 3= o = z e 5 " - v 4
C= m* =
> e 6 = z C r :C . w 5 4 C* w *
- 4 = 4 w w >
e
- 3 0 2 m = w = @ =
O
>N =* 2 w 2 w U Q e*
- W >
4 4 = > 0 2 e J w 4 4 3 U = w 4 2 4 w 4 C S CO + w C = a U a *2 v == s a v- 2 = v
- g 2 E * = d = C I & 3 O C U* . C . U e 2 C Z e = 2 4 W* W = u w 2 = 0 =3 3 - -
U 4 4 4 * = = * = 0 w U Z Z Z U O 2 4
* = 4 = 0 w w e
- 3 = 3 4 w C 3
a 4 3 2 2 Q 3 a vw = *
- e e @ E w
= 3 = = 4 C w
k w = 4 y w I e X X > U
- e >*
-m go ze e
< =* , . . . . . . . . . .
J U* = n M w c @
- n M V = N 4 U *
- w w .w w w w @ d @ @ @ @ @ @
4
- N N n n n h n h n n N N N n N
.- - . . . ~ , . _ _ . - -
p., ' ' UNB1EO ENGINEERS & CONS 1RUCIORS INC. SLMen4ARY PAGE 5 PLANF CDOt COST BASIS ENERGV ECONOMIC OATA HASE ( E E Dit ) PitASE IV 3.18 09/8s 858 MWE HI CJi IEMPERAIURE CAS COOLED REACIOR-SC 08/29/88 FACIORV SITE Si1E SITE TOTAL ACCI NO ACCOUNI DESCRIPflON (OUIP. C0515 LADOR HOURS LABOR COST MATERIAL COST
.......... .......................... COSIS 999. TEMPORARY CONSTRUCilON FAC 2282763 Mil 40.267.400 34.576.850 48.844.250 912. CONSIROCilON TOOLS & EQUIP
- 350595 MH 5.896.464 28.626.300 27.522.764 913. PAVROLL INSURANCE & TANES 45.852.940 45.852.940 994 PERMilS. INS. & LOCAL TARES t.839.600 9.839.600 995. IRANSPORTATION 91 CONSTRitCilON SERVICES 45.852.940 2633358 MH 37.473.394 33.033.300 115.659.554 929. '
DeOME OFFICE SERVICES 164.242.1&) 164.242.100 922. ItOME OF F ICE O/A 7.927.340 7.127.340 923. IlOME OFFICE CONSTRCIN MGMI 2.582.950 2.5f2.950 92 ItOME OFFICE E NGRG. & SE RVI C E 173.882.390 173.882.390 939. FIELD OFFICE EXPENSES 6.036.990 6.036.980 932. FIELO JOB SUPERVISION 61.744.870 61.744.870 933. FIEtp OA/QC 5.638.985 5.638.985
~
934 PLANT STARTUP & TESI 3.976.500 3.976.500 93 FIELO OFFICE E NGRG&SE RVI CE 78.360.355 6.036.980 77.397.265 TOI AI INDIRECT COSIS 290.395.685 2633350 MH 37.473.394 39.070.210 366.939.209 9 TOTAL BASE COSI 631.537.052 16880830 Met 248.749.486 I40.723.847 1.021.010.385
( Effective Date - 1/1/ 81
~
TAELE S-6 ENERGY ECON 0tiIC DATA BASE (' , 1139. %'e PRESSURIZED WATER REACIOR hTGS CAPITAL COST ESTIMATE S-19
- _ _ . -__ ._ . . - . _ . _ . _ _ . m . _ - _
- y. m
=
tJNIIED E NGINt ERS & CONSIRUCIONS INC. $UMMAlif PAGE t PLANI Copt COST BASIS INERGY ECONOMIC DATA HASE (EEDR) PHASE IV I48 09/89 1939 MwE PRESSURIZED WAllR REACTOR 08/21/81 FACIORY Silt SITE SITE TOTAL ACCI NO ACCOUNT DE SCRIP f lON EQUIP. COSIS LABOR 610045 LABOR COSI MATERIAL COST COSIS 20 LAND AND LAND RIGHTS 2.750.000 2.750.000 28 STRUCIURES + IMPROVEMENTS 7848603 Me 446.499.285 9.788.599 61.794.246 188,075.130 22 REACIOR PLANI (OUIPMENT 176.843.095 3057013 Me 59.529,875 14.316,087 242.688.987 23 IUROINE PLANT EQUIPMfNI 835.678.569 2682179 M4 43.238,848 0.846.075 187.756,492 24 ELECTRIC PLANI EQUIPMENI 24.870.073 243293 M4 34,846.182 10.947,962 69.964.217 25 MISCELLANEOUS PLANI EQUIPI 18.460.093 522197 MI 8.762.679 9.725,269 29.948.048 26 . MAIN COND HEAT REJECT Sv5 22.553.618 490546 M4 7.678.298 8.974,964 32,206.873 TOTAL DIRECE COSIS 390.487.040 16673839 Me 262.548,867 102.354.533 745.389.740 98 CONSTRUCTION SERVICES 55,663,543 2809375 Mt 44.838,013 37,364,800 137.t66,356 92 HOME OT F ICE ENGRG.&SE RVICE 872.tt8.650 172.It9,610 1 93 FIEEO OFFICE ENCRG& SERVICE 77,674,740 3.058,950 80,693.690 IOIAL INDIRECT COSTS 305,449.893 2009375 M4 44.838,083 40.383.750 389,979.656 4 TOTAL BASE COST 685.936.933 194832O6 Me 306.686.180 142.738,283 1.435.361,396
'. . _ _ __. _ ~ . . - . _ . _ _ _ . . _ . . _ . ~ _ . . .
__.-.___,m ._ . . . _ . . _ . - - . . _ . . _ , _ . . m.._ . . . .. . _ - . . _ . - _ _ - _ . _ _ . . ~
,e-~ . %
I O 1 I f r t#JIIFO ENGINFERS & CONS 1RUCTORS INC.
SUMMARY
PAGE 2 ' PLANT CODE COSI RASIS ENE RGv ECONOMIC OA14 GASE ( E f t:0 ) P90ASE IV ' 148 09/89 1939 MWE PRES $URI7ED WATER REACIOR 08/21/89 FACIORY SITE SITE SITE TOTAL ACCT NO ACCOUNI OESCRIPflON Em88P. COSIS LAftoR HOURS LABOR COST
.......... ........................., MATERIAL COSI COSTS
+
20 tAND AND L AND RIQ115 ' 2.750.000 2.750.000 i i 1 I 4 l i a i 1 I i ) i i i e
rr 'h t 18NI I E I) F NGINE E RS & CONST RtJCIORS INC.
SUMMARY
PAGE 3 PL ANT CODE Cost BASl5 ENERGY ECONOMIC 041A HASE (EEDH) PilASE IV 148 01/89 1939 MwE PRE SStfRIZED WP .'ER RE ACIOR 08/21/88 (ACIORY SITE SITE SITE TOTAL ACCI FJO ACCOUNI DESCRIPflON EuulP. COSIS LAHOR tt0 HRS LABOR COST eeee. eees ...ee.... MAT E RI AL COST COSIS eeeeeeeeeeeeee s ...eeeeeeeeee eeeeeeeeeeee eeseeeeeeeeee ...eeeeeeeeee seeeeeeeeeeeee 288 VaRowoRK 247.750 667506 Met 8,969,892 6.905.300 16,922.872 282. RE ACIOR CONT AltJMENI DtOG 4.375,3'I4 2473946 Mt 37.976.338 20.589.210 62.940.882 243. TURSINE R o0*G + etEAIER 11Av 651.662 600763 Mt 9.094.360 to.236.2G6 19.982.288 214. SECURIIY DulLDING 46.994 50478 Mt 750.t25 379.963 0.177.082 285. PRIM Aut 64DG + ltJNNE L S 847,670 746670 Met 10,996,193 4.826,287 15.970. ISO 296. WASTE PROCESS BUILDitJG 249.024 723879 Mt 90.547,083 4,105.523 44.888.630 207. 'UEL STORAGE ntDG 859.545 347346 Mt 5.346.144 2.3t6.690 8.522,379 218A. CONIROL RM/O-G BulE DING 1.4R5.754 950238 Mel 84,065.365 5,04t.222 20,592.341 2988. ADMINISIRAf!ON6 SERVICE RLG 834.885 285722 MG 4.428,895 2.698,483 7.955.183 2980. FIRE PUNP IIOUSE . It4C F NDINS 32,684 16488 Mt 247 ti4 149.436 399.234 298E. EMERGENCV FEED PUMP BLOG 32,140 219 885 Me 788.495 3.032.4t9 3.853.054 218F. MANWAY IUNNELS (RCA f utJL S ) 2.457 50949 Mt 730.877 216.298 949.625 218G. EttC. Tut 4NELS 4.449 560 Dec 9.452 3,732 17.633 21880 PJON - E SSE N . SwGR BLOG. 18.586 22206 Me 325.245 184.234 528.065 288J. MN SIEAM + FW PIPE ENC. 10,310 254105 MI 3.080,499 0,533.357 4,624,158 218K. PIPE TUNNELS 26222 Me 379,382 925.089 '504.471 298L. IECar4ICAL SUPPORT CENTER 42.303 28668 Me 433.408 205.733 681,444 2tBM. livDROGEN RECOMBINER SIRUCT 3.678 9536 M4 936,791 64.993 205.455 2 tap. CONT AIN EQ NAIC64 MSLE SHLD 84565 Me 208.295 44.950 253,245 e 2185. 6N)tulNG POND 12248 Mt 174.520 57.490 232,080 298T. ULilMATE HEAT SINK SIRUCI 36.388 379673 Mt 5,397.006 9.978.974 7.412,368 218V. CONTR RM EMG AIR INIK SIR 45657 Mt l 207,050 62.598 269,568 28 STRUCIURES + IMPROVEMENIS 9,789.599 7848603 24 106.499.285 61.794.246 188.075.130
I v
- m e e m e > w - m e - - e N c n e > 0 C e m e e a w m e e c - e
- e. n. e. m. e. m. o. m e
- O. e. m. O. N.
- n. . e.
N ae* O. e m m O e N e M e N e = @ = @ @ w o N
* (=
- e
-e*
e
- e > N e e o e o m - N & c c m e ~ m
- e. e- e
- w e - O
< N Oc* * - * - - o. - v. O. e.
- e= &.
s e =ve e o e -e- -e e O N e N c m w e- N e > 0
- N m -
- O N N N e
> * - N = =
2 * , 4
- I3
- e
=*
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Ol S R RCU EIS E MS S. 3 3 0 0 0 0 0 0 0 0 3 3 T . 4 4 4 8 1 2 9 3 INOENR S 5 5 9 91 2 6 1 9 8 1 8 7 4 8 9 COP NC YO. RC. 3 3 5 4 2 8 9 7 5 4 9 6 I EE O 6 6 6 4 0 9 9 3 4 7 4 3 W I 6 6 6 9 5 9 9 7 9 6 4 9 DYM CP. . fG AI . 5 5 2 6 2 2 7 5 3 7 5 5 l R9 F U 5 5 6 7 6 7 0 8 i f3 Q 1 1 3 6 NN9 E UE1
. C P S T E E
. A I S E M C C
- . F U E X G I I - Q x A M V V N N E A B R R - O O T S N E S N E I B
& L E S I S E D T S S I I & A C E C S I S & T C S C I C R &. N S E G S P.
I U L E O V I I G E I I R O S R R D C L R V S R P V G C I I D N f R A N G X R & N T S C. S. S I A & N S E / O N E E E T S A E N e R O S 0 C E P P C O H9 D O W U . I N E U U E E C 8 C f S S I O E E E E C S C I C R I / T . l N N A l C C C C I Q R I I E S1 N Y i I I ( l I I I I F 0 / A F D S O0 U R C . R C F F F F F 0 A T F N A C O. A U L S O U F F F F O J Q S O I B C. R R L T P R O O O O C O I O I S T D D D T D L L A P S R M N S E E E E L L L N L A A
. M N V R A N M M M M f E E A I I T
. I O A E R O O O O O i I I L I C O
. I C P P I C H H t I H F F F P F I T E
O . D . C 8 T 4 M.. P N9 _ A I . , . . . . . . . . . - L C 1 2 3 4 5. 1 2 3 9 2 3 4 P 1 9 9 6 9 9 2 2 2 2 3 3 3 3 3 _ C. A 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 - { i . 1i
( Effective Date - 1/1/ 81 TABLE 5-7 - _ _. ENERGY ECONOMIC DATA BASE k 1260 MWe PRESSURIZED HEAVY WATER REACIOR NPGS
. CAPITAL COST ESTLVIE ,
?'
5-20
( < = . m = N e O e = w 0 C w e e n = @ m @ @ c O N * @ w e @. e. @. O. m. N. , n. @ w s see e m
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e
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=N =
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Z g a = = = C e v 5* = = . - Q w w 2 4 v* w = = c C m -C o - e ye
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4
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e ~~ % UNI f f 0 ENGINEERS 8 CONSYRUCTORS INC.
SUMMARY
PACE 2 PLANI CODE COST BASIS ENfRGV ECONOMIC OATA OASE ( E f tb8 ) PetASE IV ! 165 01/88 1260 MWf PRE SSilullf 0 teF AVV W4tfR REACIOR 08/21/89 FACIORY SIIE SITE SITE TOTAL ACCT NO ACCOUNI OESCRIPflWJ EQUIP. COSTS L ABOR 4 00RS LABOR COST MATERIAL COST COSIS 20 LANO . L A ND R I G8 ti S 2.750.000 2.750.000 298. VARDWONK, 247.099 658506 Mt 8.817.897 6.357.097 15.422.083 282. REACIOR CONIAlHMENI HI DG 3.762.095 3029570 Met 46.876.940 24.839.568 74.777.796 293. IllRHINE ROOM + ttEAIER HAY 764.583 695773 MH 9.346.279 10.856.772 20.967.626 284. SEtuRITY eultOING 46.994 49903 Mit 742.968 374.463 1.164.418 285. RX SERV.& F.N. BUILDING t.109.428 885H034 Mi t 15.355.256 5.6t7.899 22.073.883 296. D20 UPGRAOING TOWER STRU.CT 132.171 929424 Mit 1.743.575 I.435.907 3.388.653 2184. CONTROL RM/D-C BUILDING 1.687.444 1048838 Mil 15.357.295 4.536.220 28.580.956 2888. ADMINISTRATION *WAREl80USE 797.974 284 799 M60 4.406.060 2.692.620 7,896.654 218C. COMP COOLING WATER BUILD. 290.584 235828 Me 3.457.474 8.641.046 5.399.034 2180. FIRE PUMP 980USE.lNC INOINS 27.349 16301 Mt 244.992 919.072 390.533 298J. PENEfRAIIONS HUILOlHQ 106.274 215299 Mi t 3.000.757 9.972.477 13.179.508 218K. PIPE 10NNELS 26222 Me 379.382 125.089 504.471 2081.. TEcleNICAL SUPPORT CfNTER 42.303 28668 Mit 433.408 205.733 681.444 2085. 680tDING PONO 10125 MI 142.990 47.090 990.080 2tBI. Ut.flMATE ttEAT SINK STRUCT 36.381 320392 Mit 4.558.558 4.744.540 9.339.479 288V. CONIR RM EMG AIR INTK STR 95657 Mit 207.050 59.335 ' 266.385 289. AFI 987.000 795000 Mit 11.694.000 7.469.000 20.000.000 29 SIRUCIURES + IMPROVEMENIS 9.959.526 8630323 WI 826.093.186 81.093.228 297.145.933
a
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m N IJNIIFO E NGINEERS & CONSTRUCIORS INC,
SUMMARY
PAGE 4 PLANT CODE COSI HASI$ ENERGY ECormMIC OATA OASE (EEDH) Pe tASE IV e65 09/88 12fO MWE PRE SSilRIZED etT AVY WAIE R RE ACIOR 08/21/89 FACTORY SITE Stif SIIE TOTAL ACCI NO ACCOONI DFSCRIPIION EQUIP. COSTS LABOR llOURS LABOR COSI M41ERIAL COSI COSTS 241. SWi lCl#GE AR 6.650.459 98993 Mit 1.604.242 157.183 8.498.884 242. STAllON SERVICE EOulPMENI 19.398.794 15888n Mit 2.541.995 383.983 14.317.692 243. SW I IClaOO AROS t.152.646 87318 Mit 284.188 101.465 1.535.229 244. PROIECIIVE E QUIPME N T 193377 MH 8.852.79G 608.465 2.4Gl.269 245. ELECI.STRUC
- WIRI NG cot 4INR 913685 Mil 14.795.820 3.066.434 17,862.254 246. POWE R & CONIROL WI R I P4G I.258.685 8052525 Mit 67.200.'362 7.898.567 26.350.614 249. AFI 2.594.000 299000 Mel 4.856.000 9.550.000 9.000.000 24 ELFC1RIC PLANT EQUIPMENI 23.040.504 2653636 Mit 43.132.333 13.766.097 79.938.934 251. IRANSPORTATION & LIFT EOPT 2.696.574 42216 Mit 710.126 880.922 3.587.622 252. AIR. WATER
- STEAM SERVICE SV 9.762.770 524048 Mit 8.833.283 0.275.223 49.879.276 253. COMMUNICAT IONS EQUIPMENT 2.242.548 476460 Met 2.883.703 489.262 5.615.506 254. FURNISHINGS
- FIX10RES 4.181.298 81384 Mit 176.768 29.620 1.387.686 25 MISCELLANEDUS PLANT EQUIPT 85.883.183 754908 Mit 12.603.880 0.975.027 30.462.090 268. SIRUCIURES 140.530 163374 Mi t 2.372.947 9.673.558 $.687.028 262. MECllANICAL EQUIPMENI 37.025.603 e 402797 M18 6.580.798 928.372 39.534.766 s
26 MAIN COND itEAT REJECT SYS 32.166.133 566971 Mit 8.953.738 2.101.923 43.229.794 IDIAL OIRECE COSTS 47G.141.780 18 832632 Mit 283.205.445 424.760.029 884,107.254
,- . 'N UNI TED ENGINE ERS & CONSTRUC TORS IP4C.
SUMMARY
PAGE 5 PEANI CDOE COST DASIS ENERGV ECONOMIC DATA DASE (EEDO) Pila S E IV 865 09/8s 3260 MWE PRESSUR! LED HEAVV WAIER REACIOR 08/21/81 FACIORY SITE SITE SITE TOTAL ACCT NO ACCOUNI DESCRIPTION EQUIP. COS I.S LABOR 9000RS LAROR COSI MATERIAL COST COSIS 911. TEMPORARY CONSTRUCil0N FAC 2568388 Mit 40.179.436 12.487.200 52.666.636 982. CONSTRUCTION TOOLS & EQUIP 396266 Mit 6.898,203 27.200.800, 33.399.003 983. PAVROLL INSURANCE & TAKES 59,819.315 59.899.385 994. PERMIT 5. INS. A LOCAL TAXES 998.250 998.250 915. TRANSPORIAllON 98 CONSTRUCIION SERVICES 59.889.315 2964654 Mit 46.377.639 40.686.250 146.883.204 929. 5 0ME OFFICT SERVICES 873.595.070
- 173.595.070 922. DONE OFFICE 0/A 7.453.600 7.453.600 923. I TOME OFFICE CONSTRC,IN MGMT 2.498.650 2.498.650 92 It0ME OFFICE ENGRG.& SERVICE 983.547.320 183.547.320 93a. FIELD OFFICE EXPENSES 3.527.150 3.527.950 932. FIELO 000 SUPERVISION 73.198.690 -
73.991.690 933. FIELD OA/OC 6.204.880 6.204.880 934 PLANT STARIUP & TEST 4.023.250 4.023.250 93 FIELO OtFICE ENGRGASEkVICE 83.489.820 3.527.150 86.946.970 TOIAL INDIRECT COSTS 326.786.455 2964654 MH 46.377.639 44.293.400 497.377.494 TOIAL BASE COST 802.928.235 2 0097286 Mit 329.583.064 168.973.429 f.300.484.748
l
~ 1 I
Effective Date - 1/1/81 TABLE 5-8 ENERGY ECONOMIC DATA BASE ( 150 MWe HIGH TEMPERATURE GAS COOLED REACTOR-?ROCESS STEAM NPGS CAPITAL COS5 ESTIMATE e 9 4 w a 8 * % 5-21'
. E m.
t 0 2 4 8 3 3 8 6 2 2 8 2 8 0 0 1 8 9 8 9 5 5 3 6 5 0 9 . 0 9 3 3 5 9 6 6 2 0 8 9 8 8 . .
/ LS 0 9 4 5 3 6 7 7 4 7 5 7 4 E 9 AT 5 3 3 6 5 8 6 2 9 8 7 5 8 G 2 TS. 7 9 8 0 6 3 3 2 9 3 6 0 2 A / OO. .
P 8 TC 2 3 4 8 9 4 7 0 2 8 6 8 8 0 3 9 6 5 1 8 9 5 6 9 9 Y . 1 8 4 1 3 7 R . A . M . e e p S T 0 8 8 8 6 3 7 0 0 6 6 6 S 0 5 3 0 4 9 2 7 0 2 2 9 O 0 7 4 6 6 9 7 1 8 8 9 0 . C . . E 0 7 9 8 7 8 8 9 9 6 7 9 T L 5 3 2 2 6 9 4 6 6 8 4 0 _ I A 7 5 4 0 8 2 5 4 5 9 7 2 SI . . R. E T .
. 2 4 4
5 1 4 3 1 1 2 8 5 2 5 0 3 3 1 9 A . M. 5 2 6 9 7 5 5 6 2 2 8 P 0 6 6 9 3 9 9 6 6 5
- i.
S. 7 6 1 5 9 3 2 8 8 1 R O . . O tC. 6 4 2 3 0 2 0 5 5 6 VI t l 5 3 3 9 8 3 6 5 5 8 I C i j 2 2 8 9 8 3 4 6 6 t A S0 . . EE 8 4 5 7 9 5 2 5 9 9 7 A
.SR l
A L. 8 2 1 2 6 1 3 3 9 1 CiD NPE ' I L
)
O SOO RDC O( S t t 4 t 4 t H t t t e e 4 e 4 s s e et e I fS C(A R. I M. s D D 8 e a M s s O C N . 4 2 0 9 6 0 3 2 2 3 RE E 0 h t 7 0 9 3 7 6 3 I SE T I . 2 7 4 6 3 G 0 4 68 2 SAR I R 4 0 5 9 8 5 4 8 4 2 NSU O T SO. O. 9 6 5 4 8 0 8 4 4 3 4 0 6 6 3 2 3 2 0 9 CAA A 5 4 0 1 0 2 2 2 T R L . 9 1
&AE .
DP S M RCf EII F M 5 2 0 9 O 3 6 0 0 2 2 4 4 N1 s 1 4 1 f
- 8 5 9 9 3 4 6 5 I
GDl do P 5 . 4 2 5 3 9 6 6 5 0 7 3 5 T 0 . NCti RC. 5 0 4 2 6 6 6 6 7 9 3 9 FE O 4 7 0 9 0 8 0 7 8 8 5 5 f I 1 4 2 7 2 4 3 7 3 4 6 9 DY w CP. . f GM At . 5 3 6 5 7 4 2 5 8 8 5 7 f R F s . 5 4 1 3 3 5 6 5 8 0 tu 1 2 2 int 5 4 f 8 a f l t E 1 .
. E E
. S 5 C C I V I l N I T S V v N.. E N N R R S
O. I M t v E M E M P I C E E 5 E S S T P P I E C 4 A T P 5 O I l a t J S I G S I . l e R U t O P E I V G R O 5 R P Q O ( l R S R N G C 1 C. G M E E u O E G N T 5 5 I I T O T C S N E f S 4 f R I I N E A E C O 1 4 & N N N ( 9 O. O A A A L I E H T C O E E C E R C _ I / I N S L t P N E I C I I E S8 A E P P A O R T I F D S O0 lN t R C L N I C F F N A C fO. U R E I P O D U f O I B C . I O N R C R O C p C. A ) a U I C l i f 1 C C ft L A I S F t L A L A
. p R A 7 f E 5 l I N M
)
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= -
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2
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= w 4 g 3 o { C e
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- o e o a c e
a I
.: e a m-
-N e-e c
g. g
- - c .
O S
-2 g
a o o o e 2 a w
- > p w
m - o w e w w
+
2 z w w g e =o w O e e
< u g u O a e 4 - 3 w w A J & 2 w OO a Y > 4 a o . I e C e X w a u 5 a a w - - - - a e 3 4 w 3 2 2 4
C - w 3 u + C C - a e ue 3 - 2 U O a 2 L E 3 U Q =U Z d E - g o a a = - e =a a v -3. 2- s -
-3 C = -Cx w a-3 s x w ew .- - -4 . g= - I a
?
- 4 4 w 0 w 4 w a 2 z v s - s a
- w > a = 4 - 4 C Q w Q J - -
W 4 X - U < w I E o 3 Y U = - 3 Q e be e.
-n 2 2n . e .
. Qa we e s
g U*
- g. O
+
- n n
=
= ,. e e ~ 4 e Ce w eI- -
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'N 4
DNS I f D E NGit4f E RS & CONS T RUCIORS INC. SUMM4RY PAGE 3 PLANT COOf COSI BAS 15 tHfRGW ECONUMIC DAla BASE ( E f De n s't4A SE IV . 325 09/89 150 MWE tilGe IEMPERATURE CAS s'UOLED REACTOR-PS 08/28/81 FAC1DRV SIIE SifE SITE TOTAL ACCI NO ACCOUNT DESCRIPilON EOtilr. CCSIS LAP.OR HOURS LA80R COST MATERIAL COST COSIS 220A. PA)Ci t AR SIEAM SUPPLVlNS$$) 123.228.000 823.228.000 2206. NSSS OPTIOrds 228. REACIOR E QUIPME NT 460.498 623853 MI 10.4G7.437 83.275.176 23.903.039 272. MAIN HEAT IRANS SVS. l.447.299 878 86 Mit 1.539.652 953.400 3.932.288 223. S AF E G AAROS COOL . 515. 3.622.309 869556 seet 2.862.089 323.579 6.807.969 224 RAD WAStf PROCESSING 2.340.632 '73058 MI t.232.640 95.932 , 3.669.404 225. PA>CL E AR f ui t. HANDL ING + SI 4.533.255 74674 Me t.020.756 89.672 5.643.683 226. OlHE 04 REACTOR PLANT EOUIP 92.858.288 246389 Mt 4.653.552 9.068.930 18.080.770 227. INSIRUMENTAllON
- COrdiROt. 4.534.289 9 57883 Mt 9.992.869 60.072 6.507.230 228. REACIOR PLANI MISC liEMS 444.800 847548 te l 2.353.679 363.475 3.169.946 22 REAC[OR PLANI EQUIPMENI 153.470.200 95407k2 Me 25.234.666 85.429.438 194.934.394 238. IURillNE GENERAIOR 89.695.786 288G66 M4 4.526.849 f.192;999 25.4t5.626 233. CONOfNSING SYS. 1.789.739 198469 Me 2.023.307 343.935 4.956.999 234 FEEO HEAT. SYS. 6,509.277 869220 Mt 2.870,t94 320.556 9.700.027 235. OlllE R TORR PLANT EOulP 97.3R4.015 377538 MI 6.335.999 964.519 24.684.525 236. INSTRUMENTATION
- CONIROI. 825.732 70957 Mt f.959.391 567.909 2.545.024 237 IURnte4E PLANT MISC ITEMS 60628 Mt 924.437 638.698 f.563.835 23 TURBINE l'LANI EQUIPMENT 46.204.549 0065470 MI 17.832.t69 4.028.608 68.065.398
- l. , e e n n n n a e o nM - @- e - n . . .
e e e m e 9 n - N - a m e e
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=Je mg e M
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n e n e T R e e n e e
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n
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% b = go M M 9
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- e* n n - - M v v a ma
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{29 we
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5 g -a
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=
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=
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=
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. . e
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o = a
> v u
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= =
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=
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a
=
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z e : a m - E o U* U a a
=
s e 3 * = z4 v
= U J 4*
e
= = = =
- 4 = c Q
w w 3 U w Z e = E Zm U. e 3 % y 2 4 a = e 3 = e, e e a 3 m a w C s w
=
a -4 2UC
=
3 w
=
I
=
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=
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=
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4 e n n n n n n n n a n n n n n n
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e n. v - *
- e. . O. =. Q . n. @
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* % OC* * * *
- Q*
= =
M
= n 9
e e* O* N L e =We* M M e N O e n e O N O M* e e e Q M N M @ @ W O e *
> + - - @
G e ! M e e e I a e
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Qe . e. . C. w
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2* M M @ W we
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= o M =
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- c. We @ e c g Co M. . e. e.
C wWe M N e e e
>- = * @ e e e
=v ==. e. e.
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=
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e o- I 1 auw w== t
.s W. o o o n n n O o n 2
=
0 e 2 @ n n @ M = - e , e c g = no e. e. n. e. . o. o. n. e. n. M. e.
.v- a v .s e e , * - * - o= nc e M ww w
e .
= **
~ ~ e M e e e e e c
*>3 y&* M. M. C. w @ @
mC3
. . M. N. v. e. . .
4-* @ e C e n e a O M = @. m
=3 h3* go M M d c @ e C e
. . ^3 w*
n g , { .2- 6 e U A e w w w 4 = 0 w v e w
- w w '
=
U
. 5 < = >
=
2 2 w 4 = 2 3 C O = e 2 w e 2 m e = e w
= * =
a w e >
- e w Q = e M
. e U w U e e = ,
Le g es U = U 2 2 e w M w
=
e o
-. w a e R+
Q
= = c w = = a O
= ve =
4 Q y w 2 D e Q & > C U 0 ee e =
- w a 4 2 Q x 2 e 2 =
g e O w N Q w w w e 4 C "e we C* e W Z C 2 Q e v = Q 3 -E = 2 e Q u w w 3 a L 3 w U w C u
=N Q w w w w w e U = 0 3
=
* ,e
= 2 2 4 = W W W U =
e-
). 0 m w
> = = = = = . =
= = = = = w C CC 3 2 u w w w
%. 4 w O e w w e v ..
uo a a= 8 s e 2 2 - w w . o o, o e
= w o
2
=
=
ue a = L a o C O O O 0 = 0 = 0 C C = 4 4 e a 3 2 e = w w w a C e a Z 2 > 2 4 2 I I I 1 w a w s 2 a e e w w *
= c < w a = g g ; ; = = =
4
= c
=
c w
= v c s = v . . . . w w w a w - =
8 :. w
@ Ce
=n 2e ZM e e . - - . . -
w Qe a n M w @
- N M
- N M
T
& ve * - * * =
- N n n n M M M M M
,--g---. , - - - -.n -- m , - - , - -
Effective Date - 1/1/8L
~. -
TABLE 5-9 ENERGY ECONOMIC DATA BASE {' 1457 .We LIQUID METAL FAST BREEDER RIACTOR hTCS CAPITAL COST ESTIMATE I e [ } - l l l . 5 5-22 ? - l
tstellfD ( W.INEERS & CONSIRtfCIORS INC.
SUMMARY
PAGE 1 PtANI COOf COSI P.A515 INf RGv E CONOMIC DAI A OASE (FEDU) PetASE IV 408 09/80 8457 Mwf 610t811) METAL FASI RRif0ER RfActOR 08/21/88 (ACIORY Silf SIIE Sitt IOIAL ACCI NO ACCOUNI DFSCRIPIlota EQUIP. C0585 L Af!OR SK)tfR$ LABOR COST MATERIAL COSI CO3 8 5 20 1ANO AND LAND RIGstIS 2.750.000 2.750.000 28 SIROCIURE5
- IMPROVEMENIS 83.770.448 19958848 Mt 178.795.480 10J.669,t19 295.235.747 s
22 REACTOR PLANI fQUIPMENI 5215692 Mt 87.785.238 23.897.752 438.838.704 543.444.687 23 IUROINE PL Atal E OtllPMINI 153.088.998 287d838 Mit 47.577.888 8.993.885 209.652.979 24 fifCtRIC P4 ANT EQUIPMfNI 26.426.675 2972878 set 48.228,720 15.205.838 89.5S4.226 25 MISCfLLANEOUS PtANI EQUIP 8 19.498.086 80 89 492 set 16.754.349 2.403.893 38.666.258
. 26 M A I N Cord) IIE A T REJECI SV5 620548 Mt 24.949.747 9.857.546 2.220.958 36.228.259 IOIAL lilRECf COSIS 668.465.488 24665266 Me 388.992.214 858.079.438 1.295.529.940 94 CONSTRilCilON SERVICES 82.414.480 4921442 MI 45.399,200 65.t16.800 192.930.480 92 HOME OFFICE ENGRG.& SERVICE 256.939.870 256.939.870 93 flEtD OFFICE ENGRG& SERVICE 95.286.290 3.799.400 99.085.690 103AL INDIRECT COSIS 434.640.640 4 32 0442 set 65.t16.800 49.998.600 548.956.040 IOIAL BASE C051 9.103.106,828 28786708 M4 454.109.084 207.270.038 t.764.485,180 f
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/^ ,
g PLANT CODE UNIIE D E NGINE E RS & CONSIRUCIORS INC. SucesAR Y PAGE 4 COST BASIS ENERGV ECIMN)MIC OAIA HASE (EEDS) P04ASE IV 404 Ot/u t 9457 MWE IIQU[D METAL f ASI ORI E DER REACIOR 08/29/89 FACTORY SITE SITE SITE ACCI NO ACCOUNT DESCRIPil0N TOTAL EOUIP. COSIS L AftOR is0URS LABOR COST MATERI AL COST COSIS 240. SwlICHGE AR 929999 M4 ft.990.274 0.977.39G 200.68s 19.168.288 242. SIAllON SERVICE EOulPMENT 94.276.949 159655 Me 2.556.852 398.799 17.224.084 243. 5WITCl4IDADDS t.269.066 073 t8 Me 284,938 114.289 9.6G4.403 244 PROIECilVE EQUIPMENT $93470 Me t.854.326 822.308 2.676.634 245. ELECT.SIRUC o wl R I NG CONitJR 9242438 Mt 20.092.720 4.466.744 24.479.464 246. POWER & CONTROL W I RIDJG t.591.194 03 88078 Me 29.540.008 9.210.958 32.349.360 24 ELECIRIC PLANT EOblPMENI 26.926.675 2972878 MI 48.229.720 15.205.839 89.554.226 259. TRANSPORTAllON & LIFT EQPT 3.626.978 59225 Me 869.674 78.653 4.567.305 252. AIR. WATER.$1EAM SERVICE SW 19.969.076 947002 Mt 15.070.006 2.041.326 29.080.448 253. COnceeUNIC4flONS EQUIPMENT 2.568.288 38441 MN 628.205 259.939 3.456.432 254. FURNISallNGS . FIRTURES 8.333.674 12524 pt 994.454 33.975 9.562.103 25 MISCELLANEOUS PLANT EOUIPT 99.498.006 1099992 Mt 16.754.349 2.443.893 38.666.258 269. STRUCIURES 140.530 163374 Mt 2.372.937 9.973.558 3.687.018 262. ME Ca tANIC A L EQUIPMENT 24.009.297 458974 Mt 7.484.609 9.047.407 32.549.233 26 MAIN COND flEAT REJECT SYS 24.849.747 628548 Mt 9.857.546 2.220.958 36.224.251 TOTAL DIRECT COSIS 668.465.488 24665266 MS 388.992.284 158.079.438 9.215.523.840 t l l l l -
UNIIEO (PMlNFER$ & CONSTRUCIORS INC. SL*MMAR Y PAGE 5 PLANI COOf COST BASIS ENERGV ECONOMIC OAIA Et ASE (EEO8) PHASE IV 400 09/89 1457 Mwl LIOulD METAL FAST BREEOER REACIOR 08/29/89 FACTORY SITE SlfE Site IOTAL ACCI NO ALCOUNI OfSCRIPilON EQUIP. COSIS LAl'OR HOURS LABOR COST MATERIAL COST COSIS 911. TEMPORARY CONSTRUCTION FAC 3570804 M4 56.495.520 ft.785.400 68.200.920 912. CONS 1ROCilON TOOLS & FOUIP 550638 M4 8.70s.280 32.252.550 40.953.830 983. PAVROtt INSURANCE & TAKES 82.414.480 82.484.480 984. PERMITS. INS. & IOCAL 1 ARES 8.361.250 9.369.250 995. TRAN".PORIAIION 99 CONSIRUCTION SERVICES 82.414.480 4429442 M4 65,t96.800 45.399.200 192.930.480 921. HOME OFFICE SERVICES 244.018.020 244.089.020 922. llOME OFFICE O/A 60.430.2'00 80.430.200 923. 910ME OFFICE CONSTRCIN MGMT 2.498.650 2.498.650 92 440ME OF F ICE ENGRG.&SE RVICE 256.939.870 256.939.870 939. FIEtp OFFICE EXPENSES 3.799.400 3.799.400 932. FIELO JOB SUPERVISION 89.093.130 80.093.130 933. FiftO OA/OC 8.548.650 8.548.650 934. PLANI STARIUP & IEST 5.724.510 . 5.724.510 93 . FIELO OFFICE ENGRG& SERVICE 95.286.290 3.799.400 -99.085.690 TOTAL INDIRECT COSTS 434.640.640 4929442 Me 65.116.800 49,198.600 548.956.040 101AL BASE COST I.103.106,928 28786708 Me 454.109.004 207.270.038 9.764.485,100
Effective Date - 1/1/81 1
. I 1
TABLE 5-10 ENERGY ECONCMIC DATA BASE {' 1240 We HIGH SULEUR COAL FPGS CAPITAL COST ESTIMATE s O e 5-23
A 1 . UtelIE D EldGlt4E E RS & COfJSIRUCIORS INC.
SUMMARY
PAGE t l PLANI CODE COSI OASIS ENEWGY EcoraOMIC OAIA flASE (GEORI PelASE IV 680 01/89 1240 MwE IIICJe Sulf uR COAL 08/28/89 j FACIORY SITE Sitt Slit 101AL
- ACCF Pd) ACCOUNT DEScutPflON EOulP. COSTS I Aa'tt)R #e0045 '
LABOR COST MATERIAL COST COSTS eeeeeeee.e .ee...eeeeeeeeeeeees ...ee seeeeeeeeeeee eseeeeeeeeee eeeeeeeeeeese seeeeeeeeeese seeeeeeeeeeeee 20 tAND AND tANO RICetTS 2.750.000 2.750.000 29 51RUCIURES e IMPROVf ME NIS 6.980.005 9690999 Mt 24.627.763 48.606.300 68.294.068 22 OOltfR PLANI EOulPMfNI 268.198.754 5633507 MI 93.328.249 26.729.048 380.169.043 23 IURHINE P1ANI E QUI PME N f 1867269 Me 30.950.769 IJ5.103.573 7.559.040 973.6t3.382 24 . _ELECII4IC PLANT EQUIPMENI 14.845.879 8254435 Mt 20.364.238 ft.983.975 46.394.092 25 MISCittANEOUS PLANT EuulPT 8.408.200 260822 Me 4.*342.967 0.167.146 83'.918.383 26 MAIN COND Ilf4I REJECT SVS 98.944.69'i 2RG748 Mt 4.525.929 1.569.005 25.039.629 , TOTAL OIRECT COSIS 440.394.006 10993063 Mt 178.939.907 92.556.594 781.090.527 91 CONSIRuCIlON SERVICES 36.949.770 3564894 Mt 25.440.090 27.762.900 90.052.760 92 teUME OfflCE ENGRG.& SERVICE 28.193.000 28.t93.000 93 IlELD OFFICE ENGRG4 SERVICE 29.054.520 1.657.700 30.792.220 TOTAL INDINECT COSIS 94.197.290 1564894 let 25.440.090 29.420,600 849.057.980
-s TOIAL BASE COSI 534.599.396 12557957 Mt 203.579.997 128,977,994 860.948.507 0
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= f =3 =e.
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o e = = O e O w w n e n m* gc; wo. e. c. w. . n. . e. e. n. n. n. m. e. e. n. e. m y eve a m n m e m n - n e. www
~
n mw e e m D -c . .* w e e w n e o e cw n = e O =e w O Owg uge c. e. e. e. . e. =. =. n. e. c. w'- <=* n
- e= e n. .
= 1O w* e > 0
- n e
n e = n = a n e c
= =w 5 -
n m 22n we - Ow- *
- 2 2
- w w = .
e = = = 2 0 & a o e> 2 e U = a e
- C e
- 3 a 2 3*
=*
. e =
e w > e e2 a = a= 0 2 = 2 2 w 2 w O = 2
- w 2
w Q = w Q ', >e ao a e
- g
* =
w e 3 U = 2 . 2 = v
= 2 a
1 0 L e w 2 O
=* a = e a w
- v a 2 = e l @ a. a g a > a e =- o w e a
+ e 3
- U* 3 .
Q e w 2 2 = 5 = 0 e ce e = C o = = e> ea 2 2 =
. 2 w 4
e-w* Co 2
* < c2 - - =
4 a > w o
= = =
*s e
w e o g w 4 2 w 2 2 = w e w *N< * *2 4 w 2 w 2 e C 2 2
=
=
4 2 4 2 4 e* = 2 e e
= = a Q
c = g g w c = c = a a OC -g ** e w
= 2 a a C 2 W a 2 L L u ce C
> 3 2 e< a g w 4 a - 4 3 w e C O 2 w e w V# J
= 2 m
- E O w a
3 a a w a 2 2 E n g2 w w 2 ' u. *.e e < w s w a = a w a
= w a a= = =
e w . : w : ew e = = e a q .O . : e a w e e
- C = a e = w 2 C O o w = e
- w e C < w m O = c c O
= v w 2 = 3 w Q = =
- C
- C
- v
- O ce
*- 2*
2e * -
< .. g . . . . . . .
a U* O - a m. e e e n e - m m nN m nm nmo e I a U* n n n n n n n n n N e n [ i 4 e n n n n n n n n n n N N M n M N I e
h
,/
w
- e n O~ O N m N e a w >e >we n e - e >
=
e O - v
=
mO e c- = e w n N
@ a
\ e . e. e. C. . . @. O. e. . o. M. e. m. o. O. e. e.
% Jee m e O = m e e M w 'e - e a w W = 0 w - <=*
- e O O m e e
- n n - > -
- e m e c
E N e Oge
=Us e e -
N. . e. N c. N w
. m.
e O. n e
.e C.
- e. e.
m
- m. e.
N N C. e O. O e = = w = n n = m a
- I e
=
- n - c N e e c N M e w e e m N e w e* e e w e e e > c & M M w w m N O -
C* - a - We . o. O. e. e. e. e. e. n. . e. n. . e. . O. e. w
=se
* *
- e
= -e e O m m
- N e o m e
e w w N O N n e - e
=4 *
- n @ c N O e - e e c e = ,e c.
- M N v - c c.
m*
- M e =
=
. O.
c.
- M we
- m e 4 e Io
* - O c e m - e
= e e e v v mm m n e O
- m o m e e N es *
- c c
- e a e n o
@ @ @ @ w w ce m. M. e. M. N. n. @ @
wUe
=
- e oe e C ea * -e e w w
e M. c m *
- e. e m C O -
.a .
N
. T.
O n w c. N e m
= =a* e = - w - e woo O. m. n. m. m. O. m. n. n. c. .
w ee * * @ n O n w = n w e
.e4 g e se N P
=
=
=
ec 20 . S' a. OE. o EO O.E O E. E. E. E. E. E. E. E*E. E E. E. E. E
$=
awa w }.
- m o m o owO > e m
e w
- em N N O - = m
- n v n e a w e
*eg = .
=ae n e c - N w - c > > - e = > 0 l edO n O O c = m w e n o e m O n w e n
( ZGU MO* e e - e e w c e N M e e C e e 1 O Ce c w n .- n N n O Uwe <* - O
== s. -
dew
- Ca e 3 mue w=-
wE Me n = 0 e
@ e m e O m n m c Z~
- E =G m
e O n .
~ e e e e e 8 n n e 8
- e. C. e. a. n. w -
QC2
.O
>C*
MU+ W Om e e n m e c e
- a. n. e. n.
e
- a. . e. .
www C
- e m m w O w w w
- e o e c 0 6 = w e cm3
=c 3 =
Ut e
<=*
e
- c
- e. =. c @
e. w
- e. e. - e a w
- e. e. m.
- w e e O
=3O -
- =e
==
22n s5* w.
- w Ow- e e
a = > > =
- 2 & W & & O
. 2 = 0 = 0 = >
- w 2- 2 w w 2 w 2+ E C C 3 e a
w U w e O
=Co* U 2 1 = = I w = w =
=*
= = = a w > L 2 2 = U 3 2 g a = = 3 - 3 w > 2 w
&* O w . - 3 a w 3 = I 2 w 7 e
=* w X = 3 O 0 m* e O w = g I w =
k a w d w = 4 J E E e
- U* w = = s 2 w w 4 e Me U e
=
C C-w. c.o -
> e w 33 0
=a 2
2 C
= =
4 w - a 3 e 3
-5
=
=
w U
=
m a C U 2 s = 0 =e
=N =* 2 w 3 w 3 2 C 2 U C L 4 *
- w w e J w M- Ze 4 e 4 > 3 U = 3 4. Q = 2 w
- CO 3e w C = = U m w U 5
= 4 4 a 4
O E 2
=
U C* g 2 y = e d - C = = 2 3 e U * . O U G 3 = Q C
= .U -
4 4 2 e w = 2 U U* U w = 3 = @ w se = = = = U w U 2 3 2 a
=
2 = w U V < J
* = 4 - C w 3 w e 3 2 2 4
- 3 3 a 4 2 2 2 e a U = =
e e e e
= = Q s a = 0 3 4 = = w 4 C w
L w L w = 4 U s 3 3 e 5 K = 4 5
- U
- O Q*
== ..
Ze = ,e m. d U*
- N * @ 4.
- n m w e
- M a U* 9 w w w w w w c c c c Mc c e e g e n n n n n N n n n n n n n n n
l
f s uni l f 0 E NGI NE E RS & CONS 1 RticiORS INC.
SUMMARY
PACE 5 PLANI Ct>D E COSI HA$ls E NE RGF ECONOMIC OAIA RASE ( E E De l Plea SE IV G10 01/89 1240 Mwf HIGt Sulfur COAL C8/21/81 (ACIORv Silt SIIE SITE TufAL ACCI M) ACCOUNI DtSCRIPTIGN E Qtil P . COSIS LABOR HOURS LADOR COST MATERIAL CO$t C0515
.......... .......................... ............. ............ ............. ............. .t............
911. TEMPORARY CONSTRUCTION FAC 3343098 MH 21.832.590 7.683.500' 29.516.090 912. CONSIRtJCilON 100LS & E QtJI P 225796 Mit 3.607.500 59.395.I50 23.003.250 983. PATROLL INST #R ANCE & 1 ARE S 36.949.770 36.949.770 914. PERMIIS. INS. & LOCAL I AEE S 683.650 683.650 985. TRANSPORIAllDN. 98 CONSIRbCTION SERVICES 36.949.770 f564894 MH 25.440.090 27.762.900 90.852.760 929. INMHE OFFICE SERVICES 26.699.860 26.699.860 922. 8 0ME OFFICE O/A 92:4. HOME OFFICE CONSIRCIN MGMT l.493.940 0.493.140 92 HOME OFFICE E NGRG.4SE RVI CE 28.193.000 28.193.000 939. FIELO OFFICE E APENSE S 9.657.700 f.657.700 912. FIELO 000 SUPERVISION 27.819.510 27.889.110 933. FIELO QA/OC 492.470 492.470 934. PLANI STARIUP 6 TEST 742.940 742.940 93 FIELO OFFICE E NGRG& SE RVIC E 29.054.520 9.657.700 30.782.220 IOTAL INDIRECT COSTS 94,193.290 1564894 hit 25.440.090 29.420.600 149.057.980 a 10lAL BASE COSI 534.591.396 42557957 Mil 203.579.997
, 824.977.414 860.148.507
/
.f
. Effective Date - 1/1/ 81 TABLE 5-11 t' ENERGY ECONOMIC DATA BASE-795 .We HIGH SUIJUR COAL FPGS CAPITAL COST ESTIMATE G
5-24 r- - -
I . 0 5 8 7 8 5 2 5 2 0 0 2 7
. 0 8 0 6 8 6 5 6 9 5 4 0 6 9
0 0 9 8 9 0 2 4 7 4 0 2 6 8 . E
/
LS. . 0 0 4 8 0 9 5 0 6 4 9 0 0 8 AI 5 5 8 4 8 5 9 6 9 2 5 0 6 G 2 T S. 7 9 9 3 0 3 7 2 3 7 7 9 A / OO 6, P V 8 0 T C. 2 4 5 7 6 2 3 9 0 4 2 8 7 9 0, 5 6 0 5 2 8 8 0 1 9 4 9 5 R . A M M U S I 0 0 9 5 0 3 4 0 0 0 0 9 S 0 4 3 6 2 4 9 0 0 5 5 5 O. C.
. 0 0 4 8 0 9 5 9 7 8 5 4
_ E 0 5 6 5 0 8 8 2 4 8 6 9 I L 5 8 0 2 6 8 6 3 4 9 3 G I A 7 8 0 5 8 0 2 2 4 1 6 8 SI . . ER. T .
. 2 3
2 9 4 4 9 0 I 8 7 9 1 9 0 2 9 8 _ A M
. 5 8 8 7 0 2 6 9 0 7 I 9 2 4 7 0 9 0 7 7 7 EC.
S. O 2 0 5 3 8 4 4 3 5 6 0 0 0 0 V 1 6 4 0 0 4 T 4 5 6 0 9 5 3 8 8 8 I I SO. R. B 4 5 6 7 7 4 5 0 0 6 E S 0 6 6 7 3 3 8 9 9 7 A. 2 6 9 3 2 1 9 4 A L . 3 9 Ce t NP I
)
SO RO Ot S t t t t t t i t b t t t R. i e I E Me Mi Mi Me Me M M M C( U Me M U O 8 3 9 0 4 7 9 9 9 2 RE t t 8 5 3 2 5 2 8 6 6 4 I Sl . t l 4 4 9 3 7 0 6 6 6 3 SAA iR 4 3 0 0 2 0 1 8 8 3 NBO
- O CA C SO. B.
A 0 4 8 2 0 0 4 8 1 9 0 1 2 2 2 2 7 9 8 4 8 8 0 5 1 3 9 I R L .
&Au .
Or S t RCu EI s E NtM t S I 0 5 8 4 1 6 8 9 2 4 6 6 8 5 8 0 0 9 9 I t#a S 7 4 5 9 8 3 t 8 4 4 7 9 5 9 4 8 5 8 GOl Y O. . . . NCt e RC 4 8 7 9 3 9 3 9 4 7 3 7 EE O 9 2 5 8 2 6 9 9 2 6 8 7 E I .. 6 4 1 5 6 0 4 7 OY w 6, 5 9 4 EGM l R CP. Al
# u 8 2 8
2 3 7 3 0 6 0 4 9 2 7 1 9 9 2 2 8 6 5 iE 5 O 1 2 3 NN9 f E t E7
. T
_ E E
. S P 5 C C I T I v I I N i N U S V V N E I h E Q R R D M N t M E T S E E l 5 E E M P C E S 5 S f l e
V M P l I E C 4 T O P l it N J S I S. G S IP . G R u O A l E I V G R O S R. I P u y O E L R S R R C C I C. R M E P O E G N I S S I E I T C S N E I S A E O N S A B8 D J I N E C O _ 8 t
- I A U E T N E E C A N A L O H C O E C R T / I . L S A L P E E I C I I E S9 N. E P N O R O0 U. D R L T I F D S P C A N I C F F N A C O N U E I L O O U F O I C A I R N R L C R O R, C C E I I E L 1 O L L A )
# u L O C C N A 5 E L A A
. t R I R E S I I N M E I I
. A I O 0 L I A D O I O O
. L S H 1 E M M I C eO t F I T E
D O C 0 o I 4 t N6 A I L P C. C. A 0 2 8 2 2 3 4 5 6 9 2 3 2 2 2 2 2 9 9 9
~
O 1
m t#4t if 0 (NGINF E RS 6 CON 5100CIORS INC. 5LeMMARY PAGE 2 PLANI CODE COSI BASIS ENERGv ECONOMIC DATA BASE (FEDU) PHASE IV 640 01/81 795 MWE telGH Sua f ue COAL 08/2s/89 FACIORY SITE SIIE Sitt IOfAL ACCI M) ACCOUNI DF50RIPfl0N EuulP. Costs LABOR hours LABOR COSI MAIERIAL COSI Costs
.......... .......................... ............. ............ ............. ............. . 6...........
20 LAND A ND L AND R I GHI S 2.750.000 2.750.000 219. VARDWORK 168.920 226642 MH 2.927.645 4.095.544 7.892.009 242. SIEAM GENERATOR BUILDING 549.058 498733 MH 6.167.965 12.656.073 99.365.096 293. I URill NE .I'E A I E R. CON T ROL D10 302.860 258756 Met 3.879.370 7.442.108 11.624.339 2980. ADMINISIRATION.5ERVICE RI D 242.842 62528 MH 979.579 f.940.360 2.324.089 2988. ELECTRICAL SWITCHCR UtDCS 29.993 6999 MH 108.977 59.535 997.625 288M. COAL CAR IHAW 56 tE D 2582 Met 38.298 19.590 57.888 218N. ROIARY CAR DUMP HLDG*TUNHL 5.118 43180 MH 607.523 546.526 9.959.167 2180. COAL BREAMER HOUSE 89.467 20092 MH 321.552 546.269 959.288 298P. CO A L. CRUSHER HOUSE 995.672 15224 MH 236.687 287.768 640.057 2100. Dolt ER HOUSE TRANSFR IDWER 2.614 3807 MH 48.045 891.214 161.843 288R. ROIARY PLOW MAININCE SHED 8.870 892067 MH 9.589.035 f.849.145 2.739.050 218T. LOCOMOTIVE REPAIR CARAGE 16.999 5972 MH 79.343 96.298 592.602 218u. MATERIAL HANDL
- 5E RVICE 810 20.978 10775 Mel 963.469 202.056 385.688 2tBV. wASIE WATER TREAIMENT BLDG 4.353 9313 MH 139.985 984.203 250.540 2tSW. MISC COAL ltANDLING $lRUCT 155.400 66906 MH 948.255 9.504.539 2.608.186 299. 51ACM STRUCluRE '
948309 MH 2.218.705 2.889.820 5.100.525 21 SIRuCTURES
- IMPROVEMENTS t.694.750 1404488 MH 20.440.295 32.815.040 54.950.085 l
. f
n
.e e n o n a n n n n e n n n n n e a e n - - a n e e e n.
- n. , ,
e . . . . . . e. e. n. ,. m. . e. n. e. . . w
~
- a
<-m .o e, e n o, n o e e e n n e e e e
, e e n n - n e c n o e a a n e %
-e oo e* o
- n n n - *n e* * * *
- e* e* o* *w e - - *
- o n s e nu .n n n n- n n , - n n e - e e n* n
.o .
n e n
, - - - e
- a. .
I G e - , n e e n e e e e. o. 3nn 8n = e e n - - e n, . - e e e n e e
. . . n. e. e. e. o. e. . e. n. e. e. e o. e.
.v.
na.
. n , n n n e e n n ~ e, e.
e e n
- , - e n - e e c e-. . e. n e n. n. o. 8 e e n.
n Re e n e. n e. a - - - n - e - - , w - - m.
... e e e en o n n, o n
ne - n
, e o e e n o e ~ e n e, a,
- e. 8. ne.a. e. e. o. n.
e. c . n. . e. e. n. n. e. e. wu - n n n e e e e e e - e e , n a
> - . n e n - n 8 =, n.- , e e e - n e
-a.
ec. e.
- e. n.
- n
- n
- c. e.
e
- 8. e.
n n e
- e. n.
. e.
e m... - ,- e -
. e. s.
y:
.s
+e a ,, . - . . . - - -
- " a. I I I I I -I I -I -I' I - I- I-I -I -
I I I-u- aw g. w o o a e n ~ - e e, n o, - e n e .n o e e n o n n e e n - e n
-ed
+<<
w.
=
-a n e e e e e 2e n e-o nee o- e n n
- e nn e e e e e n n e
o ^ (- 5' s u o Wo. m. n n e n n - - O N e e, e n - n o e n - - n N n n n - o ve>= <* s. n , - ed3 . Cm e a avD w-e '
-2 2--
d.
=e o
Q .n e n no e N n n e e e e e e n e
, n, n , e e n n e O e,
~IG >c e e e* n n n n*n e n - e n *n % e bC- u: au*
, e ,
- e e e e *
- n* n e
e, e e n e, n wm om D w o *. va* n e n , e e e o n e e e n @ n n n, e n e n * - m c
-os <-. e - - e* e o n n* e n -a n
=a +
- e e n. n
--e w 5" . -
g2e w n w
- I I -
e w w ~ J 6 a e
. + 2
= =
e
> 2 o u w a e - oa eI
=
6' .* e = w > e e a a c x - x w - 5 - w 2 2 w
-. + = - 2uc - - - w
- -2 u &' u 1 = I
. . > e - a a s o e b =w 5 . v s e - -
e
-. s m.
- e a w - a x - < . e e L Q s > 0 e -
o w e w - o v. e 3 . g e w - x 5 =.
=
- c 2' x w o
e.
- 7. - . w 3' 3' w e e E-w .
X e Z
; 2 e : .e = = = - - a w
n w - - - o .o
- e O 2 > 2 2 e < a = = w e e 2 2 2 2 = w e 4
*N =* w w ~ > J Q N *
- 4 w 0 - C = w a e* 2* = ^2 e e C = 2 w a 0 2 = a 2 L 4 u
Oo 6' . e - * = 2 e a w a 4 - 4 3 = C e O < g I w e w = 3 w w v a
= .
- o w : aw a
a 2 2 : o 2 2 v4 e. e I s w - = a 2 - - 4 w 3 w a C C 6 4 W ) e
=
@ - - a Q ow w =
@ a C
a
~* O
- a e 0 - w 2 O O 3 3 w =E 2 3 3 w
. w e o 4 m w o - = c - u w o - > -
e 5 . u . o co
-, 2 2@ * -
g = * * - -
- - - - + - - -
M u o - n n e- e n e - n- , e e n
& U n n n h n n n N N N n n n n n n n 4 . N n N N n N N n n N n n N n N N n
y UNiiED ENGINE E RS & CONSTRUCIORS INC.
SUMMARY
PAGE 4 PLANT CODE COSI BASIS ENE RGr E CONOMIC UAT A IIASE I E E DB ) PHA S E IV 640 08/89 795 MwE HIGH SUL E UR CUAL 08/29/88 FACIORY Slif $18E SIIE TOTAL ACCI NO ACCDONT OESCQlPilON - EOulP. COSIS LABOR hot fR S LAllOR COST MATERIAL COST COSIS 249. $WI TCleGE AR 6.929.802 57640 Mil 934.852 97.558 7.954.205 242. STATION SERVICE EQUIPMENI 5 8295 Mit 5.884.493 887.285 459.020 6.160.798 243. 5W I T CHilO AROS 687.008 9030 Mit 146.688 93.497 927.223 244. PROTECTIVE EOulPM(Ni 76400 Mel 9.258.270 8.006.365 2.257.635 245. ELECT.5tRUC +WERING CONTNR 580035 MH 8.244.748 2.755.828 90.000.576 246. POWER & CONTROL WIRING 726.088 385920 MH 6.306.704 5.747.759 82.780.559 24 ELECTRIC PLANI EQUIPMENT 13.519.499 9090320 M60 17.700.477 9.860.020 49.080.988 259 TRANSPORIAllON & LIFI E OP T. l.786.209 7200 Mil 820.577 124.396 S.960.774 252. AIR. WATER
- STEAM SERVICE SV 4.027.202 154468 Mit 2.603.594 383.30G 6.944.022 253. COMMUNICAllONS E QUIPMENT 866.889 25000 Mel 408.550 254.t35 829.574 254. FURNISHINGS
- F IN TURE S 885.290 6717 Met 103.554 22.534 8.018.378 255. WASTE WATER TREATMENT EOPT 828.960 29369 Mit 479.585 297.572 9.605.397 25 MISCELLANEOUS PLANT EOulPT 7.623.742 222754 Mit 3.715.380 0.088.943 12.350.065 261 STRUCTURES st3.059 66037 MH 969.454 832.949 f.907.454 262. MEC6tANICAL EQUIPMENT 12.956.907 153990 M60 2.495.238 435.653 15.887.798 26 MAIN COND HEAT REJECT SYS 43.069.966 220027 Mel 3.456.692 8.268.594 17.795.252 IOfAL DIRECT COSIS 290.493.558 7971689 Mel 128,534.006 71.232.908 490.260.465 l
UNIIE D ENGINE ERS & CONST RUCIORS INC.
SUMMARY
PAGE 5 PEANT CDOE COST HASIS 640 ENfRGY FCONOMIC OAIA BASE ( E E I)R ) Pe tA SE IV 01/84 795 MVE HIGH SULFUR COAT 08/28/88 FACIORv SITE Silf SITE IDIAL ACCI NO ACCouNI OfSCRIPIlON EQUIP. COSIS - LADOR POURS LABOR COST MATERIAL COSI COSTS 988. T E MPOR AR Y CONSTRUCTION FAC 002859G Mit 16.680.043 5.904.800 22.544.843 982. CONSIRUCTION 10045 & EOulP 153065 MH 2.470.028 43.055.900 85.525.928 983. PAYROLL I NSUD A NC E & IAXES 26,799.943 26.794,94% 984 PERMITS. INS. & LOCAL IAAES 484.000 , 484.000 985. IRANSPORfATION 91 CONSfRUCflON SERvlCES 2G.798.941 9080669 Mit 49.080.078 19.444.700 65.306.792 979 HOMI OFFICE SE RvlCE S 19.335.800 19.335.800 922. 8 0ME Of f lCE O/A 923. 0 0MF OFFICE CONSIRCIN MGMT f.288.650 1.288.650 92 00ME OF F ICE E NGRG.& SERVICE 20.624.450 20,624.450 938. FIELO OFFICE EAPENSES t.999.850 f.198.850 932. FIELD dOH SUPERVISION 83.600.400 93.600.400 933. FIELD OA/OC 348.480 348.480 934 PLANT SIARIUP & IEST 618.300 618.310 93 FIEED OFF ICE ENGRG& SERVICE 14.567.190 4.191.850 15.759.040 TOIAL INDIRECT COSIS 69.983.581 8888669 Mil 19.080.079 20.636.550 108.700.202 TOTAL BASE COST 352.477.039 9953342 Mit e 447.614.077 98.869.459 59f.960.667 e
P t l
~
Effective Date - 1/1/81 I* TABLE 5-12 ENERGY ECONOMIC DATA BASE.
. 1244 MWe LOW SULFUR COAL FPGS
( CAPITAL COST ESTIMATE ./.
-e e
l . i l 1 - l l \ l - l l l l 5-25
.m.
\
f a UNIIfD ENGINEER $ & CONSIRUCIORS INC. St3MMARY PAGE 2 PLANI COOf COSI BASIS E NE RGY (CONOMIC OAIA BASE ( E E Oll ) Pita SE IV 630 09/89 9244 MWE tOk SuttuR COAL 0s/29/89 FACIORY $llf SlfE Slif 10!AL ACCT NO ACCOUNI DESCRIPIION EQUIP. COSIS L an0R 1000R5 LAROR COSI MAfERIAL COSI COSIS e eeeeeeee eeeeeeeeese.eeeeeeeeeeeeee seeeees ..see seeeeeeeeee. o.eesseeeeeee seeeeeeeeeees eseseeeeeeeeee 20 t AND ANO L AFA) RIGHIS 2.7';O.000 2.750.000 284. VARDWORK 168.920 28 8920 Mit 3.620.687 5.006.475 8.796.012 292. SIE AM GE hJE RATOR BUIL DING 662.262 559029 Mil 8.390.068 18,282.482 27.334.742 211. IllRfilNE .84E AIE R.CONTROt flL D 373.486 302 953 Mit 4.513.288 8.818.575 93.725.349 2488. ADMINISIRAllON*SERVICf BLG 265.284 69093 Mit 1.0J0.044 1.2G6.313 2.605.649 2180. FIRE PUMPHOUSE 2988. ELECfRICAL SWITCHGR BLOGS 39.475 7584 MH 118.103 65.933 295.519 218L. SIACN/ RECLAIM IRANSFR TOWR 7.930 19 9G0 Mel 162.769 131.017 300.716 2tHM. CUAL CAR illAW $41E D 2582 MH 38.298 19.590 57.888 218N. ROIARY CAR DUMP BLDG *1DNNL 5.918 43989 MH 607.523 546.526 1.159.867 2180. DEAD STORAGE RECLM HOPPERS 24020 MH 346.265 279.610 625.875 288P. CUAL CRUSelER llOUSE 822.567 87619 Mit 273.125 347.495 743.887 2180. HOILER leOUSE T RANSF R TOWER 3.936 6085 Mit 94.505 294.894 312.635 298R. DEAD STORAGE TRANSFER TONL 62045 Mit 883.174 586.923 E.475.297 2889. LOCOMOilVE REPAIR GARAGE e6,991 5972 Mit 79.313 96.298 192.602 218U. MAIERIAL HANDL* SERVICE BLO 20.871 10775 Mit 162.983 202.056 385.840 218V. WASTE WATFR 1REAIMENT BLDG 82227 Met 4,353 179.549 148.877 397.779 2tSW. MISC COAL llANDLING STRUCT 4.184.000 496624 MH 2.479.184 2.457.860 5.820.974 299. SIACM STRUCTURE 87539.1 Met 2.625.829 3.406.395 6.032.224 21 SIRUCIURFS + IMPROVEMfNTS 2.866.493 1786754 Me t 25.662.497 49.568.749 70.097.739
3 tsNI s f D ENGINE E RS & CONSIRifCIORS INC. SUMasARY PAGE i PLANT CDOE CUST HASIS INENGV ECDNOMIC DATA HASE ( E f t>Q ) Pt 84 S E tv
- 630 O t/8 4 t244 Mwt tow SULFtfR COAL 08/21/88 FACIORY SIIE Siff Sitt TOTAL ACCT to ACCOUNT DESCRIPIIDN EQUIP. COSIS LABOR HOtlR S LABOR COST MAIERIAL COSI
.......... .......................... COSTS 20 LAND AND LAND RIGHIS 2.750.000 2.750.000 28 SIRUCIURES . I MPROVE ME NI S 2.866.493 1786754 MH 25.662.497 44.568.749 70.097.739 22 80lLER PLANT E QUI PME N T 229.049.289 5888970 MH 86.008.958 38.470.999 346.538.366 23 IDHHINE PLANI E QUIPMf NT 834.460.383 1867269 MH 30.950.769 7.559.039 172.970.828 24 EtECTRIC PLANI E QUI PME NI 14.669.929 1237090 MH 20.084.895 89.995.984 45.870.658 25 MISCEitANFOUS PLANT FOUIPT 8.408.200 260822 MH 4.342.967 1.067.94G 93.918.303 26 MAIN CONO NE AT REJECT SVS 18.944.695 28G748 MH 4.525.929 s.568.804 25.032.428 IOIAL DIRECI COSIS 408.398.999 10626947 MH 979.585.935 97,192.778 677.877.625 94 CONSIRUCIION SERWICES 35.704.004 8552004 MH 25.930.844 22.900.800 83.745.748 92 HOME OFFICE E NGRG . &SE RVICE 24.450.470 24.450.470 93 F IEt D OF F ICE ENGRG&SE RVICE 22.105.490 1.385.450 23.490.940 IUIAL INDIRECT C05tS 82.260.064 1552004 Mi t 25.130.844 24.296.250 138.587.958 infAL BASE CUST 490.658.983 12978959 MH 996.746.779 829.489.029 808.864.783
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=
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=
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- N N N N N N N N N n M M M M M M N N N N N N N N N N N e
v I UNII(O (NGINffRS & CONSIRUCIORS INC.
SUMMARY
PAGE 4 PLANI CODE COST HASIS INfRGV FCONOMIC OAIA RASE IEEDB) Pe t ASE IV 630 O'l/8 8 9244 MWE LOW Sul f uR CUAL 08/29/88 factory Slit SITE Site TOTAL ACCI NO ACCOUNI OESCRIPTION E Otll P . COSIS LanOR HOURS LABOR COSI MATERIAL COST COSIS eeeeeeese, eeeeeeeeeeeeeeeeeeeeeeeeee esseeeeeee .. eeeeeeeeeeee eeeeeeeeeeeee eseeeeeeeeeee eeeeeeeeeeeeee 24t. SwitCHGEAR 8.008.090 66705 MH 8.088.879 tl6.3t9 9.206.288 242. STAllDN SfWVICE (OUIPMENT 4.982.673 55006 MH 875.893 172.992 5.969.558 243. SWIICHROARDS 833.020 10530 MH 870.945 96.045 8.100.0t0 244 PRUIECIIVE f00lPMENI 73400 MH 1.202.244 0.00G.983 2.309.227 245. ELECI.%IRUC eWIRING CONINR 584900 MH 9.394.233 3.074.579 12.468.882
~
246. POWEW & CONINOL WIRING 996.94G 450350 MH 7.359.628 6.548.996 14.824.763 24 ftfCIREC PLANT E QtJIPME N T 84.669.929 8231090 Mit 20.084.895 19.195,964 d5.870.658 s 250. TRANSPORIAllON & LIFT EOPT l.882.265 8125 MH 135.742 [125.952 2.013.959 252. AIR. WATER
- STEAM SERVICE SV 4.683.763 182544 MH 3.076.G78 364.277 8.124.718 2'a3 . COMMUNI C Al lONS E OUI PME NT 166.889 25000 MH 408.550 254.835 829.574 254 FURNISillNGS
- FIXeURES 855.190 6797 MH 903.55,4 22.534 1.011.378 255. WASTE WA1ER TREAIM[NI EOPT 819.993 37736 MH 698.443 - 400.248 0.878.684 25 MISCELLANEOUS PLANT EOulPi 8.40.1.200 260122 MH 4.342.967 0.167.846 13.988.393 261. S'ROCluRES t30,272 82550 MH 4.204.483 s.Ot3.632 2.345.387 262. ME cs tANIC A L EQUIPMENT 16.894.423 204999 MH 3.324.446 548.472 22.687.048 26 WAIN CONO HEAT REJECT SYS 18.944.695 286749 MH 4.525.929 1.569.804 25.032.428 (
10lAL OIRECT COSTS 408.398.999 10626947 MH 178.585.935 97,192.779 677,177.625 i
r uni f EO E NGINT E RS & CONSIROCIORS INC.
SUMMARY
PAGF 5 PLANT CDOE COSI BASIS EHfRGY ECONOMIC OATA DASE (EED8) PHASE IV 630 09/89 4244 MWE LOW SutFOR CDAL 08/2t/8s FACTORV SITE SITE SITE 10lAL ACCi NO ACCOUNT DESCRIPilDN EQUIP. COSIS LA80R hours LABOR COST Mair18AL COST COSIS 998. IEMPORARV CONSIRUCilDN FAC 1322078 Mit 29.480.568 6.282.800 27.623.368 912. CONSTRUCTION IDOL S 4 EOulP 229926 Mi t 3.720.276 16.405.100 89.825.376 983. PAVROLL I NSUR APAC E & TAKES 35.704.804 35.704.804 914 PERM 115. INS. 4 LOCAL TAXES 592.900 592.900 995. IRANSPORIAhi fM 98 CONSIROCflDN bYs*4E > 35.704.104 1552004 Mit 25.830.844 22.900.800 83.745.748 929. HOME OFFIC( r,'. { te a. 22.957.330 22.957.330 922. HOME OFFICE 0/A 923. S OME OFFJCE CONSIRCIN MGMT t.493.140 9.493.140 92 HOME OFFICE E NGQG . & SE RVI C E 24.450.470 24.450.470 931. F IE LD OFF ICE F APENSE S 1.385.450 9.385.450 932. FIELO J08 SUPERVISION 28.175.000 20.975.000 933. FIELD OA/OC 375.100 375.100 934. PLANI STARiuP & IEST 555.390 555.390 93 F IELO OFF ICE ENGRG4SE RVICE 22.005.490 1.385.450 23.490.940 IOIAL INulRECT COS15 82.260.064 1552004 Mit 25.930.844 24.296.250 139.687.t58 TOIAL 8ASE COST 490.658.983 12978958 Mit 196.716.779 128.489.029 808.864.183
\
Effective Date - 1/1/81 TABLE 5-13 - ENERGY ECONOMIC DATA BASE 795 MWe LOW SUIJUR COAL FPGS CAPITAL, COST ESTIMATE O e j . 5-26
^
PLANT CODE UNIIED ENGINEERS & CONSTRUCIORS INC.
SUMMARY
PAGE I COST RASIS ENERGY ECONOMIC OATA OASE (EfDG) PetASE IV 620 09/8,1 795 MWE TOW SULFUR COAL 08/29/88 EACIORY Stit SiiE SITE 101AL ACCI NO ACCOttNI OE SCRIPT ION EQUIP. COSTS LABOR is00R$ LAROW COST MATERIAL COST CO5IS
.......... .......................... ...........,. ............ ............. ....e........ ............e.
20 L APA) AND LAND RIQtl5 2.750.000 2.750.000 21 SIRt)CTURES + IMPROVEMINTS 2.289.966 1437086 Mit 20.e,6 3 . 9 3 9 32.309.689 55.255.594 22 BOILER PLANI EQUIPMENT 169.316,606 3698599 Me 60.032.683 22.644.449 243.993.730 23 TUROINE PLANT EQUIPMENT 72.508.247 1084365 MB 86.122.692 4.555.677 93.779.616 24 ELECTRIC PLANT EQUIPMENT 18.940.298 4082486 Mt 17.ta75.4 85 9.875.386 39.390.029 25 MISCEtLANEOUS PLANI E NtilPI 7.625.062 222845 Mt 3.716.999 1.082.097 12.354.070 26 MAIN COND flEAT REJECT SYS 63.069.966 220165 Me 3.458.734 8.268.594 17.797.294 IOf AL OIRECT COSIS 268.735.945 7675448 Mt 822.970.374 74.495.894 465.328.333 98 CONSTRUCIION SERVICES 25.552.478 I t700T4 Me 98.694.646 16.965.200 64.432.324 92 HOME OFFICE E NGRG. 6 SE RVICE 47.999.630 17.999.630 93 FIELO OFFICE ENGRG&5ERVICE 12.989.350 955.900 13.945.250 s IOTAL INDIRECT COSTS 56.453.458 8870074 Me 88.694.646 87.929.800 92.989.204 IOTAL BASE COSI 325.188.603 8845522 Mt 940.785.020 92.336.914 558.380.537 e 4
N 2 . 0 2 6 9 5 5 3 8 7 5 3 3
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=
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UN I I E D E NG I NE E R S & C DNS I RUC I OR S I NC .
SUMMARY
PAGE 4 PLANT CODE COSI BASIS ENERGV ECONOMIC DATA BASE (EEDR) PetASE IV 620 OI/nt 795 MWE TOW SULFUR COAL 08/28/89 FACIORY SITE . SITE SITE TOTAL ACCI NO ACCOUNI DE SCR I Pi f 0N EQUIP. COSIS LAROR laOURS LAROR COST. MATERIAL COST COSIS 249. SWi tCleGE AR 6.389.973 58840 MH 942.962 98.362 7.353.297 242. SIAtION SERVICE EQUIPMENT 4.294.997 d6436 MII 739.983 143.605 5.098.585 243. SWI ici enO ARDS 687.240 146.688 9030 Mit 93.497 927.355 244 PROIECTIVE EQUIPMENT 72400 MH 1.185.902 1.090.498 2.996.400 245. EIECT.SIRUC
- WIRING CONINR 580035 Met 8.244.748 2.755.828 19.000.576 246. POWER & CONIROL WORING 726.088 386440 Mit 6.395,202 5.773.526 12.884,886 24 ELECTRIC PIANT EQUIPMENT 88.940.29R 1082480 MH 87.575.485 9.875.386 39.391.029 251. TRANSPORIATION & LIFT EQPi 9.796.20t 7200 Mel 820.177 824.396 1.960.774 252. AIR.WAIER* STEAM SERVICE SV 154559 MH 4.028.522 2.605.045 313.460 6.947.027 253. COMMUNICATIONS EOUIPMENT 866.889 25000 MH 408.550 254.935 829.574 254 FURNISatINGS
- FIXTURES 885.290 103.554 6797 Mit 22.534 0.091.378 255. WASIE WATER 1REAIMENT EOPi 828.060 479.585 29369 Mit 297.572 8.605.317 25 MISCELLANEUUS PLANT EQUIPI 7.625.062 222845 Mai 3.716.999 1.082.097 82.354.070 269. STRUCTURES 193.059 66875 MH 963.496 832.94I t 909.496 262. MECit%NICAL EQUIPMENT 82.956.907 453990 MH 435.653 2.495.238 15.887.790 26 MAIN CONO tlEAT REJECT SYS 83.069.966 220t65 Mit 3.458.734 9.268.594 17.797.294 TOTAL DIRECT COSTS 268.735.145 7675448 MH 122.170.374 74.485.834 465.321.333
PLANT CODE UNI T E O E NGI NE E RS A CONSTRUCIORS INC.
SUMMARY
PAGE 5 COSI BASIS ENERGY ECONOMIC OATA BAS [ (EEDH) PtlA SE IV 620 09/88 795 MwE LOW SULFUR COAL 08/28/89 FACIORY SITE SIIE SITE ACCT tao ACCOUNT DESCRIPTIDN TOTAL EQUIP. COSl5 LABOR ltOURS LAROR COSI aAIEptAL COSI COSTS 999. IEMPORARY CONSTRUCTION FAC 1013143 Mit 46,117.257 4.986.200 29.103.457 992. CONSIRDCIION IOOLS & EQUIP 156968 Mi t 2.497.389 St.569.550 14.058.939 983. PAVROLL INSURANCE & IARES 2%.552.478
- 25.552.478 984. PERMITS. INS. & LOCAt. TAXES 487.450 497.450 ,
995. TRANSPORIATION 91 CONSIRUCTION SERVICES 25.552.478 1970074 Mi t 18,684.646 16.965.200 61.032.324 929 HOME OFFICE SERVICES 86.622.980 16,622.980 922. HOMt OFFICE O/A ' 923. DN)ME OFFICE CONSIRCIN MGMT 4.288.650 9.288.650 92 HOME OFFICE E NGRG. & SE RVIC E 87.998.630 17.918.630 , 939. FIELO OFFICE EXPENSES 955.900 955.900 932. FIELO JOO SUPERVISION 82.302.070 12.302.070 933. FIELO OA/OC 217.800 297.800 934. PLANT STARIUP & TEST 4G9.480 469.480 93 FIELO OFFICE ENGRG& SERVICE 12.989.350 955.900 13.945.250 IUIAL INDIRECT COSTS 56.453.458 1970074 Me t 18.684.646 17.929.100 92.989.204 TOIAL BASE COST 325.188.603 8845522 Met 140.785.020 92.336.984 558.300.537
Effective Date - 1/1/81 d
/
TABLE 5-14 ENERGY ECONOMIC DATA BASE , , 630 MWe COAL GASIFICATION CCMBINED CYCLE FPGS CAPITAL COST ESTIMATE 8 l J . 5-27 l l [
UNI T ED ENGINEERS & CONSTRUCIORS INC. SUMMIAY PAGE 2 PLANT CODE COST RASIS 660 ENERGY ECONOMIC DATA BASE (EEDR) PHASE IV 01/81 630 MWE COAL GASIFICATION COMBINE 0 CYCLE 08/21/89 FACTORY SITE SITE SITE TOTAL ACCT to ACCOUNT DESCRIPTION EQUIP. COSTS LABOR DOURS LABOR COST MATERIAL COST COSTS e 20 LAND AND LAND RIGHTS 687.500 687.500 219. WARDWORK 102.376 155070 Mt 2.098.414 2.749.278 4.950.068 213. TURRINE GENERATOR BLDG 287.792 19237G Mt 2.965.074 7.045.020 10.297.886 214. CONTROL BUILDING 89.506 46466 M4 719.238 840.675 1.641.419 2108. ADMINISTRATION
- SERVICE BLD 82200 Mi 1.326.190 9.748.395 3.067.585 218C. FUEL Olt. STORAGE TANMS 7888 Mt 125.037 104.820 229.857 2180. FUEL OIL FORWARDING HOUSE 3.545 3221 MI 47.022 32.895 83.462 2181. DIESEL GEN & SWITCHGR BLOG
- 16320 Mt 256.693 309.868 566.554 2184. CDAL CAR THAW SHED 2538 Mt 36.014 15.850 51.864 218N. CDAL UNLOADING FACILITY 3668 Mt 52.164 30.475 82.639 218P. COAL CRUSHER DOUSE 660 Mt 10.600 8.612 19.292 218R. ROYARY PLOW MAINTNCE SHED 218T. LOCOMOTIVE REPAIR GARAGE 2180 COAL HANDLING CNTRL HOUSE 930'24 13.283 12.706 25.989 218V. WATER TREA1 MENT BLDC. 85.011 17950 Mt 258.568 243.061 516.640 218W. MISC COAL HANDLING STRUCT 155.400 46689 MH 614.671 298.671 1.068.742 2182. MISC SMALL BUILDINGS 143.816 143.816 2194. FLUE GAS STACK 148366 Mt 2.219.393 2.883.800 5.103.193 2198. VENT + FLARE STACK t.785.416 29020 MJ 422.761 283.248 2.491.425 21 STRUCTURES + IMPROVEMENTS 2.430.046 753354 Mt it.165.122 18.744.183 30.340.351
.s PLANT CODE UNITED ENGINEEOS & CONSTRUCTORS INC. SUMMIRY PACE 3 CGST BASIS ENERGY ECONOMIC DATA BASE (EEDB) PHASE IV 660 01/81 630 MWE COAL GASIFICATION COMBINED CVCLE 08/29/81 FACTORY SITE SITE SITE ACCT NO ACCDUNT DESCRIPTION TOTAL EQUIP. COSTS LAROR HOURS LABOR COST MATERIAL COST COSTS eeees.eeee eeeeeeeeeeeeeeeeeeeeeeeee, seseeeeeeeees eeeeeeeeeeee eeeeeeeeeeeee eeeeeeeeeeeee eseeoseeeeeees 221. GASIFIER SYSTEM 55.273.366 12 81418 Me 20.229.E76 665.575 76.180.617 222. DRAri SYSTEM 2.261.421 63812 M4 1.076.929 3.338.350 223. ASH HANDLING SYSTEM t.568.806 57289 M4 957.323 99.842 2.618.971 224. FUEL HANDLING SVSIEMS 5.509.062 129353 Mt 2.176.905 1.268.062 8.951.029 225. PARTICULATE REMOVAL SYSTEM 84.076.029 298568 Mt 5.022.272 49.098.30t 226 DESULFURI2ATION SYSTEM 16.297.332 345670 Mt 5.814.583 22.111.915 227. STEAM GENERATING SYSTEM 21.092.790 496080 Mt 8.313.649 464.829 29.871.268 228. INSTRUMENTATION + CONTROL 3.073.082 92400 Me t.499.357 78.376 4.650.815 229. BOILER PLANT MISC. ITEMS 3.377.417 923476 Mi f.939.762 288.343 5.605.522 22 CAS1FIER/8 OILER PLT EQUIP. 122.522.305 2818066 Mt ~4 7.022.456 2.885.027 172.429.788 231. STEAM TURBINE GENERATOR 28,869.650 113775 Mi 1.803.765 619.699 38.285.114 232. GAS TURBINE GENERATORS 70.457.449 1429894 Mt 24.024.735 195.283 94.677.467 233. CONDENSING SYSTEMS 3.774.741 65239 mi 1.119.351 121.620 5.007.712 234 FE.ED HEATING SYSTEM 3.594.274 .
67260 M4 1.138.366 99.017 4.834.657 235. OIHER TUR8INE PLANT EQUIP. 2.130.522 106182 Mt f 792.226 077.662 4.100.410 236. INSTRUMENTATION + CONTROL 237. TURBINE PLANT MISC tiEMS
- 66450 Mt 1.108.583 0.189.629 2.228.212 23 . TURBINE PLANT EQUIPMENT 808.826.638 1848800 M4 30.979.026 2.324.910 142.130.572
. I
+
PLANT CODE UNITED ENGINEERS & LONSTRUCTORS INC.
SUMMARY
PAGE 4 COST BASIS ENERGv ECONOMIC OATA BASE (EEOBI P64ASE IV 660 01/89 630 MwE COAL GASIFICATION COMOINEO CYCLE 08/21/89 FACTORY SITE SITE SITE ACCT NO ACCOUNT DESCRIPTION TOTAL EOUIP. COSIS L AROR 60URS LABOR COST MATERIAL COST COSTS 248 SWITCHGEAR 3.268.686 31052 wt . 503.625 54.392 3.826.703 242. STATION SERVICE EQUIPMENT 2.936.920 27009 we 434.930 63.502 3.435.352 243. SWITCHBOARDS 279.910 3370 mt 54.657 5.466 340.033 244. PROTECTIVE EQUIPMENT 88600 Met 1.450.642 1.057.809 2.508.451 i 245 ELECT.STRUC
- WIRING CONTNR 448430 mt 7.328.243 2.422.056 9.750.299 246. POWER & CONTROL WIRING
! 1.190.285 436035 M4 7.125.680 5.935.967 14.879.932 24 ELECTRIC PLANT EQUIPMENT 7.595.809 1034496 wt 16.897.777 9.539.192 34.032.770 251. TRANSPORTAi!ON & LIFT EOPT 308.152 2740 mt 46.089 73.385 420,626 252. AIR. WATER +5 TEAM SERVICE 5( l.435.929 834980 mt 2.269.703 374.372 4.080.004 253. COMMUNICATIONS EQUIPMENT I 195.046 37620 MH 614.786 61.479 871.31I 454 FURNISittfdGS + FIXTURES 874.334 1300 mt 21.869 196.203 25 . MISCELLANECUS PLANT EQUIPT 2.806.461 176640 mt 2.952.447 509.236 5.568.144 261. STRUCTURES 5.875 26355 mt 380.991 295.088 689.954 262. MECD4ANICAL EQUIPMENT 7.365.775 93303 M4 1.519.076 203.825 9.080.676 26 MAIN COND 64 EAT REJECT SYS 7.371.650 119658 El f.892.067 498.913 9.762.630 TOTAI. CIRECT COSTS 250.853.899 6751014 21 110.908.895 33,188.961 394.951.755 i J I 1
UNITED ENGINEERS & CONSTRUCTORS INC. SUMMORY POGE 5 PLANT CDDF COST BASIS ENERGY ECONOMIC DOTA BASE (EEDB) PHOSE IU 660 01/81 610 MWE COAL GASIFICATION COMBINED CYCLE 08/28/81 FACTORY SITE SITE SITE TOTAL ACCT NO ACCOUNT DESCRIPTION EQUIP. COSTS LABOR HOURS LABOR COST MATERIAL COST COSTS eeeeeeeeee eeeeeeeeeeeeeeeeeeeeeeeeee eeeeeeeeeeese eeeeeeeeeeee eeeeesseeeeee seeeeeeeeeeee eeeeeeeeeeeeee
~
911. TEMPORARY CONSTRUCTION FAC 853400 MH 14.086.816 6.419.050 20.505.866 912. COP!STRUCTION TOOLS & EOUIP I40560 MH 2.333.220 14.844.900 17.178.120 913. PAYROLL INSURANCE & TAXES 23.110.205 23.110.215 9 14. PERMITS, INS. & LOCAL TAXES 490.050 490.050 915. TRANSPORTATION s 91 CONSTRUCTION SERVICES 23.190.215 993960 MH 16.420.036 21.754.004 61.284.251 921 HOME OFFICE SERVICES 19.337.010 19.337.090 922. HOME OFFICE O/A 923. l HOME OFFICE CONSTRCIN MGMT t.288.650 1.288.650 ' 92 HOME OFFICE ENGRG.& SERVICE 20.625.660 20.625.660 l 931. FIEtD OFFICE EXPENSES 1.234.200 1.234.200 932. FIELD JOB SUPERVISION 13.597.980 13.597.980 933. FIELO OA/OC 344.850 344.850 934. PLANT STARTUP & TEST 618.310 618.310 93 FIELD OFFICE ENGRG& SERVICE 14.561.140 9.234.200 15.795.340 TOTAL INDIRECT COSTS 58.297.015 993960 MH 16.420.036 22.988.200 97.705.251 TOTAL BASE COST 309.150.914 7744974 MH 127.328.939 56.177.161 492.657.006 i
Effective Date - t/1/81 TABLE 5-15 F.NERCY ECONOMIC DATA BASE COMMODITY AND CRAFT MANHOUR SL2tfARY
!!90 MWe BALLING WATER REACTOR NUCLEAR POWER CENFRATING STATION NUCLFAR PLANT QUANTITIES Consud it y Unit Quantity Cost / Unit (a) Consmodity (con t 'd ) Unit Quantity Cott/ Unit (a)
F.acavation CY 5% ,000 14.10 valves LT _ 34,g4e Fill CY 396,000 3.35 Fire Protection LT -- 0.78* Forework SF 2.416,000 18.17 BOP Pump (1000 HP & above) HP 57,500* 98.17 Reinforcing Steel TN 20,402 I,615.00 lleat Exchangers LT -- 35.50* Concrete cy 205,727 108.32 Turbine Generator - LT - 87.47* Fabedded Steel TN 698 9,411.00 Instrumentation and Control LT -- 18.48* Structural Steel TN 10,871 1,667.00 Lighting & Service Power LT -- 4.24* w. Special Steel liners LT -- 36.79* Duct Runs and Containers LF 496,114 31.49 A. c Carbon Steel Piping (NS) 1.5 1,857,481 16.60 Wire and Cable LF 4,550,000 5.44 Stainless Steel Piping (NS) LB 224,986 64.50 Electrical Balance of Plant LT -- 29.55* Carbon Steel Piping (NNS) LB 4,477,000 8.90 Nuclear Steam Supply System LT - 104.30* Stainless Steel Piping (NNS) La 3 % ,000 29.34 All Others LT -- 444.22*
- Cost per unit is in dollars per kilowatt (NS) = Nuclear Safety Crade (NMS)
- Non-Nuclear Safety Crade
. + Includes Boiler Feed Pumps (a) Data in Constant $1951 (Inflation-Free)
NUCl. EAR FIANT MANHOURS Manhours Cost u 103 (a) Craft (cont'd) Manhours Cost w 10N"I Craft Boiler Hakers 618,054 11,045 Millwrights 311,174 5.420 Carpenters 2,256.991 34,419 Operating Engineers 1,515.233 24.153 Electricians 2.617,870 43,404 Pipe Fitters 4,358,134 76,268 Ironworkers 2,466,695 38,875 Sheet Metal Workers 304,426 5,047 laborer s 2,234,227 25,381 All others 1.059.570 14,232 TOTAL CRAFT IABOR 17,742,374 278,064
Effective Date - t/1/88 TAGLE 5-16 ENERCY ECONOMIC DATA BASE o C0tNODITY AND CRAFT MANitOUR SUPNARY 858 MWe HICH TEMPERATURE CAS-C001.ED REACTOR - STEAM CYCI.E NUCLEAR POWER CENERATING STATION NUCIIAR PI ANT QUANTITIES Comm.d t t y Unit Quantity Cost / Unit (a) Commodity (cont'd) Unit Quantity Cost / Unit (s) Excavation CY 423.115 6.77 valves LT -- 12.84* Fill CY 338,408 8.15 Fire Protection LT -- 1.478 Formwork SF 2,627,975 18.66 BOP Pump (1000 HP & above) HP 84,100* 72.71 Reinforcing Steel TN 22.618 1.623.00 Heat Exchangers LT -- 35.20* Concrete CY 169,055 104.00 Turbine Generator LT -- 65.06* Fmbed. led Stect TN 817 8,849.00 Instrumentation and Control LT -- 19.62* Structural Steel TN 8.395 1,679.22 Lighting & Service Power LT -- 4.02* i u. 4 Special Steel Liners LT - 27.88* Duct Runs and Containers LF 476.000 28.38 w Carbon Steel Piping (NS) I.8 608.104 15.60 Wire and Cable LF 4,062,084 5.95 Stainless Steel Piping (NS) LB 133,028 62.97 Electrical Balance of Plant LT . - 29.28* i Carbon Steel Piping (NNS) LB 1,859,019 9.04 Nuclear Steam Supply System LT -- 200.14* Stainless Steel Piping (NNS) LB 312,933 28.48 All others LT -- 562.58*
- Cost per unit is in dollars per kilowatt (NS) = Nuclear Safety Grade (NNS) = Non-Nuclear Safety Grade
+ includes Boiler Feed Pumps i = Does Not include Pre-stressed Concrete Vessel (a) Data in Constant $1981 (Inflation-Free)
NUCLEAR PLANT MANHOURS I'} Craft Manhours Cost x 10 lI"I Craft (cont'd) Manhours C6st x 10 Boiler Makers . 668.543 11.947 Millwrights 230.628 3.884 Carpenters 1.905,595 29.060 Operating Engineers 929,791 14.821 Electricians 2.314.205 38,370 Pipe Fitters 2.190,081 38,327 f . Ironworkers 2,045,277 32.234 Sheet Metal Workers 108.524 1,799 I Laborers 1.685,698 19,150 All Others 1.468.436 21.684 TOTAL CRAFT LABOR 13,546,778 211,276 i i
,~
o
. Effective Date - t/1/88 TABtE 5-17 ENFRGY ECONOMIC DATA BASE Cott1DD11T AND CRAFT MANHOUR SL29tARY l139 HWe PRESSURIZED WATER REACTOR NUCIIAR POWER CENERATING STATION NUCLEAR PLANT QUANTITIES Comaudity Unit Quantity Cost / Unit I* Coassodity (cont'd) Unit Quantity Cos t /t'n i t Excavation CY 529.000 14.22 Valves LT -- 13.37*
Fill CY 396,000 3.34 Fire Protection LT -- 0.83* Formwork SF 2,045,384 19.14 BOP Pump (1000 HP 4 above) HP 55,500* 95.61 Reinforcina Steel TN 21.600 1,683.00 Heat ExchanRers LT -- 34.37* Concrete CY 175,000 106.75 , Turbine Generator LT -- 84.65* j Fabedded Steel TN $46 9,627.47 Instrumentation and Control LT -- 17.25*
- Structural Steel TN ' l l ,300 1,677.00 Lighting 4 Service Power LT -- 4.41*
U Special Steet Liners LT - 18.97* Duct Runs and Containers LF 485,000 31.47 Carbon Steel Piping (NS) LR 1,500,300 15.85 Wire and Cable LF 4,608.000 6.41 Stainless Steel Piping (NS) LB 440,170 61.08 Electrical Balance of Plant LT -- 27.35* Carbon Steel Piping (NNS) LS 4.661,000 8.90 Nuclear Steam Supply System LT -- 110.94* Stainless Steel Piping (NNS) LB 410,000 29.46 'All others LT -- 458.73*
- Cost per unit is in dollars per kilowatt (NS) = Nuclear Safety Crade (NNS)
- Non-Nuclear Safety Crede
+ Includes Boiler Feed Pumps (a) Data in Constant $1981 (Inflation-Free)
NUCLEAR PIANT MANHOURS Craft Manhours Cost x 10 N' Craft (cont'd) Hanhours Cost x 10 I' Botter Makers $15,547 16,361 M111vrights 243,344 4,098 Carpenters 2,113.519 32.231 Operating Engineers 1,263,202 20,135 Elec t r ic ians 2,581,267 42,797 Pipe Fitters 4,293.002 75,128 fronworbers 2,050,602 32,318 Sheet Metal Workers 178,000, 2,951 Laborers 2,088,328 23,723 All others 946,958 12,806 TOTAL. CRAhr IAROR 16,673,769 262,548 4
Effective Date - t/1/81 TABLE 5-18 F.NERCY FCnNOMIC DATA BASE COMH0DITY AND CRAFT MANHOUR SL29tARY 1260 HWe PRF.SSURIZED HEAVT WATER RFACTOR NUCIIAR PUWER CENERATION STATION NUCLEAR PIANT QUANTITIF.S Comunod i t y Unit Quantity Cost / Unit
- Commodity (cont'd) Unit Ouantity Cnst/ Unit F.xcavation CY 534,874 14.01 valves LT -
12.42* Fill CY 402,183 3.41 Fire Protection LT - 0.93* Formwork SF 1,791,418 19.98 80P Pump (1000 IIP & above) HP 85.850+ I44.90 Reinforcing Steel TN 23,573 1,693.00 Heat Exchangers LT -- 54.01* Concrete CY 175,281 106.07 Turbine Generator LT -- 85.88* Embedded Steel TN 659 11,370.00 instrumentation and Control LT -- 14.86* Structural Steel TN 9,989 1,667.00 Lighting & Service Power LT -- 3.26* j v. g Special Steel Liners LT -- 17.58* Duct Runs and Containers LF $40,500 30.95 Carbon Steel Piping (NS) LB 1,631.098 17.78 Wire and Cable LF 5.170,000 5.10 Stainless Ste;l Piping (NS) 1.8 82,620 65.07 Electrical Balance of Plant LT -- 25.49* Carbon Steel Piping (NNS) LB 5,104.389 8.88 Nuclear Steam Supply System LT -- 131.92* I Stainless Steel Piping (NNS) LB 99,000 30.75 All Others LT -- 430.53* f
- Cost per unit is in dollars per kilowatt (NS) = Nuclear Safety Crade (NNS) = kn-Nuclear Safety Crade
+ Includes Boiler Feed Pumps (a) Data in Constant $1981 (Inflation-Free) y NUCLEAR PIANT MANHOLTRS I*
Craft Kmhour s Cost x 10 (* Croft (cont'd) Manhours Cost x 10 Boiler Hakers 994,200 17,766 Millwrights 280,706 4,727 r carpenters 1,996,617 30,448 Operating Engineers 1,275,135 20,326 48,139 4,066,955 71,172 El ec t ricians 2.903.451 Pipe Fitters Ironworkers 2.221,983 35,018 Sheet Metal W rkers 103,376 1,714 laborers 2,038,885 23,162 All others 1.067,306 12,755 16,948,654 265,227 ' TOTAL CRAFT LABOR 1
Effective Date - t/1/81 TABLE 5-19 ENFRGY ECONOMIC DATA BASE COHHODITY AND CRAFT MANilOUR SUPHARY I457 MWe LIQUID HETAL FAST-BREEDFR RF. ACTOR NUCLEAR POWER CENERATING STATION NUCI FAR PLANT QUANTITIF.S Comuu.dtty (cont'd) '} Comunooit y Unit Quantity Cost / Unit ' Unit Quantity' Cost / Unit Eacavation CY 779,943 16.73 Valves LT -- 8.02*
- Fill CY 270,335 7.56 Fire Protection LT - 12.16*
Fo rmwrk SF 2.240.890 17.18 BOP Pump (1000 HP & above) HP 98.600+ 55.81 Reinforcing Steel TN 39.897 1.688.00 Heat Exchangers LT -- 29.61* Concrete CY 264,245 110.75 Turbine Ce.ierator LT - 75.17' Fabedded Steel TN 1,538 9.363.00 Instrumentation and Control LT -- 8.82* Structural Steel TN 15.627 t,667.00 Lighting & Service Power LT -- 5.95*
- Y Special Steel Liners LT --
35.55* Duct Runs and containers LF 780.165 28.23 0 Carbon Steel Piping (NS) La 555.097 9.02 Wire and Cable LF 6,474.100 5.21 Stainless Steel Piping (NS) La 763.822 50.36 Electrical Balance of Plant LT -- 23.35* Carbon Steel Piping (NNS) L8 5.039,891 8.90 Nuclear Steam Supply System LT -- 268.85* Stainless Steel Piping (NNS) LB 816.000 21.47 All Others LT -- 498.03*
- Cost per unit is in dollars per kilowatt (NS) = Nuclear Safety Crade (NNS) = Non-Nuclear Safety Crade
+ Include Boller Feed Pumps (a) Data in Constant $1981 (Inflation-Free)
NUCI. EAR PIANT MANHOURS Craft Nnhours Cost x 10 N'I Craft (cont'd) Mantw>urs Cost a 10 N'I Bo!!er mkers 1,396,134 24.949 Nillwrights 409,907 6,904 Carpenters 2.448.713 37,343 Operating Engineers 1,974.773 31.478 Elec t ric ians 3,950.199 65,494 Pipe Fitters 5.704,864 99.835 ? Ironworkers 4,087.181 64.414 Sheet Metal Workers 405.297 6.720 l ! laimrers 2,859,136 32,480 All Others 1.428.907 26.095 T(rrAL CRAFT lAs0R 24.665.201 388,992 i l
--s t .
Effectice Date - I/1/81 TABl.E 5-20 ENERGY ECONOMIC DATA BASE COMMODITY AND CRAFT MANilOUR SINMARY 1240 MWe HIGH SULFUR COAL-FIRED FOSSIL POWER CENERATING STATION COMPARISON COAL PIANT QtfANTITIES Commodity Unit Quantity Cost / Unit Commodity (cont'd) t'n t t Quantity Cost / Unit Excavation CY 220.000 7.22 Heat Exchangers LT - 22.40* Fill CY 99.000 7.62 Turbine Generator LT - 68.76* Formwnrk SF 1.067.000 8.68 Coal Handling 1.T -- 10.70* Reinforcing Steel TN 7,000 1.035.00 Dust Col. & Elec. Precipitator LT - 16.22* Concrete CY 108.000 90.83 Soy Removal System & Structures LT - 168.67* F.mbedded Steel TN 369 5.795.00 Heat.. Ventilating & Air Cond. LT -- 5.77* Structural Steel TN 24.400 1.383.00 Ash llandling LT -- 6.69* Y 0 Carbon Steel Piping L8 4.672.573 5.01 Instrumentation and Control LT -- 5.61* Stainless Steel Piping LB 600 18.51 Lighting & Service Power LT -- 1.89* Chrome-k ly Piping 1.8 3.219.000 8.16 Duct Runs & Wire Containers LF 646.000 17.67 Valves LT - 3.40* Wire and Cable LF 3.986,000 3.73 Fire Protection LT - 0.54* Electrical 8alance of Plant LT -- 15.67 Pumps (1000 HP & above) HP 103.750* 43.83 Fossil Steam Supply System LT -- 86.40* All Others LT -- 158.98*
- Cost per unit is in dollars per kilowatt (a) Data in Constant $1981 (Inflation-Free) f Dnes not include Ignition Oil System
+ Includes Botter Feed Pumps COMPARISON COAL PIANT MANHodRS
* *I Craft ftinhours Cost x 10 Craft (cont'd) Manhours Cost a 10 Boiler Makers 290.298 5,188 Millwrights 315.!!8 5. V)7 Carpenters 447.729 6.828 operating Engineers 651.660 10.387 Electricians 1.829.575 30.334 Pipe Fitters 3.782.634 66.196 Ironworkers 942.189 14.849 Sheet Metal Workers 9 9 Laborers 663.910 7.542 All ot'hers 2.070.051 31.511
- w apni f rithle Trvr gs regry ggnog 10.993.164 17P.147
Effective Date - t/1/81 . TABLE ENERGY ECONOMIC DATA BASE COMMODITY AND CRAFT MANHOUR SL291ARY 795 MWe HICil SULFUR COAL-FIRED FOSSIL POWF.R CENERATING STATION COMPARISON COAL PLANT QUANTITIES Coss=>d i t y Unit quantity Cost / Unit
- Cniumnd it y (cont'd) Unit Quantity Cost / Unit!'
7.50 Heat Exchangers LT -- 27.31* Excavation CY 180.000 7.44 Turbine Generator LT -- 56.36* Fill CY 84.000 8.43 Coal HandlingI LT -- 15.37* Forework SF 896.000 Dust Col. & Elec. Precipitator LT -- 15.35* Reinforcing Steel TN 5.500 1.032.00 90.76 Soy Removal System & Structures LT -- 184.408 Concrete CY 88.500 314 5.795.00 Heat.. Ventilating, & Air Cond. LT -- 5.85* EmbedJed Steel TN 18,000 Ash HaMling LT -- 7.61* Structural Steel TN 1.378.00 5.01 Instrumentation and Control LT - 8.93* Y Carbon Steel Piping L8 3.017.000 7 600 18.51 Lighting & Service Power LT -- 2.41* Stainless Steel Piping LB 7.87 Duct Runs & Wire Containers LF 568.000 17.63 Chrose-Holy Piping LB 1.212.000 4.11* Wire and Cable LF 3.421.000 3.75 Valves LT - 0.80* Electrical Balance of Plant LT -- 22.348 Fire Protection LT -- Fossil Steam Supply System LT -- 91.63* Pumps (1000 HP & above) HP 66.320+ 51.58
.All others LT -- 191.37*
- Cost per unit is in dollars per kilowatt + Includes Boiler Feed Pumps
# Does not Include ignition Oil System , a)
( Data in Constant $1981 (Inflation-Free) COMPARISON COAL PIANT MANHOURS Hanhours Cost u 10 *I craft (cont'd) Manhours Cost x 10 Craft 3.742 Millwrights 231.953 3.906 Boiler Mahers 209.399 5.591 Operating Engineers 470.269 7.496 Carpenters 366.631 25.120 Pipe Fitters 2.487.750 43.536 F.lec t r ic ians 1.515.072 11.297 Sheet Metal Workers 9 fronworkers 716.823 1.439.107 21.773 1.aborere 534.777 6.075 All others 7.971.701 128,536 I T t Appitcable TOTAL CRAFT LABOR
l TASit. 3-22 Effective Date - t/l/81 ENERCY ECONOMIC DATA BASE CotteWITY UiD CRAFT MANHOUR S199tARY 1244 MWe II1W SULFUR COAL.-FIRED FOSSIL FOWER GENFRATING STATION COMPARISON COAL PIANT QUANTITIES Commodity Unit Quantity Cost / Unit Coassadity (cont'd) Unit Quantity Cos t /Un it Excavation CY 253.603 6.63 l' eat Exchangers LT -- 26.47* Fill CY 173.993 7.62 Turbine Generator LT -- 69.97= Formuurk SF l.062.866 8.70 Coal Randling# LT - 15.56e Reinforcing Steel TN 6.e00 1.036.00 that Col. & Elec. Precipitator LT -- -- Concrete CY !!6.619 88.68 Soy Removal System & Structure LT -- 154.32* FabedJed Steel TN 389 5.795.00 Heat.. Ventilating. & Air Cond. LT -- 11.39* Structural Steel TN 26.330 1.385.00 Ash Handling LT - 6.69* Carbon Steel 31 ping LB 4.672.570 5.01 Instrumentation and control LT - 4.91* U Stainless Steel Piping LB 600 18.51 Lighting 6 Service Power LT -- I.90* Chrome-Moly Piping L8 3.219.000 7.83 Duct Runs & Wire containers LF 646.250 ,17.56 valves LT -- 3.61* Wire and Cable LF 3.989.000 3.7) i Fire Protection LT -- 0.56* Electrical Balance of Plant LT - 15.25* Pumps (1000 HP & above) HP 103.750+ 43.8) Fossil Steam Supply Systers LT - 88.26* All Others LT -- 182.148
- Cost per unit is in dollars per kilowatt + Includes Botter Feed Pumps (a) Data in Constant $1981 (Inflation-Free)
_ COMPARISON COAL PLANT MANHOURS Craft Manhours Cost x 10 I* Craft (cont'd) Manhours cost x 10 (* 158.276 2.953 M111 wrights 340.056 5.727 ) Boller fukers - Carpenters 448.299 6.837 Operating Engineers 583.381 9.299 Electricians 1.663.731 27.585 Fipe Fittets 3.597.955 62.964 Ironworkers 917.731 14.463 Sheet Metal Workers 6 9 tat, ore r s 794.090 9.021 All Others 2.123.534 32.741 TOTAL CRAFT IABOR 10.627.053 171.588 F Not .\pplicable
TABLE e-23 Effective Data - t/1/81 ENFECY ECONOMIC DATA RASE COMMODITY AND CRAFT MANIIOUR
SUMMARY
795 MWe IfW SULFUR COAL-FIRED FOSSIL POWER CENERATING STATION COMPARISON COAL Pl. ANT QUANTITIES Cosunodity # Unit Quant it y Cost / Unit _ Commodity (cont'd) Unit Quantity Cost / Unit Escavatton CY 198,266 6,82 Heat Exchangers LT -- 27.71* Fill CY 101,228 7.57 Turbine cenerator I.T -- 56.36* Formwork SF 856,460 8.44 Coal Handling LT - 19.75* Reinforcing Steel TN 5,311 1,029.00 Dust Col. & Elec. Precipitator LT -- -- Concrete CY 92.675 89.54 Soy Removal System & Structures LT -- 167.53* Embedded Steel TN 325 5,795.00 Heat., Ventilating, & Air Cond. LT -- 12.04* Structural Steel TN 19,380 1,464.00 Ash Handling LT -- 7.87*
, Carbon Steel Piping LB 3,013.380 5.01 Instrumentation and Control LT --
7.99* e 5 Stainless Steel Piping LB 600 18.51 Lighting & Service Power LT -- 2.42* Chrome-Moly Piping LB 1,232,0~)0 7.87 Duct Runs & Wire Containers LF 567,500 17.64 Valves LT -- 4.33* Wire and Cable LF 3,423,022 3.75 Fire Protection LT
-- 0.85* Electrical Palsace of Plant LT -- 19.02*
Pumps (1000 llP & above) HP 66,320+ 51.58 Fossil Steam Supply System -- 92.65* LT All others LT -- 152.63*
- Cost per unit is in dolla'rs per kilowatt
+ Includes Boiler Feed Pumps # Does Not include Ignition Oil System (a) D1te in Constant $1981 (Inflation-Free)
COMPARISON COAL PIANT MANHOURS Craft Hanhocre Cost x 10 I*} Craft (cont'd) Hanhours Cost x 10 N* Boiler Makers J16.154 2,075 Millwrights 243,969 4,108 Carpenters 352.411 5.374 operating Engineers ,425,359 6.780 i El ec t ric i ans 1.400,418 23,219 . Pipe Fitters 2,321,084 40,619 Ironworkers 720.350 11,353 Sheet Metal Workers 0 0 1.aborers 617.239 7.011 All others 1.478.586 21.633 TOTAL CRAFT LABOR 7,675,570 122,173 A Not Applicable
SECTION 6 6.0 FUEL COST FOURTH UPDATE The Fourth Update of the fuel costs in the Energy Economic Data Base covers both fissle fuels (uranium, thorium and plutonium) and fossil fuels (coal). It provides fuel costs for all of the t'echnical models in the Data Base, in accordance with a consistent set of ground-rules. Broad ground-rules and assumptions governing fuel costs are discussed in Section 3. This section presents the detailed bases for both the nuclear fuel cycle costs and the fossil fuel costs. 6.1 FUEL COST
SUMMARY
Fuel costs are prepared for the EEDB as total thermal costs (C/MBtu). Nuclear fuel cycle costs for the Fourth Update consist of Fuel, (including are con-version and enrichment) Fabrication, Transportation, Reprocessing (Breeder option only) and Disposal costs. Costs for short term on-site spent fuel storage are included in the Capital Costs; long term storage is assumed to be off-site at a Federal depository. Coal fuel costs for the Fourth Update con-sist of Fuel and Transportation costs only. Costs for Flue-Gas-Desulfurization are not included in the coal fuel costs. These costs are included in the Capital and the Operating and Maintenance costs. Fuel costs are summarized in Table 6-1 for all plants for startups in the year 2001. Table 6-2 summarizes fuel costs for the commercialized technologies for plant startup in the year 1981. Table 6-3 gives data for the advanced techno-logies for variable plant startups in the year when the technologies are ex-pected to be deployed commercially. Table 6-3 includes the LWR plants and the conventional coal-fired plants for comparison. 6-1
6.2 NUCLEAR FUEL CYCLE COST UPDATE PROCEDURE The Initial Update of the nuclear fuel cycle costs is a first-of-a-kind effort, performed by United Engineers & Constructors, Inc. and their subcontractor, the NUS Corporation, to produce a fuel cycle cost data base for the EEDB. In the Second Update, an Approximation Factors Method is developed as the EEDB nuclear fuel cycle cost update procedure, and is described in the Second Update Report.* This procedure is utilized to develop the nuclear fuel cycle costs for this Fourth Update, for the selected technical models given in Table 1-1. 6.3 DETAILED FUEL COSTS Results of the Fuel Cost Fourth Update are presented for each technical plant model in ;he Tables listed below. Specific BWR mass flow data is not available for t'his study; therefore, PWR data is used for the BWR (Model A1). Nuclear Year Fuel Cycle Fossil Year Fuel Cost Plant of Cost Table Plant of Table Model Startup Number Model Startup Number PWR 1981 6-4a/4b HS12 1981 6-13a PWR 1987 6-5a/5b HS12 1987 6-13b PWR 2001 6-6a/6b HS12 2001 6-13c HTGR 1995 6-7a/7b HS8 1981 6-13a HTGR 2001 6-8a/8b HS8 1987 6-13b PHWR 1995 6-9a/9b HS8 2001 6-13c PHWR 2001 6-10a/10b LS12 1981 6-13a LMFBR 2001 6-11a/11b LS12 1987 6-13b Explanation LS12 2001 6-13e of Fuel Cycle 6-12 System Desig- LS8 1981 6-13a i nation i LS8 1987 6-13b LS8 2001 6-13e CGCC 1987 6-13b CGCC 2001 6-13c
- Refer to Section 8.1 for additional details i 6-2
\
For the nuclear fuel cycle costs, '.'a" tables tabulate Input Cost Components and "b" tables tabulate Output Cost Components. In the "a" series of nuclear fuel cycle cost tables , the costs of the fuel cycle components are assumed to remain unchanged in terms of constant $1981. In the "b" series of nuclear fuel cycle cost ~ tables, the costs are given for Direct, Indirect and Total Costs, leveli:ed over the nominal 30-year plant lifetime from the year of plant'startup. The values in the "a" tables are given in terns of unit market prices and in the "b" tables are given in S/MBtu. The costs are based on the mass flow characteristics of the specific reactor type for which the costs are computed. These characteristics are applied as derived coefficients to the unit costs for the materials / services given in the "a" tablas. 6.4 PROJECTION OF ECONOMIC PARAMETERS FOR FUEL The projection of several national economic parameters is a key element in the calculation of nuclear and coal fuel cost estimates. Principal among these are the long term inflation rate, interest rate, and discount rate. They are particularly relevant in calculating the levelized fuel cost for either a nuclear or coal-fired power generating station. The levelized fuel cost is the constant annual cost of the fuel over the life-time of the plant, in which the fuel is utilized, whose stream of payments has a present value equal to the present value of the actual or predicted annual cost (which nay be variable) of the fuel over that period. 6-3
Revised 10/06/81 Levelized values.for each component of the nuclear fuel cycle are provided in constant 1981 dollars. The coal fuel cost,s for the EEDB Fourth Update nre stated in terms of first year costs in constant 1981 dollars for each year of startup. The assumption is made that no escalation will. occur for coal, even though it is expected that coal will rise over time to the levels of more expensive, competing fuels. This is a conservative assumption in terms of the objective, assump-tions and groundrules of the EEDB Program. This assumption is subject to examination in future updates. When valid information becomes available, projections of future coal costs will be incorporated. However, adjustments are made for startup years beyond 1981 to account for escalation due to rising scarcity. For the case where it is desirable to incorporate the escalation of coal costs into a cost calculation, a levelization factor should be computed and applied to the first year costs reported in this update, before the feel costs are added to levelized capital and operating and maintenance costs. Consistent rates of interest and escalation must be used in the computation for compat-ibility and consistency with the capital and 0&M costs with which it is combined. An approximation of the necessary levelization factor may be
- computed with the following equation
LF = d, ~(1 + d)U - (1 + a)"' (8) d-a (1 + d)n _ g Where: LF = levelization factor
- a = (1 + 1) (1 < e) - 1* l j d = discount rate per annum
- i = inflation rate
- l n = number of years
- e = escalation rate *
- Refer to Section 2 4 2 for definitions of these terms as used in the EEDB Program .
6-4 f
6.5 NUCLEAR FUEL CYCLE COSTS , The Nuclear Power Generating Stations (NPGS) currently deployed in the United 1 States consist of Light Water Reactors (LWR's) and a single High Temperature Gas cooled Reactor (HTGR). The HTGR NPGS is a 300 MRe demonstration unit re-presenting a one-of-a-kind situation, because commercialization of this design is indefinitely postponed. The Light Water Reactor NPGS utilize both Pres-surized Water Reactors (PWRs) and Boiling Water Reactors (BWRs). The PWRs are manufactured by Westinghouse, Babcock and Wilcox and Combustion Engineering Companies. The General Electric Company is the sole manufacturer of the BWR. In this update of the EEDB, nuclear fuel cycle costs are developed for five dif ferent reactor plant types; the Pressurized Water Reactor (PWR), the f Boiling Water Reactor (BEL), the High Temperature Gas Cooled Reactor (HTGR), the Pressurized Heavy Water Reactor (PHWR) and the Liquid Metal Fast Breeder Reactor (LMFER) Nuclear Power Generating Stations. The last two of these reactors have no commercial prototypes in existence in the United States today. Reactor and cost input data for' the commercialized LWR fuel cycle are based on a significant amount of real operational experience. The extrapolation of this data is reasonable in predict,ing future costs. It is important to emphasize that the data in the fuel cycle costs for the remaining three reactor types are based entirely upon analytical and predictive models and not on commercial experience. l The similarities of the BWR and the PWR are such that the fuel utilization characteristics differ only slightly. Consequently, their fuel costs, levelized over the nominal plant lifetime, do not vary more than i 10 percent. The fuel cycle for the LWRs is exemplified in this update by the PWR l 6-5 l
l data. The values given in the NASAP (Nonproliferation Alternative Systems Assessment Program) are used to attain a normalized value for the LWRs' as a class. Since there are minor but real variations among the LWR reactors cur-rently operating and under construction, the use of NASAP data provides a neutral basis for the computation of costs. Therefore, the explicit fuel cycle costs calculated for the PWR are utilized to represent both PWRs and BWRs. Because of the lack of experimental information regarding the three as yet uncommercialized reactors (HTGR, PHWR, and LMFBR), data on mass flow for these reactor types are also based on NASAP information, which represents a neutral and agreed upon body of data for the reactor types in question. ( 6.5.1 Nuclear Fuel Cvele Description Nuclear fuel cycle cost analysis for this update of the EEDB is based on the steps in a typical uranium / plutonium fuel cycle, illustrated in Figure 6.1. This Figure shows a complete reactor fuel cycle from mining of uranium ore through reprocessing of irradiated fuel, recovery of uranium and plutonium from spent fuel and shipment of high level waste to permanent storage. Under this scheme, the uranium and plutonium are recycled through the reactor fuel cycle. It should be noted that the reprocessing portions of the fuel cycle shown in Figure 6.1 are included for completeness and to provide economic data for this option. Currently, reactor fuel'for the commercial Light Water Re-actors is not being reprocessed. The alternate back-end of the fuel cycle, without the reprocessing option shown in Figure 6.1, includes temporary storage and eventual disposal of the spent fuel without reprocessing. 6-6
e A standardized cost code-of-accounts format for presentation of the f uel cycle costs is given which correlates to the steps in the typical uranium / plutonium fuel cycle. The cost code-of-accounts numbering system is an extension of the format developed b:7 USAEC Report NUS-531, " Guide for Economic Evaluation of Nuclear Reactor Plant Designs." - 6.5.2 Components of the Nuclear Fuel Cycle Cost Analysis The total nuclear fuel cycle cost is composed of direct and indirect cost components. The direct cost component is the cost of the fuel consumed as reflected in the cost of the materials and services for each step of the nuclear fuel cycle. It is independent of calendar time and plant capacity factor. The indirect cost component is the carrying charge associated with the value of the reactor fuel during a given calendar period. It includes interest on borrowed money, return on equity, federal.and state income taxes, and other costs associated with the time value of money. Since the indirect , cost component is dependent on time, it is related to the plant's performance in terms of the plant's capacity factor. Both the direct and indirect cost estimater are developed on an inflation-free basis and reported in constant January 1 dol'lars of the year of the estimate. The nuclear fuel cycle costs developed here are levelized over the life of the reactors, which is assumed to be 30 years. This permits comparison of the various reactor fuel cycle systems on the same economic basis. In addition, the total nuclear fuel cycle costs include the economic impact l of the initial core on the thirty year levelized fuel cycle cost. This effect
~
is considered, because the initial core is larger and more expensive than 6-7 i l l l
the reloads, which represent only part of the core. The total impact of the initial core cost on the total levelized fuel cost is dependent on the reactor, fuel cycle and generating history. 6.5.2.1 Direct costs Direct costs are the costs of materials and/or services associated with each step in the fuel cycle shown in Figure 6.1. These are as follows:
- a. The cost of U 0 in dollars per pound - $/lb U 0 '
38 38
- b. The cost per kilogram for conversion of the U 0 t UF 38 6
~8 8 U*
- c. The cost for enrichment of the UF t te eve requ red by the 6
particular reactor fuel cycle under consideration. The cost is given in dollars per separative work unit - $/SWU.
- d. The cost for fabrication, carrying the enriched UF t pelletized 6
UO and encapsulating in a cladding material, followed by assembly of 2single fuel rods into a fuel elem*nte - $/Kg U (or HM).
- e. The costs for shipping fuel to the reactor site - the point of use - $/Kg U (or HM); in this report, these costs are included in fabrication cost.
- f. The cost of shipping spent fuel after on-site storage, to (a) reprocessing or (b) a Federal repository for spent fuel storage - $/Kg HM.
- g. The cost of spent fuel disposal - $/Kg EH or the cost for re-processing of spent fuel - $/Kg HM.
- h. The cost for disposal of waste from the reprocessing operation -
S/Kg HM.
- 1. The cost / refund value of the recovered U or Pu as shipped for fuel f abrication of mixed oxide fuel - MOX - S/Kg IIM.
The assignment of a specific dollar value to the individual steps of the direct costs in the nuclear fuel cycle remains open to discussion. In the Fourth Update of the EEDB, the costs for these steps have been derived from the best U03 8 = uranium ore concentrate UO2 = uranium oxide
-HM = heavy metal UF6 = uranium hexafluoride 6-8 U = elemental uranium
l I information available and represent either a consensus of current estimates or actual costs. The values given in Tables 6-4a through 6-11a ("a" tables j only) summarize the fuel cycle unit prices used in :this evaluation. It must be noted that the costs for natural uranium are taken over the period i from 1981 to 2030, with values for these and the intervening years shown in Table 6-14. Fuel fabrication costs depend on various fuel cycle options in the reactor types involved. These costs are summarized, by reactor type, in the "a" tables. The shipping of fuel to a site usually constitutes a minor cost which is absorbed under fabrication costs. However, the handling of the plutonium-rich material from the LMFBR requires greater care and ine'rs"gre'ter u a shipping
- costs.
When spent fuel elemet - are removed from the reactor, they are generally stored in a safe and shielded area on-site to permit the short-lived fission products to decay. Storage times may vary from 120 days to 10 years. Under the assumptions of the EEDB Program, the investment cost of this spent fuel
- storage is included in the capital cost of the plant. Consequently, there i is no explicit charge given for on-site spent fuel storage facilities, even l
though the time value of money for the fuel storage period is included in the l fuel cycle costs. ) i The shipping of spent fuel from the reactor site to a reprocessing plant or J a temporary or permanent Federal repository for spent fuel elements, does require significant expenditures. These expenditures differ for the types of 6-9
-- . _ _ _ - _ _ . -. .- =____ - _ _ _ _ _ . . _ _ . -- _- - _- . _ _ - - _ _ _ . _ _ _ _ _ _ -
i
~
i t i a - fuel shipped, and are shown in the "a" tables. The Fourth Update considers 4 i throwaway cycles for the non-breeders and plutonium recycle for the breeders. i j The projected reprocessing costs for the breeder reactor is also given in the "a" tables. In terms of constant dollars, it has been assumed that there f will be some productivity increase with the passing of time and that this ' productivity increase will be accompanied by a reduction in the cost of opera-tion. I It is generally accepted that the value of the plutonium and of the uranium i recovered in reprocessing, will be economically attractive only when that I l . portion of the fuel cycle, with its attendant waste disposal, is shown to be less expensive than the use of fresh uranium and the subsequent steps of enrichment and fuel fabrication. For the fast' breeder reactor, therefore, the assumption is implicit that the plutonium will be bred from depleted U-238, which is considered to have no value. This may be noted in the "a" tables. 6.5.2.2 Indirect Costs i In addition to the direct costs, there are related cost factors, which affect the overall fuel cycle cost. These indirect costs usually include: l e Interest on borrowed money, 1 i e Return on equity, o Federal and State income taxes, e Other taxes . e Other costs related to the time-value of money. i 6-10
.e p-. -
g .-r- --g-w-----1 --%- _ _-,---.------.-w.- - , _ . - - - m- e _ , %% -- , , -w-
- . _ _ _ _ _ _ _ _ _ _ _ = _ - . - - _ - _ _ . . - . - _ - . . - - _ - _ _ - - - _ _ _ _ _ _ - _ _ . - _ -
l The calculation of indirect fuel cycle costs requires that all the factors affecting them be projected over the time period for which they are being calculated. Indirect costs are related to the time when payments for materials ) and services are made, and the amount of time that the fuel spends in the reactor. Therefore, indirect costs are impacte.d by the lead and lag times i associated with payments for materials and services and by the performance of the plant as measured by its capacity factor. It is of ten not possible to establish a linear relationship between indirect costs and the direct costs for the associated fuel cycle steps. Generally, a discounted cash flow analysis is used to precisely determine the indirect costs, when the information available can support this level of accuracy. However, adequate estimates of indirect cost can be derived by an interest rate approach. 6.5.2.3 Other Factors The operational lifetime for all reactors is assumed to be 30 years. The startup dates considered are discussed in Section 3.0. -
! The lead and lag times involved in the procurement of fuel, the reprocessing step (where reprocessing is involved), and the eventual crediting of the recovered materials, affect costs, because they represent a charge similar to an interest rate. The lead time is the length of time from the payment for materials and services at the beginning of the fuel cycle, to the time this fuel is placed in the reactor core. This lead time simulates the pro-gress payment schedule. The lag time is the length of time from discharge of fuel from the reactor to the point when payments are made for materials 6-11 i
i
, - , , - ~ . , -- , , - . . . , , _ _ _ . - - _ . . , . - _ - .
a and/or services at the back-end of the cycle, or to receipt of credit, if any, for recovered fuel. A summary of the lead and lag times used in the Fuel Cycle Cost Fourth Update are tabulated in Table 6-15. In the various steps of the fuel cycles, where the fuel itself undergoes pro-cessing, some losses are inevitable. However, on the basis of experience, they are considered to be too small to significantly affect the overall costs in any step of the fuel cycle. For all of the reactor types and fuel cycle options presented, it is assumed that the tails assay for enrichment is I approximately 0.2 weight percent U-235. Minor changes in the percentage of . the tails assay are not expected to affect the costs of the fuel cycle signi-ficantly. Advanced isotope sept. ration technology is not considered in this re po rt . 6.5.3 General Approach to Muclear Fuel Cycle Cost Analysis The general approach to Nuclear Fuel Cycle Cost Analysis consists of the i following activites:
- 1. Projection of general economic parameters over the period of interest, including long term escalation, interest and discount rates.
- 2. Selection of the nuclear fuel cycle calculation method that is appropriate for the level of accuracy required and the j availability of the input data.
I 3. Selection of the desired combinations of reactor type and I fuel cycle alternatives.
- 4. Acquisition of mass flow data for the selected combinations of reactor type and fuel cycle alternative.
- 5. Acquisition of input unit cost data projections for each step of each nuclear fuel cycle under consideration over the time period of interest 6-12
._,,,_.,,_-__w- , _ _ - - -
, _ _ . , _ - _ - , . . , -- - __, - . -- _. m. ,
- 6. Calculation of the direct and indirect cost components for {
i each step in the reactor-cycle combination being analyzed for the period of interest.
- 7. Calculation of th'e levelized total nuclear fuel cycle cost for each cycle case being an~alyzed over the period of interest.
i The calculation of the direct costs is dependent on the reactor core design and the energy and mass balance associated with the cycle selected. The i calculation of the indirect costs is dependent on time and reactor performance. Consequently, although the, direct' costs are the largest component of the fuel cycle, the indirect costs are the more difficult to calculate, because 1 of the complexities associated with the time related accounting. Since precise calculation of,the nuclear fuel cycle costs requires an accurate calculation of the indirects, a detailed cash flow analysis, which is usually computerized, is utilized where great accuracy is required. Very complex and sophisticated programs have been developed. Their complexity is limited only by the level of accuracy desired for a specific application. Fuel management of operating reactors is.an example of a situation which requires precise results. Bid evaluation of alternative U 0 or fabricated 3g fuel bids is another example where precision is important. In cases where such high precision is unneeded or unjustified, adequate estimates of indirect costs can be derived from an interest rate approach. 6.5.3.1 Selection of An Approximate Method Review of the USDOE objectives for t h e EEDB Program results in a decision to adopt an approximate method of nuclear fuel cycle calculations, rather than to utilize a computerized, detailed cash flow technique. The reasons 6-13
l 1 for this decision are as follows: l e The objective of the EEDB Program is to provide normalized comparisons between generic alternatives, rather than the detailed comparisons of specific alternatives found in actual industry cases. e Use of the EEDB, following the Initial Update, has provided the experience that evaluation of alternatives on a quick response basis is often required. This experience indicates that a simpler and more flexible method for developing fuel cycle costs is required.
- e The projections of input unit costs for each fuel cycle com-i ponent have great uncertainity because they reflect a " national generic average value". The average value may differ sub-stantially from the costs associated with specific bids in actual cases. The range of long term bid prices associated '
with different economic conditions at different times in different parts of the county results in this disparity. This is particularly true of the U 03 8 price. (A review of the tables and charts on U 03 8 contract prices in the USDOE, Grand Junction Office reports will demonstrate this fact.) i i e The projection of input unit costs for each fuel cycle component over a period of fifty years is also subject to the uncertainties associated with political policy decisions, technological innovations and the general discontinuities of supply / demand interrelationships. e Only the LWR reactor core with,,"once-through" fuel cycle has actual experience to support " precise" economic analyses. The HTGR, PHUR and LMFBR are based on conceptual designs and specifications. Therefore, there is little justification to utilize highly accurate, but complex, calculation techniques for the purpose of comparing alternatives. The development of the approximate method is based upon the detailed data base developed for the Initial Update of the EEDB by United Engineers and its subcontractor, NUS Corporation of Rockville, MD. 6.5.3.2 CalculationAhproachfortheApproximationFactorsMethod The Approximation Factors Method of nuclear fuel cycle calculation used in this update is based on NUS-3190, " Fuel Cycle Cost Estimates for LWR, HTGR, CANDU 6-14
~
Type EVR, LMFBR, and GCFR"; NUREG-0480, " Coal and Nuclear: A Comparison of the Cost of Generating Baseload Electricity by Region"; and other reports (Refer to Section 8.1, References 5, 6, 7, 8 and 9). A set of direct cost proportionality constants or approximation factors are
. developed for the direct cost associated with each step of each reactor-cycle combination addressed. In order to maintain continuity and consistency with the EEDB Initial Update, mathematical relationships are established between the input cost per unit given in NUS-3190 and the direct cost value in terms
- of thermal costs given as output. The input unit costs are given in the "a" series of Tables 6-4 through 6-11. The direct costs answers are given in the "b" series of Tables 6-4 through 6-11. The direct cost approximation factors are verified by using the existing data to demonstrate their validity.
The approximate method utilizes an expression
- to calculate the indirect cost as a function of the lead and lag times associated with the direct cost ex-penditure, the residence time of the fuel in the reactor and the cost of money used as a basis for calculating the carrying charges.
The impact of the initial core relative to the equilibrium core, on the total 30 year nuclear fuel cycle cost, varies with each reactor-cycle combination. To account for this impact, the approximate method distinguishes between the initial core and the equilibrium core in calculation of directs and indirects and combines them in the final operations of each calculation. The Nuclear Fuel Cycle Update Procedure (Approximation Factors Method) is
- The expression used is adapted from that given in NUREG-0480 at the bottom of page C-15. The general discussion of the nature of carrying charges which forms the basis for the approach is given on pages C-14, C-15, and C-16 of that source.
6-15 N 9 -
- -. y-.7
described in detail in the Second Update Report.* 6.5.4 Input _ Unit Cost Projections The total nuclear fuel cycle cost is a function of the market prices of the materials, processes and services associated with each step of the cycle. These market prices are referred to as the input unit costs in this discussion. As previously noted, the principal fuel cycle cost experience is derived from operations with the LWRs. However, only a partial segment of the full fuel cycle is completely defined. Government policy decisions have not yet been made on the reprocessing of spent fuel and the disposal of high level radioactive vastes. Therefore, cost experience is lacking in these areas, as well as the associated area of the value of the recovery of spent fuel. It is important to recognize the absence of experiential cost data for the reprocessing portion of the fuel cycle in the case of the LMFBR, because the recycling of fuel is an integral part'of this fuel cycle. All values for unit input costs associated with the nuclear fuel cycle steps are given in constant 1981 dollars. In some cases, the costs of the fuel cycle steps remain constant or decline with respect to time. This effect is caused by such factors as the presumed savings resulting from familiarity with the processes, or from the quantity of the system throughput. In other cases, particularly that of the uranium core, the costs may increase with time. In the inflation-free context of the EEDB Program, this increase is due to a change in the amount of effort required to extract ore from sources less rich in uranium, thereby reouiring additional processing steps or longer application of the same processing steps. In other words, the increase in cost arises from a real change in the amount of energy, labor and materials
- Refer to Section 3.1 for additional details.
6-16
i expended in producing the same product and quantity and is referred to as escalat' ion caused by scarcity. This is an attempt to distinguish it from escalation caused by inflation, which represents a change in the value of money, rather than a change in the cost of the process. To illus-trate the effect of input unit cost changes on fuel cycle costs, sensitivity studies were reported in NUS-3190. These are included in the Initial Update of the EEDB*. This work shows the impact of a change in a particular fuel cycle step on the total fuel cost. 6.5.4.1 Data sources for Input Unit Costs , Although there are a number of references for projections of nuclear fuel cycle unit input costs, the one selected for this update of the EEDB is NUREG CR-1041, " Fuel Cycle Cost Projections," Battelle Pacific Northwest
/
Laboratories; December, 1979. This report addresses input cost projections for six LWR cases. The projections represent three nuclear electric growth rates for a "once-through" fuel cycle environment and three nuclear electric growth rates for a " recycle" environment. The ground-rules for the Fourth Uodate of the EEDB specify a "once throuah" cycle for the LWRs, HTGR and PHWR cases and the initiation of repro-cessing for the LMFBR. case to the extent necessary to support their operation. Therefore, the input unit costs for U 30o, conversion, fabri-cation and spent fuel shipping are taken from the case for a "once-through" fuel cycle with medium nuclear growth for all reactors. The reprocessing and high level waste disposal input unit costs for the LMFBR,are adapted from
~
the estimates of these costs for LWR fuel, as given in the case for
" recycle" with medium nuclear growth. All unit cost projections in
- Refer to Section 8.1 for additional details 6-17
NUREG CR-1041 are based on zero inflation rate. 6.5.4.2 Adaptation of Input Unit Cost Data ' The input costs given in NUREG CR-1041 are given in constant 1979 dollars. The Fourth Update of the EEDB adjusts all of the nuclear fuel cycle input costs components (except for U 0 ) fr m 1979 t 1981 dollars by applying 38 en escalation factor of 10 percent per year. Because of the current uncertainties associated with prediction of U pricing, this component is dealt with 38 differently, as discussed in Section 6.5.4.3. Although NUREG CR-1041 uses a 4 percent discount rate, for its fuel cycle calculations, the Fourth Update Groundrule fo'r the' discount rate cites a value of 3.5 percent. Therefore, the present worth calculation performed
, s on the adjusted unit input cost projections utilizes a discount rate of 3.5 percent as part of the levelized price calculation. The input unit values 31ven in the "a". tables (the "a" series of Tables 6-4 through 6-11) in this section are given in constant 1981 dollars. The output costs given in the "b" tables (the "b" series of Tables 6-4 through 6-11) in this section are the levelized fuel cycle costs.
Since the NUREG CR-1041 input data applies only to the LWR, it is necessary to adapt these inputs to create input unit costs for the.HTGR, PHWR, and LMFBR reactors. This is accomplished by using the NUS-3190 data to develop ratio's between non-LWR reactors and LWR reactors for various fuel cycle steps. These ratio's are then applied to the appropriate LWR input unit costs to develop non-LUR ir.put unit costs. 6-18
6.5.4.3 Discussion of U33 0 Costs For non-breeder reactors , the cost of U380 is th'e largest contributor to the total nuclear fuel cost. This is particularly true when the' reactors are coupled with a "once-through" fuel cycle. Changes in the cost of U 38 0 """ the largest impact on these reactor cycle combinations. l l More U 0 is consumed nationally during the thirty year life of a power 38 generating station under a "once-through" scenario than is consumed under a
" recycle" scenario. This results in a faster depletion of known uranium reserves for the "once-through" cycle. Therefore, the price of uranium during the life of a power plant should experience a larger escalation rate during a "once-through" case than during the " recycle" case, because of an incremental escalation associated with faster depletion of the reserves. In addition, if the deployment of nuclear power generating stations is very rapid, the demand for uranium increases the consumption of the lower cost reserves faster than if a medium or low deployment rate occurs.
NUREG CR-1041 recognizes these relationships by giving projections for six l scenarios; three involving a "once-through" cycle and three involving a l
" recycle" scenario. The uranium cost projection based on a "once-through" cycle for all LWRs and a medium expansion rate in nuclear power plants is selected for the Fourth Update. It is, over the period examined, considerably l higher than the recycle environment for LWRs with a medium expansion rate in nuclear power plants. Consequently, it is considered a conservative selec-tion for use in comparing the "once-through" fuel cycle costs with coal alt e rna tive s .
6-19
The U 3g 0 cost projection is adjusted in the Fourth Update to account for the reduction in U 0 demand that began during 1980 and is continuing in 1981. 38 It is believed that this phenomenon is driven by a lack of new nuclear plant orders and the continued postponement and cancellation of plants on order. The adjustment consists of moving the U 038 cost projection curve from NUREG CR-1041 forward in time by two years to account for the aforementioned factors. Thus, in the Fourth Update, the NUREG CR-1041 price in 1979 dollars predicted to occur in the year 2000 is delayed until the year 2002. In addition, the 1979 prices given in NUREG CR-1041 for 38 U 0 are n t escalated as are the input unit cost projections for the remainder of the fuel cycle steps.
' tee' U3g0 costs adopted from NUREG CR-1041 for the Fourth Update are considerably higher than that developed for the Initial Update of the EEDB. This is due, in part, to the development of a single average cost curve for U 0 in the 38 Initial Update, for use with both "once-through" and " recycle" operation modes.
The NUREG CR-1041 study develops separate "once-through" and " recycle" scenario curves. Because of the current lack of policy on reprocessing, the NUREG CR-1041 "once-through" curve is the only realistic choice for the non-breeder reactors in the Fourth Update. A general perception has been in vogue that the cost of uranium concentrate (U38 0 r " yell weake") will increase over the next half century. This assump-tion arises f rom the very large increase in the forward price of U 0 , which 38 occurred af ter the 1973 oil embargo and which was aggravated by the difficulties encountered by one of the major nuclear fuel suppliers in meeting its commit-ments. The price of U 0 r se by a factor of six in the space of three years. 38 In addition, projections of installed nuclear capacity in the early 2000 time-frame were higher during the mid-seventies than they are now. 6-20 _ _ _ .- ,y, _ -- - ~. , _
Subsequently, a nu=ber of external factors are tending to lower the price of U0. A g these are the discovery of very large and rich new uranium depo-38 sits in Australia and Canada, the settlement of the suits brought against the major fuel supplier who could not meet commitments and the reduction in the projections of installed nuclear capacity in the early 2000 time period. In fact, the 1981 price of uranium in current dollars.has declined to almost half the 1978 price. It has fallen much further in terms of constant dollars. e. It can be seen that the forecasting of future fluctuations in the cost of "yellowcake" is complicated by the political, economic and demand uncertainties associated with nuclear energy. Projections for the Fourth Update are based on conservative and reasonable assumptions, that account for the factors dis-cussed above. Projected U 03 8 prices are given in Table 6-14. 6.5.5 Description of Reactor Types and Their Fuel Cycles A description of the reactor types and their associated fuel cycles prepared for the Initial Update of the EEDB is included in Appendix F. This description includes the reactor-fuel cycle combinations being updated in the Fourth Update of the EEDB. It also includes descriptions of some cycles, which are deleted by the Third Update.
/
As noted earlier, the differences between the two LWR types, the Boiling Water Reactor and the Pressurized Water Reactor, have a relatively insignificant effect on the overall fuel cycle costs. Consequently, it is assumed during this analysis that the data developed for the PWR case also apply to the BWR case. 6-21
The descriptions of the reactor-fuel cycle combinations in Appendix F, . which form the basis for the fuel cycle costs, are based on preliminary NASAP data. Final data is published in Volume IX of the NASAP study. DOE /NE-0001/9. . The rated powers of the nuclear systems listed in Table 1-1 differ in some cases from the nominal thermal powers listed for the preliminary NASAP systems. However, the mass flow relationships remain unchanged for a determinate reactor type over a relatively large range of output power. Thus, although the total mass of fuel used (200 MIU vs 150 MIU) is dif ferent for two PWRs of different thermal power, the level of initial enrichment (3%), the average burnup (30,000 mwd /T) and the heat rate (10,200 Btu /kWh) are approximately the same. Therefore, the total cost of fuel is different, but the specific costs in
$/M3tu or mills /kWh are the same for the same portions of the nuclear fuel cycle. Consequently, the dif ferences between the EEDB nuclear system's rated power and the preliminary NASAP nominal rated power do not affect the calculated costs of the nuclear fuel cycle for the reactor types studied.
6.5.6 Nuclear Fuel Cvele Cost Results Nuclear fuel cycle costs are prepared for the reactor-cycle cases of interest in the Fourth Update of the EEDB for a cost and regulation date of January 1, 1981. These calculations use unit input data adapted f rom NUREG CR-1041 and an approximate method of nuclear fuel cycle calculation. 6.5.6.1 Detailed Results The details of the input unit costs used for each case and the fuel cycle component costs are given in Tables 6-4a/4b through 6-11a/11b. 6-22
6.5.6.2 Summary Results A summary of the 30-year levelized fuel cycle costs are given in Table 6-16 for the reactor types listed in Table 1-1. Both direct and indirect costs are given separately, as well as the total levelized cost, extending over the 30-years of plant operating life, beginning with the year of startup noted. Table 6-17 gives the breakdown of the levelized costs by individual cost component for various options in the fueling mode of the different reactor types. Note that for both tables, the breeder reactor cases involve a zero i bred-fuel value. The total 30-year levelized fuel cycle cost in $/MBtu and l' m/kWh for the base reactors and their fueling modes is given in Table 6-18. Table 6-19 shows the percentage of the total costs attributable to each cost component. For the thermal neutron spectrum reactors (LWRs, HTGRs, and PHWRs), the uranium supply is the largest single cost. This category includes the U0' ""*#8 "* and enrichment to the desired concentration of U-235 38 6 (or U-233). For the fast neutron spectrum reactors, such as the LMFBR, the uranium vupply cost is shown as zero. The intended fissle fuel is T Pu and no value has been assigned to the enrichment processing tails or the depleted uranium recovered in reprocessing, either or both of which constitute the fertile portions of the cores and blankets. 6-23
6.5.6.3 Censiderations Surrounding the Nuclear Fuel Cvele Cost Fourth Update The principal fuel cycle cost experience is derived from operations with the LWRs. With the exception of the costs for uranium oxide fuel and enrichment prior to reactor operation, there is very little experience accessible for the remaining reactor fuel cycles. The government's current policy, not to pe rmit reprocessing of LWR fuel, leaves the back-end of the LWR fuel cycle and its costs open to uncertainty, since there is no experience to support t' e projections, except reprocessing of naval reactor cores and weapons material. The fuel cycle costs presented in this section are, therefore, based as far as possible upon the past history of the light water reactors and the prevailing disposition of the uranium-oxide market. All of the values presented here represent points taken in a band of varying costs whose limits are not well defined and whose actual range is uncertain at this time. Despite these shortcomings, which are inherent in the current conditions of nuclear energy in the United States, the costs presented in this study permit an evaluation of: e Comparison of different reactor types with each other. l e Comparison of different reactor types with alternatives l It must be emphasized that the data on costs permit comparison rather than the establishment of absolute values in the market place. Unless it is explicitly stated ctherwise, all costs presented assume zero inflation and are given in terms of constant 1981 dollars. 6-24
a 6.6 COAL COSTS 6.6.1 Introduction l Coal costs are needed to assess the economics of coal-fired steam supply systems for central electric generating stations. Unlike the nuclear fuels, which are treated as quasi-capital investments with depreciation and potential - salvage factors, cosi is a consumable cost item. Although coal is often treated as an operational cost, the costs of coal are presented in this study as separate items of expense, to facilitate the economic comparison of nuclear and coal energy sources for production of electricity. Nuclear fuels are designed and fabricated to match reactor operating characteristics. ' Coal-fired boilers and associated systems, however, are designed to operate on existing coals with generically similar characteristics. For economic reasons, the selection and procurement of long-term coal supplies are frequently made concurrently with, and largely determirm, the. design of the coal-fired steam supply for the generating station. The costs of coal are determined principally by: ! a. the costs of extraction from the ground; and, t b. the costs of transportation to the site of use. Coal in the United States varies widely in its characteristics, its accessi-bility, and its geographic distribution. This variability directly affects the costs to the user. The average calorific value of the coal, its sulfur content, the extraction method dictated by its underground location, and its distance from the user, all af fect costs. It is not reasonable to expect, l therefore, a single, clearly defined coal price. 6-25
6.6.2 Coal Cost Estimate The coal costs for plants having startup in 1981 are shown in Table 6-13a. These values include the results of the United Mine Workers (UMW) strike settlement, concluded in the first quarter of 1978. The 1981 coal miner's strike occurred after the cost and regulation date of the Fourth Update (1/1/81). Incorporation of the effects of the 1981 UMR strike settlement will be included in future updates. Values are also given for plant startups in 1987 and 2001 in Tables 6-13b and 6-13c. Table 6-20 shows the increase in the average delivered contract coal pricesfortheyear1980,up.cotheYourthUpdatecostandregulationdate of January ,1, 1981. The intent of the coal cost estimate is to provide costs for the years 1981, i 1987 and 2001, in terms of constant 1981 dollars. The assunption is made that the levelization factor for coal costs is one, in each of the years of interest, because coal is assumed to be plentiful in that year. However, costs are escalated from 1981 to each of the startup years to reflect a degree of conservatism relative to the overall availability of coal in the future. 6.6.3 Data Sources Used for Coal Costs Data for the coal costs were derived from studies by Electric Power Research Institute, by A. D. Little, by Paul Weir Company, and by United Engineers & Constructors, Inc. , based on Federal Energy Regulatory Commission information, as referenced in Section 3.4.2b. 6.6.4 Productivity, Escalation and Inflation The estimates provided include allowances for increases in costs resulting from known conditions such as productivity decreases at the mines and increased 6-26
difficulties in mining methods, which reflect larger expenditures of energy cnd manhours. This approach is somewhat pessimistic since it ignores possible increases in productivity; however, recent industry experience shows a marked decline in productivity beginning in 1970. This fact is documented in FPRI Report No. EA-634-SR, entitled, " Supply 77-EPRI Annual Energy Supply Forecasts", published in 1978. Inflation, which is understood as the change in the value of money, is expli-citly excluded. The value of escalation for scarcity is also excluded, even though it is understood that the cost of coal may rise to the level of competitive fuels, except as discussed in Section 6.6.2 above. 6.6.5 Coal Transportation Costs, Transportation mileage costs for coal in selected cases represent a major contribution to the total coal costs to the utility. These costs are in-fluenced by whether the coal cars and locomotives are owned by the carrier or by the user / shipper and whether eastern or western railroads are used. Costs for transportation are of ten equal to the mine-mouth costs, especially when coal is transported over 1,000 rail-miles. In the Fourth Update of the EEDB, the following assumptions are made:
- a. The coal-fired plants are located at sites assumed to be 500 miles and 2,000 miles from the coal mine. The location of the hypothetical "Middletown" site is 2,000 miles from a western low sulfur coal mine and 500 miles from an eastern high sulfur coal mine.
- b. All transportation equipment used belongs to the carrier.
- c. Unit trains of 100 cars, at 70 to 100 tons per car, or 7,000 to 10,000 tons per unit train, are used in each shipment.
- d. Mileage ecsts are computed from rail rates provided by the Interstate Commerce Commission for eastern and western railroad routes.
l 6-27 l l l
6.6.6 Characterization and Analysis of Coals The two significant characteristics and analyses of coal for establishing costs are:
- a. calorific / heating value in Btu /lb, and
- b. impurity content; sulfur content in percentage points.
These two characteristics determine the price paid for coal by the utility. The analyses for the eastern and western mined coals discussed in this update are shown in Tables 6-21, 6-22, and 6-23. The concern over the reactions from'SO and NO with water in the atmosphere 2 x to form both sulfur and nitrogen oxide is increasing, because they potentially have a deleterious effect on plant life and aquatic species. The effluents from burning coals used in the Fourth Update require scrubbing and particulate collection in various degrees. The coal-fired FPGS Technical Models include design features to accomplish the necessary scrubbing and particulate collection. Hodever, costs for these design features are included in the capital costs and, therefore, do not contribute to coal fuel costs. Design features for stack effluent treatment for NOxare not included. The selection of a hypothetical plant site in the northeastern U.S. fcr low-or high sulfur FPGS has placed a burden on western coals, since the largest
- costs are for rail delivery of these coals. Since the Middletown site is 2,000 miles from the low-sulfur coal mine, but only 500 miles from the high-sulfur coal mine, eastern coals are favored over western coals in terms cf total energy costs.
6-28
% I TABLE 6-1 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE FUEL COST UPDATE
SUMMARY
- 2001 STARTUP (c/MBtu) * -
Nuclear Plant Models Comparison Plant Models Model BWR HTCR-SC PWR PKWR HTCR-PS LMFBR HS12 HS8 LS12 LS8 CCCC MWt 3578 2240 3412 3800 1170 380d 3302 2210 3446 2307 1523 MWe 1190 858 1139 1260 150 1457 1240 795 1244 795 630 { Fuel Cost 77( } A0(b) 77(b) 33(b) 80
- 224 224 96 96 231 Fabrication Cost 7(C) 5 7 6 5 15 Transportation 1(c) 2 1 1 2 4 68 68 Cost- 282 282 57 Reprocessing * * * *
- 24 * * * *
- Disposal Cost 3 fC) 2 3 2 2 1 + + + + +
e TOTAL 88 89 88 42 89 44 292 292 378 378 288
- Not Applicable
+ Disposal Costs for Coal-Fired Plants are Included in O&M Costs, Se ni<,n 7 (a) Data in Constant $1981 (Inflation-Free)
(b) Cost of U 038 (c) Complete BWR data are not Available; therefore, PWR Data are used for BWR (Model A1) Fuel Cycle Costs
TABLE 6-2 Effective Date - 1/1/82 ENERGY ECONOMIC DATA BASE FUEL COST UPDATE SIRetARY - 1981 STARTUP (C/MBtu)(* Nuclear Plant Models Comparison Plant MeJels Model BWR PWR HS12 HS8 LS12 LS8 MWt 3578 3412 1302 2210 3446 2307 MWe 1190 1139 1240 795 1244 795 i $ Fuel Cost 56 56 137 137 64 64 Fabrication Cost 7( 7 * * *
- Transportation Cost 1(b) 1 50 50 208 208 Disposal Cost 3 b) 3 , , , +
TOTAL 67(b) 67 187 187 272 272
- Not Applicable
+ Disposal Costs for Coal-Fired Plants are Included in 06M Costs, Section 7 (a) Data in Constant $1981 (Inflation-Free)
(b) Complete BWR Data are not Available; therefore, PWR Data are used for BWR (Model Al) Fuel Cycle Costs
TABLE o-3 Effective D' ate - 1/1/81 ENERCY ECONOMIC DATA BASE FUEL COST UPDATE
SUMMARY
- VARIABLE STARTUP (c/MBtu)
- Nuclear Plant Models Coal Plant Models Model BWR( } HTCR-SC(" PWR PHWR("} HS12 b) HS8 b) LS12(b) LS8(b) CCCC b)
HWt 3578 2240 3412 3800 3302 2210 3446 2307 1523 NWe 1190 858 1139 1162 1240 795 1244 795 630 Fuel Cost 61 73 61 29 166 166 75 75 170 Fabrication Cost 6(d) 6' 6 6 * * * *
- Transportation Cost 1( } 2 1 1 59 59 245 245 49 Disposal Cost 3( } 2 3 2 + + + + +
TOTAL 71(d) 83 71 38 225 225 320 320 219
- Not Applicable
+ Disposal Costs for Coal-Fired Plants are Included in O&M Costs, Section 7 (a) Data in Constant $1981 (Inflation-Free)
(b) 1987 Startup (c) 1995 Startup (d) Complete BWR Data are not Available; therefore, PWR Data are used for BWR (Model A1) Fuel Cycle Costs s
\
Effective Datet Jrnum , 1. 1981 TABLE 6-4a * (1) SYItem 1
~ PN ~US(1.E RU [
Start Up : Janua ry 1. 19813 ENERCT t.CONOMIC DATA BASE INFUT NUCLEAR FUEL COST COMPONENTS No Escalation Constant January 1.1981 Dollars j SW9tARY OF INPUT QUANTITIES BY CALENDAR TEAR (FIVE YEAR PERIODS) { Account No. Apcount Description Unite 193J 1985 1990 1995 2000 2005 2010
.10 Inttital Fuel Loaded $/KgH
.!! Uranium Supply $/KgU
.111 U03 3 Supply $/lb U 30g 43 43 43 43 47.7 57.3 69.7
.112 UF6 Conversion Se rvices $/KgU aa UF6 6.3 6.3 6.3 6.3 6.3 6.3 6.s
.113 Enrichment Services $/SWU 107.7 108.9 108.9 !!6.2 134.3 136.7 136.7
.114 Depleted U Supply $/EgU
.12 Plutonium Supply Parity value
.13 U-233 Supply Parity value
.14 Thorium Supply $/KgM
.20 Fabrication $/KgH 145.2 145.2 147.6 148.8 147.6 146.4 145.2
.21 Core Fabrication $/KgH y .22 Axial Blanket Fabrication $/KgH g .23 Radial slanket Fabrication $/KgH
.30 Shipping to Temporary Storage $/KgH
.40 Temporary Storage $/KgH ,
.50 Shipping to Repository $/KgH 29,0 29.0 26.6 26.6 24.2 21.8 21.8
.60 Disposal of Spent Fuel $/KgH 154.9 154.9 154.9 154.9 154.9 154.9 154.9 1
(1) See Table 6-12 for System Designation ,
s Effective Datet J*nua. 1981 (1) Syst,. PWR-US(La)/U-T TABLE 6-4b Start Up : Jsnuary 1, th T ENERGY ECONOMIC DATA SASE l OUTPUT NUCLEAR FUEL COST COMPONENTS , No Escalation Constant January 1, 1981 Do11 era otTTPUT QUANTITIES. 30- YFAR LEVELIZED $/MBru Direct Indirect Total ) Account No. Account Description Cost Cost Co s_t, i ) .00 Total 0.63 0.04 0.67
.10 Initial Fuel Imaded .
.11 Uranium Supply
.111 U30g Supply 0.29 0.02 0.31
~{ .112 UF6 Conversion Services 0.01 n.no n.nl
.113 Enrichment Services 0.22 0.02 0.24
.114 Depleted U Supply
]
.12 Pluto,ntum Supply
.13 U-23J Supply '
.14 Thorium Supply
.20 Fabrication 0.06 0.01 0.07
.21 Core Fabrication
, y .22 Axial Blanket Fabrication w
.23 Radial Blanket Fabrication
.30 Shipping to Temporary Storage
.40 Temporary Storage
.50 Shipping to Repository 0.01 0.00 0.01
.60 Disposal of Spent Fuel 0.04 (0.01) 0.03 (1) See Table 6-12 for System Deetsnation.
l ! s 4 1 I 4
I
- UNITED ENGINEERS & CONSTRUCTO35 INC. SUMMI.RY PAGE 1 PLANT CODE COST BASIS ENERGY ECONOMIC OATA BASE (EEOR) PHASE IV 660 01/81 630 MWE COAL GASIFICATION COM8INED CYCLE 08/2f/89 FACTORY SITE SITE SITE TOTAL ACCT NO ACCOUNT DESCRIPTION EQUIP. COSTS LABOR HOURS LABOR COST MATERIAL COST COSTS 20 LAND AND LAND RIGHTS 687.500 687.500 21 STRUCTURES + IMPROVEMEN15 2.438.046 753354 mi 99.165.122 16,744.183 30.340.351 22 GASIFIER / BOILER Pli EQUIP. 122.522.305 281806G mt 47.022.456 2.885.027 172.429.788 23 IURBINE PLANT EQUIPMENT 108.826.636 1848800 mt 30.979.026 2.324.910 142.130.572 24 ELECTRIC PLANT EQUIPMENT 7.595.80s 1034496 24 16.897.777 9.539.192 34.032.770 25 MISCELLANEOUS PLANT EQUIPT 2.106.461 176640 24 2.952.447 509.236 5.568.144 26 MAIN COND HEAT REJECT Sv5 7.379.650 ft9658 mt 1.892.067 498.913 9.762.630 TOTAL DIRECT COSTS 250.853.899 6751094 24 100.908.895 33.188.961 394.959.755 91 CONS 1RUCilON SERVICES 23.I10.285 993950 mt 16.420.0J6 21,754.000 69.284.251 92 HOME OFFICE E NGRG. &SE RVI CE 20,625.660 20.625.660
- 93 F IELD OF FICE ENGRG& SERVICE 94.561.140 9.234.200 15.795.340 TOTAL INDIRECT COSTS 58.297.015 993960 24 16.420.036 22.988.200 97.705.251 TOTAL BASE COST 309.850.994 7744974 MH 127.328.931 56.177.161 492.657.006 b
s Effs:ctive Datet Jtem a3 ITSI
] TABLE 6-5b (1) System a rwa-US(LE)/U-T _
Start Up t January 1. 1987 ENERCT ECOMONIC DATA BASE OUTPUT NUCLEAR flJEL COST COMPONENTS Mo Escalation Constant January 1. 1981 Dollara OUTPUT QUANTITIES, 30- YFAR LEVELIZED $/MBtu Direct Indirect Total Account No. .m: count Description Coat Cost Cost
.00 Total 0.62 0.04 0.21
.10 Initial Fuel loaded
.11 Uranius Supply
.111 U30g Supply 0.32 0.03 0.15
.112 UF6 Conversion Servicee 0.01 0.00 0.01
.113 Enrichment Services 0.23 0.02 0.25
.114 Depleted U Supply
.12 Flutonium Supply U-233 Supply *
.13 I
.14 Thorium Supply
.20 Fabrication 0.06 0.00 0.06
.21 ra re Fabrication f
.22 Aalal Blanket Fabrication
.23 Radial Blanket Fabrication
, .30 Shipping to Temporary Storage
; .40 Temporary Storage v- .50 shipping to Repository 0.01 0.00 0.01
.60 Disposal of Spent Fuel O.04 (0.01) 0.03 (I) See Table 6-12 for System Designation.
J f 1 l l l l l l I
Effective Date: Janus., 1. 1981 TABLE 6 6a (1) System : PWR-US(LE)/U-T Start Up : January I 2001 ENERGY 1.CONOMIC DATA SASE INFUT NUCLEAR FUEL CDST COMPONENTS No Escalation Constant January 1, 1981 Dollera f StRetARY OF INPUT QUANTITIES BY CAIRDAR YEAR (FIVE TEAR FER100$) Account No. Account Description Unita 2000 2005 2010 2015 2070 2025 2030
$/EgH I
.10 lattital Fuel leaded
.11 Urantin Supply $/FgU
.111 U033 Supply $/lb U 30g 47.} 57.3 69.7 84.8 91.4 91.4 91.4
.112 $/EgU as UF6 6.3 6.3 6.3 6.3 6.3 6.3 6.3 UF6 Conversion Services 136.7 135.5 133.1 133.1 131.9
.113 Enrichment Services $/SWU 134.3 136.7
.114 Depleted U Supply $/KgU
.12 Plutonitse Supply Parity value
.13 U-233 Supply Parity value
.14 Thortus Supply $/EgH
.20 Fabrication $/KgH I47.6 146.4 145.2 145.2 148.8 146.4 146.4
.21 Core Fabrication $/KgH
, .22 Antal Blanket Fabrication $/ESH e .23 Radial Blanket Fabrication $/KgH 5 .30 Shipping to Temporary Storage $/KgH i l
.40 Temporary Storage $/KgM
.50 Shipping to Repository $/KgH 24.2 21.8 21.8 19.4 19.4 16.9 16.9 l
.60 Disposal of Spent Fuel $/KgH 154.9 154.9 154.9 154.9 154.9 154.9 154.9 (1) See Table 6-12 for System Designation 1
l
_ -._ .-- . - _ - _ _ _ . _ . . . _ _ _ _ . - - . _ _ . _ . - . . . ~. - ~ _ . .. _ . . Effective Date: Jutu. . 19fL Tt.BLE 6-6b (1) System t FWB-US(LE)/U-T Start Up t Jrnuarv 1, 2001 ENERGT ECONOMIC DATA BASE OLTTPUT NUCLEAR FUEL COST COMPONENTS No Escalation Constant January 1, 1981 Dollars OtrTPUT QUANTITIES. 30- TEAR LEVELIZED $/MBru Direct Indirect Total Account No. Account Description Cost Cost Cost I .00 Total 0.82 0.06 0.88
.50 Initial Fuel Imaded
.11 Urant e Supply r
.311 U3 0g Supply 0.45 0.04 0.49
.112 UF6 Conversion Services 0.01 0.00 0.01
.113 Enrichment Services 0.25 0.02 0.27
.114 Depleted U Supply
.12 Plutoniten Supply
.13 U-233 Supply -
.34 Thorium Supply
.20 Fabrication 0.06 0.01 0.07
.21 Core Fabrication
! . .22 Amiel Blanket Fabrication i 1
.23 Radial Blanket Fabrication j .30 Shipping to Temporary Storage j .40 Temporary Storage
' .50 Shipping to Bepository 0.01 0.00 0.01 .
.60 Disposal of Spent Fuel O.04 (0.01) 0.03 6
(1) See Table 6-12 for System Designation. t t I i t t I 1
-s Effective Data Janua., 1. 1981 TABLE 6-7a (1) Sy' tem t HTCD-U5/U/Th-?O4-T Start Up : January 1. 1995 ENERGY trXiNOMIC DATA BASE INFUT NUCLEAR FUEL COST COMPONENTS No Escalation Constant January 1,1981 Dollars SteetARY OF INFUT QUANTITIES ST CALENDAR YEAR (FIVE YEAR PERIDOS)
Account No. Account Description Units 1995 2000 2005 2010 2015 2020 2025
.10 Inititel Fuel Loaded $/K35
.11 Uranium Supply $/EgU
.111 U30g Supply $/lb U 30s 43.0 47.7 57.3 69.7 84.8 91.4 91.4
.112 UF6 Conversion Services $/EgU as UF6 6.3 6.3 6.3 6.3 6.3 6.3 6.3
.113 Enrichment Services $/SWU 116.2 134.3 136.7 136.7 135.5 133.1 133.1
.114 Depleted U Supply $/KgU
.12 Flutonium Supply Parity value
.13 U-233 Supply Parity value
.14 Thorium Supply $/EgH
.20 Fabrication $/EgH 394.2 391.0 387.8 384.6 384.6 394.2 387.8
.21 Core Fabrication $/KgH
.22 Axial Blanket Fabrication $/KgH
.23 Radial Blanket Fabrication $/KgH j, .30 Shipping to Temporary Storage $/EgH os .40 Temporary Storage $/EgH
.50 Shipping to Repository $/EgH 415.6 378.1 340.6 340.6 303.1 30 3.1 264.1
.60 Disposal of Spent Fuel $/EgH 427.6 427.6 427.6 427.6 427.6 427.6 427.6 (1) See Table 6-12 for System Designation
- - .~.
. - - - . - . ~ _ - -
j , Effective Date: Jag 1981_ TABLE 6-7b (1) System HTCR-U5/U/Th-201-T i Start Up Anuary I. 199f' i DsERCT ECONOMIC DATA BASE
! OUTPUT NUCLEAR FUEL COST COMPONENTS No F.scalation Constant January 1. 1931' Dollars OUTPUT QUANTITIES, 30- TEAR LEVELIZED $/MBtu Direct Indirect Total Account No. Account Description Cost Cost Cowt
.00 Total 0.76 0.07 0.83 .
.10 Initial Fuel loaded
.!! Uranism Supply
.111 U033 Supply 0.34 0.03 0.37
.!!2 UF6 Conversion Services 0.01 0.00 0.01
.113 Enrichment Services 0.33 0.02 0.35
.114 Depleted U Supply
.12 Plutonisms Supply -
e i .13 U-233 Supply
.14 Thortian Supply 1 .20 Fabrication 0.04 0.02 0.06
.21 rare Fabrication
.22 Antal Blanket Fabrication
.23 Radial Blanket Fabrication ,
.30 Shipping to Temporary Storage
, .40 Temporary Storage I i .50 Shipping to Repository 0.02 0.00 0.02
* .60 Disposal of Spent Fuel 0.02 0.00 0.02 l
i i (1) See Table 6-12 for System Designation.
. [
T ll l ) i i i I i { l
- - _ -.~ .- .
f Effective Date: J tn ua s , . . . _198 t _ _, TABl.E 6-Ba (1) syttes : HTCR-U5/U[Th-20T-T Start Up 18%'u ry 1. 2001 ENERGT EtX)NOMIC DATA BASE INPUT NUCLEAR FUEL COST COMPONENTS No Escalation Constant January 1, 1981 Dollars SUP9tARY OF INPUT QUANTITIES BY CALDIDAR YEAR (FIVE YEAR PERIODS) Account No. Acco un t Description Unite 2000 2005 2010 2015 2020 2025 2030 i
.30 Initital Fuel Loaded $/KgH
.11 Uranium Supply $/KgU
.111 U05 8 Supply $/lb U 038 47.7 57.3 69.7 84.8 91.4 98.4 91.4
.112 UF6 Conversion Services $/KgU as UT6 6.3 6.3 6.3 6.3 6.3 6.3 6.3
.113 Enrichment Services $/SWU 134.1 136.7 136. 7 135.5 133.I 133.1 131.9
.114 Depleted U Supply $/KgU
.12 Plutonium Supply Parity value
.13 U-233 Supply Parity value
.14 $/KgH Thorium Supp23ly
.20 Fabrication $/KgH 391.0 1A7.R 1A4.6 1R4.6 104.2 347.8
$/KgH 347.8
.21 Core Fabrication
.22 Antal Blanket Fabrication $/KaN T' .23 Radial Blanket Fabrication $/KgH o .30 Shipping to Temporary Storage $/KgH
.40 Temporary Storage $/KgH
, .50 Shipping to Repository (2) $/KsH 378.1 340.6 340.6 303.1 303.1 264.I 264.1
.60 Disposal of Spent Fuel $/KgH 427.6 427.6 427.6 427.6 427.6 427.6 427.6 (1) See Table 6-12 for System Designation (2) Initial Core Fuel / Reload Fuel i
'I 1
.. . . _ ._ ~ - . . . _ _ . . .- _-
Effectiva Date Jrnu .g 1981 TAsLE 6-8b - (1) Sygtee ECR-UjlU/Th-20%-T Start Up J<nuary 1. 2001 ENERCT ECONOMIC DATA BASE OUTPITT NUCLEAR FUEL 0)ST COMPONENTS No Escalation Constant January 1.1981 Dollar's OUTPtrf QUANTITIES, 30- YEAR LEVELIZED $/MBtu Direct Indirect Total Account No. Account Description Cost Cost Coat
.00 Total 0.84 0.05 0.89
.10 Initial Fuel tonded f
.11 Urantun Supply
! .111 U038 Supply 0.40 0.03 0.43
.112 UF6 Conversion Services 0.01 0.00 0.01
{
.113 Enrichment Services 0.34 0.02 0.36
.114 Depleted U Supply
.12 Plutonisse Supply
.13 U-233 Supply ,
.14 Thoritse Supply
.20 Fabrication 0.05 0.00 0.05
.21 tere Fabrication i .22 Axial Blanket Fabrication O .23 Radial Blanket Fabrication
.30 Shipping to Temporary Storage .
.40 Temporary Storage
.50 Shipping to Repository 0.02 0.00 0.02
.60 Disposal of Spent Fuel 0.02 0.00 0.02 (1) See Table 6-12 for System Designation.
l I s
\
i Y s
s , i l Effective Dats: Jtnu. 2_1 198(_, ] TABLE 6-9a (1) Systes : FHWR-US(SE)/U-T ENERGY EVONOMIC hATA BASE l INPUT NUCLEAk FUEL COST CONFONENTS No Escalation i Constant January 1.1981 Dollars 1 StD91ARY OF INFUT QUANTITIES BY CALD DAR YEAR (FIVE YEAR FERIODS) Account No. Accoun t Description Units 1995 2000 2005 2010 2015 2020 2025_ . .10 Initital Fuel Loaded $/EgH
.11 Uranium Scaply $/EgU
.111 U30s Supply $/lb U 30s 43.0 47.7 57.3 69.7 84.8 91.4 91.4
.312 UF6 Conversion Services $/EgU as UF6 6.3 6.3 6.3 6.3 6.3 6.3 6.3
.113 Enrichment Services $/SWU 114.2 134.3 136.7 136.7 135.5 133.1 133.3 i .114 Depleted U Supply $/EgU
.12 Flutonium Supply Farity value
.13 U-233 Supply Parity value
.34 Thorium Supply $/Egu
.20 Fabrication $/EgH 87.4 86.7 86.0 85.3 85.3 87.4 86.0
.21 Core Fabrication $/EgH
.22 Aalal Blanket Fabrication $/Egu i e- .23 Radial Blanket Fabrication $/EgH E .30 Shipping to Treparary Storage $/KgH
.40 Temporary Storage $/Egu l .50 Shipping to Repository $/EgH 20.0 18.2 16.3 16.3 14.6 14.6 12.7
.60 Disposal of Spent Fuel $/Egu 95.9 95.9 95.9 95.9 95.9 95.9 95.9 3
k I , (1) See Table 6-12 for System Designation f I .) I E I 9
Effsetive Date: Jrnua. 193' TAae.E 6-9b (1) System . t 31NR-Ube.)7U-T[1 Start Up : Jsnutry I. 1995 DERCT ECONOMIC DATA BASE - OUTPUT NUCLEAR FUEL COST COMPONENTS No Escalation Constant January 1,1981 Dollare OUTPUT QUANTITIES. 30 - YEAR LEVELIZED $/Matu Direct Indirect Total Account No. Account Description Cost Cost Cost,
.00 Total 0.30. 0.00 0.38
.10 Initial Fuel loaded
.11 Uranium Supply k
.111 U038 Supply 0.21 0.01 0.22 .
.312 t'F6 Conversion Services 0.01 0.00 0.0I l
.113 Enrichment Services 0.06 0.00 0.0f.
.114 Depleted U Supply
.12 Flutonium Supply ,
.13 U-233 Supply
.34 Thorium Supply
.20 Fabrication 0.06 '
0.00 0.06
.21 Core Fabrication
.22 Aatal Blanket Fabrication
.23 Radial Blanket Fabrication
[ . 30 Shipping to Temporary Storage w .40 Temporary Storage
.50 Shipping to Repository 0.01 0.00 0.01
.60 Disposal of Spent Fuel 0.03 (0.01) 0.02 l
l (1) See Table 6-12 for Systes Designation. , l l l l l
Effective Datet January au l98 L TABI.E 6-10a (1) Syrtem a FHWR US(SE)[U-T Start Up : January 1, 2001 INFLTI NUCLEAR FUEL COST GMFONENTS No Escalation Constant January 1. 1981 Dollars i S199tARY OF INFUT QUANTITIES BY CALENDAR YEAR (FIVE YEAR PERIODS) Ac count No. Account Description Units 2000 2005 2010 2015 2020 2025 2010
.10 Inititel Fuel Loaded $/EgH ,
.11 Uranium Supply $/EgU
.111 U03 8 Supply $/lb U 038 47.7 57.3 69.7 84.8 91.4 91.4 v1.4
.112 UF6 Conversion Services $/EgU as UF6 6.3 6.3 6.3 6.3 6.3 6.3 6.3
.113 Earichment Services $/SWU 134.1 136.7 136.7 135.5 133.1 133.1 131.9
.114 Depleted U Supply $/EgU
.12 Flutonium Supply Parity value
.13 U-233 Supply Parity value
.14 Thorium Supply $/EgH
.20 Fabrication $/EgH 86.7 86.0 85.3 85.3 87.4 86.0 86.0
.21 Core Fabrication $/EgH
.22 Aztal Blanket Fabrication $/Kg3
.23 Radial Blanket Fabrication $/EgH o, .30 Shipping to Temporary Storage $/EgH E .40 Temporary Storage $/EgH
.50 Shipping to Repository $/EgH IR.2 16.3 16.3 14.6 14.6 12.7 12.7
.60 Disposal of Spent Fuel $/EgH gg,g 95.9 95.9 95.9 95.9 95.9 95.9
(!) See Table 6-12 for System Designation i i 1 1 i
Effective Date JLn_ a. 1988 TABLE 6-10b (1) Systes PHWR-uS(SE)/U-T Start Up t Jrnuxty 1. 2001 ENERGY ECONOMIC DATA BASE OUTFUT NUCLEAR nlEL COST COMPONENTS No Escalation Constant January 1,1981 Dollars OUTFUT QUANTITIES. 30- TFAR LEVELIZED $/MBtu Direct Indirect Total Account No. Account Description Cost Cost Cost, Total - 0.42 0.00 0.42
.00
.10 Initial Fuel leaded
.11 Uranium Supply
.111 U038 Supply 0.25 0.01 0.26 0.01 0.00 0.01
.112 UF6 Conversion Services 0.06
.11) Enrichment Services 0.06 0.00
.114 Depleted U Supply
.12 Plutonium Supply *
.13 U-233 Supply
.14 Thorium Supply 0.06 0.00 0.06
.20 Fabrication
.21 Core Fabrication
.22 Axial Blanket Fabrication
.23 Radial Blanket Fabrication
.30 Shipping to Temporary Storage y .40 Tamporary Storage Shipping to Repository 0.01 0.00 0.01
* .50 0.02
.60 Disposal of Spent Fuel 0.03 (0.01)
(1) See Table 6-12 for System Designation.
_ . _ . _ . . _ . _ . _ _ . . _ _ ._. _ . _ . , _ _ _ - _ __ _ . - . _ _ . _ . _ . _ . . _ .._.-m . _ _ _ _ _ _ _ . _ _ . _ _ . _ _ _ . _. _.. 2 l i Effsctivs Date: J*nuary 1.19th TABLE 6-11a (II 87 '
- January 1. 2001
"#UIND Start Up 4
ENERCY ECONOMIC DATA BASE INPUT NUCLEAR FUEL COST COMPONENTS I No Escalation j Constant January 1,1931 Dollars SUpttARY OF INPUT QUANTITIES BY CALENDAR TEAR (FivE YEAR PERIODS) i Account No. Account Description Units 2000 2005 2010 2015 2020 2025 2030
.10 initial Fuel Loaded $/KgH -
.11 Uranium Supply $/KgU .
l U0 $/lb U 30g o 0 0 0 0 0 0 , .Ill 3g Supply .
.112 UF6 Conversion Servide9 $/KgU as UF6
.113 Enrichment Services $/SW i .114 Depleted U Supply $/KgU 0 0 0 0 0 0 0
.12 Plutonium Supply Parity value 0 0 0 0 0 0 0
.13 U-233 Supply Parity value
.34 Thorium Supply $/KgH
- .20 Fabrication $/KgH i .21 Core Fabrication $/KgH 641.3 636.0 610.A 630.R 646.5 636.0 6 36.0
! .22 Axial Clanket Fabrication $/KgH 40.9 40.5 40.2 40.2 41.2 40.5 40.5
.21 Radial Blanket Fabrication $/KgH 147.6 146.4 145.2 145.2 148.8 146.4 146.4 r l $/KgH
- , . 30 Shipping to Temporary Storage j i 40 Temporary Storage $/KgH 2
* .50 Shipping to Reprocessor $/KgH 142.2 128.1 128.1 114.0 114.0 99.3 99.3 j .60 Reprocessing $/KgH $09.0 435.6 361.9 ~ 347.6 341.4 341.4 341.4
.70 Disposal of Reprocessing Wastes $/KgH 364.8 364.8 364.8 364.8 364.8 364.8 364.8
.80 Final t'uel Recovered (Credits) - $/K3H
.81 Uranium $/KgH O' O 0 0 0 0 0 !
l
.811 Equivalent U 30g Supply $/lb U O3g
.812 Equivalent UF6 Conversion Services $/KgU
' .813 Equivalent Enrichment Services $/SW
.82 Fissile Plutonium Parity value 0 0 0 0 0 0 0 1 .83 Bred U-233 Parity value
.90 Refabrication of Recovered Fue! $/KgH f j
r 1 i' (1) See Table 6-12 for System Designation A 1 I i I l 4 2 i
\
Effsettve Date: INFBR-pu/U/u/u-HT JtnuM7_hQ81_ (1) System : Start Up : January 1. 2001
.. TABLE 6-Ilb ENERCY ECONOMIC DATA BASE OUTPUT NUCLEAR FUEL 0)ST COMPONENTS No Escalation Constant January 1,1981 Dotters OttfruT QUANTITIES. 30 - YFAR LEVELIZED $/NBru Direct Indirect Total Account No. Account Description Cost Cost Cost 0.43 0.01 0.44
.00 Total
.10 lattital Fuel loaded *
.31 Uranium Supply (2) h
.111 U038 Supply -- _ ,,
.112 UF6 Conversion Services
.113 Enrichment Services
.114 Depleted U Supply
.12 Plutonties Supply (3) .. ,_
.13 U-233 Supply
.14 Thorium Supply T .20 Fachrication(4) 0.01 U.12 Core Fabrication 0.!!
O .21 0.00 0.01
.22 Antal Blanket Fabrication 0.01 0.02 0.00 0.02
.23 Radial Blanket Fabrication
.30 Shipping to Temporary Storage
.40 Temporary Storage
.50 Shipping to Reprocessor 0.04 0.00 0.04
.60 Reprocessin8 1 0.24 0.00 0.24
.70 Disposal of Reprocessing Wastes' O.01 0.00 0.01
.80 Final Fuel Recovered (Credita)
.81 Uranium (2)
.811 Equivalent U 038 Supply
.812 Equivalent UF6 Conversion Services
.813 Equivalent Enrichment Services .
.82 Fissile Plutonium (3)
.83 Bred U-233
.90 Refabrication of Recovered Fuel (1) See Table 6-12 for System Designation (2) Final uranium value (account .81) is included in Urantins Supply (account .31) such that the value entered under account .11 represents the net uranium consumed.
(3) Final value of fissile plutonium (account .82 is included in Plutonium Supply (account .12) such that the value entered under account .12 represents the net fissile plutonium consumed. l (4) Includes fabrication of core, axial blanket and radial blanket (account .21, .22 and .23) l
Effective Date - 1/1/81 TABLE 6-12 ENERGY ECONOMIC DATA BASE' EXPLANATION OF FUEL CYCLE SYSTEM DESIGNATION (Refer to Tables 6-4 through 6-11) System Fuel Cycle Designation Reactor Type Fuel-Type Alternative PWR-US(LE)/U-T LWR (PWR & BWR) Low-enriched uranium (UO2 ) Throwaway HTCR-U5/U/Th-20%-T li1GR-SC & Medium-enriched uranium Throwaway llTGR-PS (20%) and thorium (UC2 -Th02 ) f PilWR-US(SE)/U-T (CANDU) PIIWR Slightly enriched (1.2%) Throvauay g; uranium (UO2 )
- LMFBR-Pu/U/U/U/IIT LMFBR Pu/ depleted uranium-core Recycle of plutonium in breeders and depleted uranium blankets (Pu0 2-UO 2/UO2/UO2 )
i
Effective Date: January 1, 1981 System : Coal-Fired FPCS(5) Startup : January 1, 1981 TABLE 6-13a ENERGY ECONOMIC DATA BASE COAL FUEL COST COMPONENTS No Escalation (Constant January 1, 1981 Dollars) Plant Type Coal Coal Costs (l) Transportation Costs (2) Total Model MWe Type (3) $/ tons $/MBtu $/t-mi(4) Miles S/ ton $/MBtu $/MBtu 11 S 1 2 1240' Ells 30.14 1.37 0.022 500 11.00 0.50 1.87 11 S 8 795 j - os LS12 1244 l 10.41 0.64 0.017 2000 34.00 2.08 2.72.
& L WLS LS8 795 l i
(1) Coal Costs are FOB Mine-mouth , l (2) Transportation Costs are " Delivered to User" t (3) ERS = Eastern (Iligh Sulfur) Coal; WLS = Western (Low Sulfur) Coal. Refer to Tables 6-21 and 6-22 for Coal Cdnstituents (4) $/t-mi = $ per ton-mile
- (5) FPGS = Fossil Power Generating Station l
Effectiva Date: January 1, aedl System : Coal-Fired FPCS(5) Startup : January 1, 1987 TABLE 6-13b , ENERGY ECONOMIC DATA BASE COAL FUEL COST COMPONENTS No Escalation (Constant January 1, 1981 Dollars) Plant Type Coal Coal Costs (I) Transportation Costs (2) Total Model HWe Type (3) $/ ton $/MBtu $/t-mi(4) Miles $/ ton $/HBtu $/MBtu 11512 1240 1 Ells 36.66 1.66 0.026 500 13.00 0.59 2.25 115 8 795 I LS12 1244 l p WLS 12.27 0.75 0.020 2000 40.00 2.45 3.20 , g LS8 795 i s CGCC 630 PilS 44.84 1.70 0.026 500 13.00 0.49 2.19 (1) Coal Costs are FOB Mine-mouth (2) Transportation Costs are " Delivered to User" (3) Ells = Eastern (lligh Sulfur) Coal; WLS = Western, (Low Sulfur) Coal; PilS = Pittsburgh Steam (Iligh Sulfur) Coal. Refer to Tables 6-21, 6-22, and 6-23 for coal Constituents (4) $/t-mi = $.per ton-mile (5) FPGS = Fossil Power Generating Station ,
Effective Date: January 1. 1981 System : Coal-Fired FPCS(5) Startup : January 1, 2001 TABLE 6-13c ENERGY ECONOMIC DATA BASE COAL FUEL COST COMPONENTS No Escalation (Constant January 1,1981 Dollars) Plant Type Coal Coal Costs (l) _ __Transpor'tation Costs (2) Total Type (3) $/ ton S/MBtu S/t-mil 41 Miles S/ ton $/MBtu $/MBtu Model MWe ilS12 1240 ' 0.68 2.92 Ells 49.32 2.24 0.030 500 15.00 115 8 795 j Tv' 1244 LS12 . 2000 46.00 2.82 3.78
~
WLS 15.75 0.96 0.023 13 8 795 j 2.31 0.030 500 15.00 0.57 2.88 CGCC 630 PilS 60.79 (1) Coal Costs are FOB Mine-mouth , (2) Transportation Costs are " Delivered to User" (3) Ells = Eastern (High Sulfur) Coal; WLS = Western (Low Sulfur) Coal; PilS = Pittsburgh Steam (Iligh Sulfur) Coal. Refer to Tables 6-21, 6-22 and 6-23 for Coal Constituents (4) $/t-mi = $ per ton-mile (5) FPGS = Fossil Power Generating Station l l l l l l l l L _______
Effective Date 1/1/81 TABLE 6-14 i ENERGY ECONOMIC DATA BASE PROJECTED U 3g0 COSTS l (January 1, 1981 Dollars) YEAR $/lb U 3gO 1981 through 43 1997 1998 44 1999 46 2000 48 2002 52 2004 55 j, 2006 60 . ( 2008 64 2010 70 2015 85 2020 91 2025 91 . 2030 91 3 I i l 6-52 i
TABLE 6-15 Ef fective Date - 1/1/81 ENERGY ECONOMIC DATA BASE
SUMMARY
OF FUEL CYCLE LEAD AND IAG TIMES (In Quarter-Years) ) (f) Lead Time (to reactor startup date) PRR HTGR PHWR FBR
- 1. Payment for U30g purchased ,
Initial core 7 7 5/5 (g)
- Reloads 4 4 2/4 (g)
- 2. Payment for Plutonium purchased Initial core -- -- --
5 Reloads (a) -- -- (h)
- 3. Payment for Conversion Services Initial core 5.667 5.667 -/- --
Reloads 2.667 2.667 -/2.667 --
- 4. Payment for Enrichment Services Initial core 5 5 -/- --
Reloads 2 2 -/2 --
- 5. Payment for Fabrication Initial core 2 2(d) 2/2 2 Reloads 1 L I) 1/1 1 Lag Time (from discharge date from reactor)
- 6. Payment for Spent Fuel Shipping 2/20(b) 2/20(b) 40/40 2
- 7. Payment for Reprocessing Services 2 2 -- 2
- 8. Payment for Waste Disposal 2 2 -- --
- 9. Payment for Spent Fuel Disposal 20 20 40/40 --
- 10. Receipt of Credit for l Uranium Recovered 3(c) 2 (* ) --
3 l
- 11. Receipt.of Credit for Plutonium Recovered 3(a) .. ..
30h) l l 6-53
TABLE 6-15 (Cont'd) Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE
SUMMARY
OF FUEL CYCLE LEAD AND IAG TIMES (In Quarter-Years) (a) For recycle alternative, recovered plutonium will be recycled to the subsequent cycles with a lag time of 2 cycle lengths (self-generated mode). (b) Recycle alternative / throwaway alternative. (c) For recycle alternative, recovered uranium will be recycled to the subsequent cycles with a lag time of 2 cycle lengths (self-generated mode). (d) Fabrication costs include material cost for TH02-(e) For recycle alternative, recovered uranium will be recycled to the subsequent cycles with a lag time of I cycle length (self-generated mode), based on CAC mass flows. (f) Natural uranium fuel cycle /slightly enriched uranium fuel cycle; (CANDU) . (g) It is assumed that makeup uranium is depleted uranium whose value is Zero. _ (h) Recovered plutonium will be recycled to the subsequent cycles with a ' lag time of 2 cycle lengths. Net plutonium gained or added will be sold at the lag time, or purchased at the lead time, respectively. i
\
6-54
TABLE 6-10 Ef fective Date - 1/1/81 ENERGY ECONOMIC DATA BASE
SUMMARY
OF 30-YEAR LEVELIZED FUEL CYCLE COSTS VARIABLE START-UPS ($MBtu, January 1981 Dollars) Assumed Reactor Reactor / Fuel Cycle . Commercial Designation Direct Cost Indirect Cost Cycle Cost Operation Date PWR-US(LE)/U-T 0.67 0.04 0.71 1987 HTCR-1)S(SE)/U-T (CANDU) 0.76 0.07 0.83 1995 PHWR-US(SE)/U-T (CANDU) 0.38 0.00 0.38 1995 HTCR-U5/U/Th-20%-T 0.84 0.05 0.89 2001 IJtFBR-Pu/U/U/U-HT 0.43 0.01 0.44 2001 i 1 I
TABLE 6 ., Effectiva Date - 1/1/8a ENERGY ECON 0!!IC DATA BASE
SUMMARY
BREAld)0WN OF 30-YEAR LEVELIZED FUEL CYCLE COSTS VARIABLE START-UPS ($/HBtu, January 1981 Dollars) Reactor / System Start-Up Urant Reprocessi > Designation Year Supply ) Plutoniu$ Supply (2 Fabrication (3) Shipping (4) or Disposal ) Total PWR-US(LE)/U-T 1987 0.61. 0.00 0.06 0.01 0.03 0.71 HTCR-U5/U/Th-20%-T 1995 0.73 0.00 0.06 0.02 0.02 0.83 PilWR-US(SE)/U-T (CANDU) 1995 0.29 0.00 0.06 0.01 0.02 0.38 HTGR-U5/U/Th-20%-T 2001 0.80 0.00 0.05 0.02 0.02 0.89
, IJfFBR-Pu/U/U/U-HT 2001 0.00 0.00 0.15 0.04 0.25 0.44 h
(1) Net uranium consumed including U-233 for those fuel cycles involving reprocessing. For throwaway fuel cycles, these figures represent the initial cost of uranium. (2) Net plutonium consumed. (3) Total fabrication of all types of fuel including recycle fuel or blanket fuel assemblies, where applicable. (4) Shipping to reprocessor for those fuel cycles involving reprocessing, or shipping to permanent disposal facility for throwaway fuel cycles. (5) Reprocessing and High Level Waste disposal, or permanent disposal of spent fuel assemblies.
Effective Date - 1/1/81 TABLE 6-18
. ENERGY ECONOMIC DATA BASE BASE REACTORS AND THEIR FUELING MODES 30-YEAR LEVELIZED COSTS VARIABLE START-UPS' (January 1, 1981 Dollars)
ASSUMED REACTOR CO:CTERCIAL REACTOR TYPE FUELING MODEL OPERATION DATE
$/MBtulm/kWh(}
PWR and BWR( } Throwaway (U only) 1987 0.71 7.3 HTGR-SC Throwaway (U only) 1995 0.83 7.0 PHWR Throwaway 1995 0.38 3.9 HTGR-SC and Throwaway (U only) 2001 0.89 7.5 (3) HTGR-PS LMEBR U Blanket Recycle Pu 2001 0.44 4.0 (1) BWR data not available for fuel costs; PWR data used for BWR (Model A1) . (2) Based on net plant heat rates given in Table 4-1. (3) Not applicable for a Cogeneration Facility. 6-57
ective Date - 1/1/81 TABLE 6-19 ENERGY ECONOMIC DATA BASE FUEL CYCLE COST COMPONENTS PERCENTAGE VALUES VARIABLE START-UPS (January 1, 1981 Dollars) PERCENT OF TOTAL FUEL CYCLE COST SHIPPING AND REACTOR URANIUM FUEL REPROCESSING / TYPE FUELING MODE SUPPLY FABRICATION SPENT FUEL DISPOSAL Throwaway (U only) 85.9 8.5 5.6 PWR(1) BWR 1987 HTGR-SC Throwaway (U only) 68.0 7.2 4.8 1995 i PHWR Throwaway 76.3 15.8 7.9 1995 HTGR-SC HTGR-PS Throwaway (U only) 89.9 5.6 4.5 2001 LMFBR U Blanket Recycle Pu - 34.1 65.9 2001 (1) BWR data not available for fuel costs; PWR data used for BWR (Model Al). 6-58
TABLE 6-20 . ENERGY ECONOMIC DATA BASE AVERAGE DELIVERED CO. CT PRICES OF STEAM COAL (S/short ton)
. Date Price 1976 18.39 1977 20.34 1978 23.75 1979 26.17 1980 January 27.41 i
February 27.67
,' March 27.71 April 28.50 May 28.39 June 28,78 July 29.27 August 29.71 September 29.59 October 29.42 November 29.67 December 29.35 i
Average 28.80 ' (1) From: May 1981 USDOE Monthly Energy Review; p. 89 6-59
l Effective Date - 1/1/81 TABLE 6-21 ENERGY ECONOMIC DATA BASE HIGH SULFUR COAL ANALYSIS Coal Type : Eastern High Sulfur Bituminous Coal Location : State Illinois County St. Clair Seam Illinois No. 6 Reserves (Est.): 3,000,000,000 Tons DESIGN BASIS COAL ANALYSIS I Moisture (Percent by Weight): 11.3 Proximate Analysis (Percent by Weight. Dry): Volatile Matter 39.72 Fixed Carbon 48.68 I Ash 11.60 Ultimate Analysis (Percent by Weight. Dry):
,' Carbon 69.33 Hydrogen 4.90 Nitrogen .86 Chlorine .04 Sulfur 3.61 0xygen 9.64 Ash Analysis (Percent by Weight, Dry):
f P025
.05
- SiO2 45.73 l
Fe2O3 18.38 A1 023 19.40 TiO2 1.30 Ca0 5.50 j Mgo .95 S03 6.63 K0 2 1.53 Na20 .51 Undetermined .02 I Calorific Value (Btu /lb) As Received 11,026 Dry 12,432 Ash Fusion Temperature (OF Red./0F 0x.) Initial 1950/2270 H=W 2140/2380 i H = 1/2W 2140/2400 l Fluid 2250/2500 1 6-60 l l l __ _ . _ _ . , . . _ _ _ ..
Effective Date - 1/1/81 TABLE 6-22 ENERGY ECONOMIC DATA BASE LOW SULFUR COAL ANALYSIS
. Coal Type : Western Low Sulfur Sub-Bituminous Coal Location :
State Wyoming County. Campbell Seam Roland Smith Reserves (Est.): 1,000,000,000 Tons DESIGN BASIS COAL ANALYSIS Moisture (Percent by Weight) 31.8 Proximate Analysis (Percent by Weight Dry): Volatile Matter 47.6 Fixed Carbon 45.1 Ash 7.3 Ultimate Analysis (Percent by Weight, Drv): Carbon 69.3 [' Hydrogen 5.2 Nitrogen 0.9 Sulfur 0.5 0xygen 16.8 Ash Analysis (Percent by Weight, Dry): SiO2 28.8 9.0 Fe203
- 13.0 Al 023 T102 0.7 Ca0 25.0 Mgo 6.5 18.0, S03 K02 0.4 Na20 1.2 Calorific Value (Btu /lb)
As Received 8,164 Dry 11,970 Ash Fusion Temperature (OF Red./0F 0x.) Initial 2140/2160 H=W 2180/2190 H = 1/2W 2200/2210 Fluid 2280/2370 l l 6-61 I - .
Effective Date - 1/1/81 TABLE 6-23 ENERGY ECONOMIC DATA BASE , PITTSBURGH STEAM (HIGH SULFUR) COAL ANALYSIS Coal Type : Eastern High Sulfur Bituminous Coal Location : State Pennsylvania County Washington Seam Pittsburgh No. 8 Reserves (Est.): 6,600,000,000 Tons DESIGN BASIS COAL ANALYSIS Moisture (Percent by Weight) 2.4 Proximate Analysis (Percent by Weight, Dry): Volatile Matter 39.2 . Fixed Carbon 51.2 Ash 7.3 Ultimate Analysis (Percent by Weight): Carbon 75.6 Hydrogen 5.2 Nitrogen 1.3 Sulfur 2.6 0xygen 8.0 Ash Analysis (Percent by Weight, Dry): P0 25 .28 SiO 2 46.95 Fe203 18.4 Al 023 25.64 TiO2 1.01 Ca0 2.0 Mg0 .67 S0 3 1*97 K0 2 1.75
- Na20 .45 Calorific Value (Btu /lb)
As Received 13,156 Dry 13,480 Ash Fusion Temperature (CF) 2,440 t t 6-62
f FIGURE 6-1 NUCLEAR FUEL CYCLE ACTIVITIES l MINING & ' MILLING NOTES: 1. STEPS 1 THRU 9 URANIUM ORE ARE FOR ONCE-THRU FUEL CYCLE. h 2. STEPS 10 THRU 16 ARE ADDEO FOR FUEL EXTRACTION OF U3 Og REPROCESSING AND (YELLOWCAKE) -----%-~~] RECYCLE.
- 3. SOLID LINE USUAL h l PATH; 8ROKEN LINE l OPTIONAL PATHS.
U 30 8TO UF 6 l' r-----* I i ENRICHMENT l OF F 6IN l ________ _____ i p----+-- , 444 l l FA8RICATION l FABRICATION MIXED OXIDE l OF UO2 FUEL FUEL MOX l (UO2 + PuO2) " d d " l l REACTOR l OPER ATION . MOX FUEL POWER , SHIPPING l GENERATION l l 4 l ON SITE l STORAGE-SPENT FUEL l ASSEMBLIES I 4 " SHIPPING . - - RECOVERED Pu l SPENT FUEL RECYCLE I l ASSEMBLIES PRODUCT PuC2
" l 1 ,,
l I I ,, ,, l l OFF SITt l SPENT FUEL
--+- - * " + SPENT FUEL ASSEMBLIES REPROCES$1NG ;
d'
! (GOV'T FACILITY) i I j PERMANENT i
d' HIGH LEVEL DEPLETED U l ( WASTE : RECYCLE --*- l REPOSITORY PRODUCT. ( ! UNH l GOVERNMENT FACILITIES h g i CONVERSION i L=-----=4--------+-------- DEPLETED +--- J UNH TO UF 6 6'-63
1
- SECTION 7 7.0 OPERATION AND MAINTENANCE COST FOURTH, UPDATE The Fourth Update of the EEDB Operation and Maintenance (0&M) costs is com-posed of nuclear and fossil-fired power generating stations O&M costs. For this report, the accounting breakdown includes the major cost areas for each type of plant, but does not define separate expenses for the reactor or boiler plant and the turbine plant. The O&M cost estimates accomodate state-of-the-art designs, regulations, codes and standards current as of January 1,1981. This section of the report presents the detail'ed results of I
the O&M cost update with a description of the major cost changes. 7.1 OPERATION AND MAINTENANCE COST UPDATE PROCEDURE 2 The procedure for estimating O&M. costs is developed by the Oak Ridge National i Laboratory (ORNL) and reported in ORNL/TM-6467 "A Procedure for Estimating Nonfuel Operation and Maintenance Costs for Large Steam-Electric Power Plants." I The cost estimating update procedure involves the combination of empirical l functions, that represent historical experience, with new factors arising from regulatory and economic considerations. Implementation of the procedure is through OMCOST, a digital computer program developed by ORNL. OMCOST is applied to the selected technical models tabulated in Tables 1-1 and 1-2 to produce the Operation,and Maintenance Cost Fourth Update. Input to OMCCST is staffing ano material requirements. ORNL prepares and updates these data on r l a continuing basis. 7.2 OPERATION AND MAINTENANCE COST
SUMMARY
O&M costs are prepared for the EEDB Fourth Update as the sum of staff, main-tenance material and supply costs and expenses, insurance and fees, and dd-ministrative and general expenses. Total O&M costs are summarized for all plants for the year 1981 in Table 7-1. 7-1
.- _ - __ - - . - ._ _ . -_= _ - - - _ . . - _ - --. . . ._ - _ - . . . _ . . _ _
i 1 l 7.3 DETAILED OPERATING AND MAINTENANCE COSTS 4
~'
R sults of the Operating and Maintenance Cost Fourth Update are presented for each technical plant model in Tables 7-2 through 7-12 as follows:
; Nuclear Fossil i
Plant Table Plant Table , Model Number Model Number i l BWR 7-2 HS12 7-8 HTGR-SC 7-3 HS8 7-9 i
! PWR 7-4 LS12 7-10
; PHWR 7-5 LS8 7-11
< HTGR-PS 7-6 CGCC 7-12 LMFBR 7-7
/ These tables contain all of the O&M data available in the EEDB. There are no additional data in the Backup Data File.
i 7.4 OPERATION AND MAIhTENANCE COST MODEL UPDATE
, To quantify staff requirements, staff for both nuclear and fossil-fueled plants are organized according to function. Fossil-fueled plants,.although their organization is similar to that of nuclear plants with regard to plant operation functions, differ in personnel allotment and job classifications.
i In addition, they do not require staffing for quality assurance or health physics. 1 In the Fourth Update, substantial staffing increases are incorporated for the nuclear power generating station operation and maintenance. These increases reflect increased emphasis on security, response to lessons learned at TMI and the continuing refinement of EEDB O&M cost projections. The total staffing used in the Fourth Update fer nuclear and fossil-fueled plants is tabulated in i i 7-2
Tables 7-13 through 7-19 as follows: Table Plant Model Number LWR Power Plants (BWR and PWR) 7-13 HTGR-SC Power Plants - 7-14 PHWR Power Plants 7-15 HTGR-PS CcEeneration Plants 7-16 LMFBR Power Plants 7-17 Coal-Fired Power Plants with FCD System 7-18 r Although licensed reactor operators may receive a five to ten percent premium, nuclear and fossil-fueled plant personnel are assigned the same hourly rates. i Nonlicensed jobs in nuclear and fossil work are not significantly different
~
in function. However, considerably more preparation and training may be re-f quired to learn nuclear plant procedure for repairs and inspections. The amount of the various major replacement items, expendable materials, and services used to maintain the power plant, is variable throughout the plant life. To date, historical data on new plant designs are not extensive enough to provide direct relationships for large plants. Therefore, the relation-ship of materials to maintenance labor as a percentage is estimated for a 70 percent plant capacity factor. Results were discussed with operating , personnel as a check. l l Operation and maintenance of coal-fired plants tend to be more labor intensive than that of nuclear plants because of the routine maintenance involved with burn-ing coal and the effect of high operatin'g temperatures on the equipment. l l 7-3
Maintenance costs are estimated for operation at base-load conditions near 100 percent capability. Variable maintenance costs are judged on the bcsis that 25 percent of the total maintenance is subject to change with load when operating between 50 and 80 percent capacity f actor. This judgment ic based on factors known to influence incremental costs for coal pulverizers, fuel handling, heat transfer surfaces and certain nonfuel supplies sensitive to load. The nonregenerative limestone-slurry scrubbing process is used to show a pro-csss with high sulfur removal and with economics intermediate among the various systems available for flue gas desulfurization (FGD). For both of the low
, sulfur coal-fired power plants, the operating cost of their dry scrubbing i
systems are estimsted by using the cost of the wet scrubbing systemc. Lower operating costs are expected for dry FGD systems; however, there is not sufficient operating experience with dry FGD systems to c'onfirm this assumption. Estimate of O&M costs for dry FGD systems will be incorporated in future' updates when sutficient data becomes available. The maintenance material cost factors as a percentage of maintenance labor cost are as follows: Percentage of Maintenance Labor Cost Fixed Variable Total ' Nuclear 100 0 100 Coal with FGD 62 20 82 7-4
f The O&M costs for cooling the main turbine condenser water and other plant heat exchangers are considered for evaporative cooling towers only. These costs range from $25,000 to $50,000 annually for both nuclear and coal a plants. Supplies and expenses include certain consumable materials and expenses that I are unrecoverable after use in O&M activities. These include makeup fluids, chemical gases, lubricants, office and personnel supplies, monitoring and, record services, and of fsite contract services. Costs of limestone and off-site sludge disposal associated with the limestone slurry scrubbing process for flue gas desulfurization are also included. Operators of nuclear power plants are required to maintain financial protec-f, tion to a total limit of $580,000,000. This limit is divided as of January 1, 1981 as follows: 6
$10 1
Private Insurance 160
/
Retrospective Premium 340 l Government Indemnity 80 580 The estimated annual premiums for nuclear insurance are as follows: Commercial Coverage ($160 million) $284,000 Retrospective Premium $ 6,000 l Government Coverage ($ 80 million) 6 $/MWe to 3000 MWe 7-5
Safety, environmental, and health physics inspections are routinely performed at specified frequencies for purposes of reviewing a licensed program by the Nuclear Regulatory Commission. The annual estimate for these inspections is
$100,000 for the first unit and $80,000 for each additional unit.
Administrative and general expenses include the owner's offsite salaries and expenses directly allocable to a specific power production facility. In this report, the magnitude of administrative and general expenses is related to j fixed O&M costs, minus insurance and operating fees. Values of 10 and 15 per-cent of total fixed cost of staff, maintenance materials, and supplies and expenses have been used to estimate administrative and general costs for nuclear and fossil plants respectively. ( 7.5 LEVELIZATION FACTOR The 07eration and 'faintenance costs for the EEDB Fourth Update are stated in terms of the first year cost (i.e., 1981 dollars). If one wishes to compute i a unit electricity cost using the inflation-free operation and maintenance costs, then the first year cost, af ter conversion to an electric energy cost, may be added directly to the inflation-free capital and fuel cycle costs. For an inflated cace, a levelization factor nust be computed and applied to the first year cost, before the O&M costs reported in this update are added to the inflated capital ard fuel costs. Consistent rates of interest and escalation must be used in the computation for compatibility and consist-ency with the capital and fuel costs with which it is combined. An approximation of the necessary levelization factor may be computed with the following equation: 7-6 l l _. ..
Revised 10/06/81 l
~
LF , d , (1 + d)" - (1 + a) [ d-a (1 + d)n . 1 _ k*here: LF = levelization factor
- a = (1 + 1) (1 + e) .1*
j d = discount rate'per annu=* i = inflation rate
- j n = number of years
- e = escalation rate *
(e = 0 for 0 & M)* ' 7.6 TMI RELATED OPERATIONAL COSTS The effects of the Three-Mile Island (TMI) NPCS incident result in significant changes in the operating costs of nuclear power plants in the Fourth Update. The most notable change is an increase of the station technical and engineering staff. Additionally, the operating staff is increased by an additional shift. The net effect of thesd changes is an increase of approximately 56 personnel in staff requirements as a point estimate. The additional personnel resulting from TMI, tabulated by function, are: Operations 26 ( Maintenance 43 Engineering 28 97 Depending on the operating philosophy of individual utilities, the above increase in personnel may be considered typical. The actual range of personnel additions varies from 1 to 6 for operating staffs, 12 to 30 for engineering and technical personnel, and from 6 to 50 for additional maintenance personnel. The magnitude of change for a specific utility depends on the particular operating i philosophy of that utility prior to the TMI accident. The economic effects of the TMI accident reported in this Fourth Update are based on a preliminary analysis by Oak Ridge National Laboratory. ORNL is currently reviewing data supplied by utilities on O&M costs resulting from the TMI event. O&M costs reported in the Fo'urth Update will be reconciled with the final ORNL analysis during the next update.
~
*Ref er to Section 2.4.2 for definitions of these terms as used in the EEDB Program. ,
7-7
I. TABLE 7-1 l Effective Date - 1/1/81 j
; ENERGY ECONOMIC DATA BASE i OPERATION AND MAINTENANCE COST UPDATE (Constanc $1981) i -
Model- MWe S10 6/yr. Mills /KWh j BWR 1190 36.5 5.0 HTGR-SC 858 35.7 6.8 PWR 1139 36.5 5.2 i PHWR 1260 35.7 4.6 HTGR-PS 150 21.[
- I j LMFBR 1457 42.6 4.8 HS12 1240 34.9 4.6
?
HS8 795 29.4 6.0 3.1 LS12 1244 23.3 LS8 795 21.0 4.3 , CGCC 630 11.5 3.0 i l
- Not Applicable for Process Steam /Cogenerr. tion Plant l
l l I I l l l ! 7-8 l I _ _ _. _ _ , _ _ _ _ _ _ _ . _ , _ _ , _ _ _ _ _
l i TABLE 7-2 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE (Constant $1981) 1 SU}SfARY OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR BASE-LOAD STEAM-ELECTRIC POWER PLANTS IN 1981.0 PLANT TYPE IS BWR WITH EVAPORATIVE COOLING TOWERS NUMBER OF UNITS PER STATION 1 THERMAL INPUT PER UNIT IS 3578. MWt PLANT NET HEAT RATE 10259. PLANT NET EFFICIENCY, PERCENT 33.26 EACH UNIT IS 1190. MWe NET RATING ANNUAL NET CENERATION, MILLION KWh 7302. WITH A PLANT FACTOR OF 0.70 STAFF, $1000/YR., 15952. (401 PERSONS AT $38189.) MAINTENANCE MATERIAL, $1000/YR. 5932.
<' FIXED 5932.
VARIABLE 0. i SUPPLIES AND EXPENSES, S1000/YR. 7730. FIXED 7000. VARIABLE 730. INSURANCE AND FEES, $1000/YR. 1002. COMM. LIAB. INS. 378. I GOV. LIAB. INS. 18.
! RETROSPECTIVE PREHIUM 6.
INSPECTION FEES & EXPENSES 600. ADMIN. AND GENERAL, $1000/YR. 5923. TOTAL FIXED COSTS, $1000/YR. 35809. TOTAL VARIABLE COSTS, $1000/YR. 730. TOTAL ANNUAL 0 & M COSTS, $1000/YR. 36539. FIXED UNIT 0 & M COSTS, MILLS /KWh(E) 4.90 VARIABLE UNIT 0 & M COSTS, MILLS /KWh(E) 0.10 TOTAL UNIT 0 & M COSTS, MILLS /KVh(E) 5.00 j 7-9
TABLE 7-3 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE (Constant $1981)
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR BASE-LOAD STEAM-ELECTRIC POWER PLANTS IN 1981.0 PLANT TYPE IS HTGR-SC WITH EVAPORATIVE COOLING TOWERS NUMBER OF UNITS PER STATION 1 THERMAL INPUT PER UNIT IS 2240. MWt PLANT NET HEAT RATE 8908. PLANT NET EFFICIENCY, PERCENT 38.30 EACH UNIT IS 858. MWe NET RATING ANNUAL NET GENERATION, MILLION KWh 5265. WITH A PLANT FACTOR OF 0.70 STAFF, $1000/YR. 15952. (401 PERSONS AT $39780.) - MAINTENANCE MATERIAL, $1000/YR. 5932. f FIXED 5932. VARIABLE 0. SUPPLIES AND EXPENSES, $1000/YR. 7028. FIXED 6389. VARIABLE 689. INSURANCE AND FEES, $1000/YR. 1004. COMM. LIAB. INS. 378. GOV. LIAB. INS. 18. RETROSPECTIVE PREMIUM 8. INSPECTION FEES & EXPENSES 600. ADMIN. AND GENERAL, $1000/YR. 5782. TOTAL FIXED COSTS, $1000/YR. 35059. TOTAL VARIABLE COSTS, $1000/YR. 639. TOTAL ANNUAL 0 & M COSTS, $1000/YR. 35698. FIXED UNIT 0 & M COSTS, MILLS /KWh(E) 6.67 VARIABLE UNIT 0 & M COSTS, MILLS /KWh(E) 0.11 TOTAL UNIT 0 & M COSTS, MILLS /KWh(E) 6.78 7-10
TABLE 7-4 Effective Date - 1/1/81 9 ENERGY ECONOMIC DATA BASE (Constant $1981) i
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR BASE-LOAD STEAM-ELECTRIC POWER PLANTS IN 1981.0 PLANT TYPE IS PWR 1 WITH EVAPORATIVE COOLING TOWERS NUMBER OF UNITS PER STATION 1 THERMAL INPUT PER UNIT IS 3412. MWt , PLANT NET HEAT RATE 10221. PLANT NET EFFICIENCY, PERCENT 33.38 EACH UNIT IS 1139. MWe NET RATING ANNUAL NET GENERATION, MILLION kWh 6989. WITH A PLANT FACTOR OF 0.70 STAFF, $1000/YR. 15952. (401 PERSONS AT $38189.)
. MAINTENANCE MATERIAL, S1000/YR. 5932. ~
FIXED 5932. VARIABLE 0. SUPPLIES AND EXPENSES, $1000/YR. 7699. FIXED 7000. , VARIABLE 699. INSURANCE AND FEES, $1000/YR. 1002. COMM. LIAB. INS. 378. GOV. LIAB. INS. 18. i RETROSPECTIVE PREMIUM 6. INSPECTION FEES & EXPENSES 600. < ADMIN. AND GENERAL, $1000/YR. 5917. TOTAL FIXED COSTS, $1000/YR. 35803. TOTAL VARIABLE COSTS, $1000/YR. 699. TOTAL ANNUAL 0 & M COSTS, $1000/YR. 36502. , FIXED UNIT 0 & M COSTS, MILLS /kWh(E) 5.08 VARIABLE UNIT 0 6 M COSTS, MILLS /kWh(E) 0.10 TOTAL UNIT 0 & M COSTS, MILLS /kWh(E) 5.18 7-11
~
TABLE 7-5 Effective Date - t/1/81 ENERGY ECONOMIC DATA BASE (Constant $1981) 4
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR BASE-LOAD' STEAM-ELECTRIC POWER PLANTS IN 1981.0 PLANT TYPE IS PHWR WITH EVAPORATIVE COOLING TOWERS NUMBER OF UNITS PER STATION 1 THERMAL INPUT PER UNIT IS 3800. MWt PLANT NET HEAT RATE 10291. i PLANT NET EFFICIENCY, PERCENT 33.16 EACH UNIT IS 1260. MWe NET RATING ANNUAL NET GENERATION, MILLION KWh 7732. WITH A PLANT FACTOR OF 0.70 STAFF, $1000/YR. 14559. (366 PERSONS AT S39780.) MAINTENANCE MATERIAL, $1000/YR. 3461. FIXED 3461. I VARIABLE 0. SUPPLIES AND EXPENSES, $1000/YR. 11713. FIXED - PLANT 5453.
- HEAVY WATER LOSSE.S AND UPKEEP 5100.
VARIABLE 1160. INSURANCE AND FEES, $1000/YR. 1010. COMM. LIAB. INS. 378. GOV. LIAB. INS. 24. RETROSPECTIVE PREMIUM 8. INSPECTION FEES & EXPENSES 600. , ADMIN. AND GENERAL, S1000/YR. 4926. TOTAL FIXED COSTS, $1000/YR. 34509. l TOTAL VARIABLE COSTS, $1000/YR. 1160. TOTAL ANNUAL 0 & M COSTS, S1000/YR. 35669. FIXED UNIT 0 & M COSTS, MILLS /KWh(E) 4.46 VARIABLE UNIT 0 6 M COSTS, MILLS /KWh(E) 0.15 TOTAL UNIT 0 & M COSTS, MILLS /KWh(E) 4.61 7-12
TABLE 7-6 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE 4 (Constant $1981)
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS
, . FOR BASE-LOAD STEAM-ELECTRIC POWER PLANTS IN 1981.0
, PLANT TYPE IS HTGR-PS WITH EVAPORATIVE COOLING TOWERS ; NUMBER OF UNITS PER STATION 1 THERMAL INPUT PER UNIT IS 1170 MWt ! l PLANT NET HEAT RATE 21572 PLANT NET EFFICIENCY, PERCENT 12.82 EACH UNIT IS 150 MWe NET RATING ANNUAL NET GENERATION, MILLION kWh 920. - WITH A PLANT FACTOR OF 0.70 STAFF, S1000/YR. 8951. (225 PERSONS AT 39780.) MAINTENANCE MATERIAL, $1000/YR. 2966. FIXED 2966. ( VARIABLE 0. SUPPLIES AND EXPENSES, $1000/YR. 3514. , FIXED 3195. VARIABLE 319. INSURANCE AND FEES, $1000/YR. 502. COMM. LIAB. INS. 189. GOV. LIAS. INS. 9. RETROSPECTIVE PREMIUM 4. [ l INSPECTION FEES & EXPENSES 300. l 1 ADMIN. AND GENERAL, $1000/YR. 5782. TOTAL FIXED COSTS, $1000/YR. 21396.
- TOTAL VARIABLE CCSTS, $1000/YR. 319.
l TOTAL ANNUAL 0 & M COSTS, $1000/YR. 21715. FIXED UNIT 0 & M COSTS, MILLS /kWh(E) NOT APPLICABLE VARIABLE UNIT 0 & M COSTS, MILLS /kWh(E) NOT APPLICABLE TOTAL UNIT 0 & M COSTS, MILLS /kWh(E) NOT APPLICABLE 1 1 7-13 l l l
l .i TABLE 7-7 - Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE (Constant $1981)
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR BASE-LOAD STEAM-ELECTRIC POWER PLANTS IN 1981.0 PLANT TYPE IS LMFBR WITH EVAPORATIVE COOLING TOWERS NUMBER OF UNITS PER STATION 1 THERMAL INPUT PER UNIT IS 3800. MWe PLANT NET HEAT RATE 8899. PLANT NET EFFICIENCY, PERCENT 38.34 EACH UNIT IS 1457. MWe NET RATING ANNUAL NET GENERATION, MILLION kWh 8940. WITH A PLANT FACTOR OF 0.70 STAFF, $1000/YR. 15952. (401 PERSONS AT S39780.) MAINTENANCE MATERIAL, $1000/YR. 9706.
- FIXED 9706.
VARIABLE 0. SUPPLIES AND EXPENSES, S1000/YR. 8968. FIXED 7985. VARIABLE 983 INSURANCE AND FEES, $1000/YR. 1010. COMM. LIAB. INS. 378. GOV. LIAB. INS. 24. RETROSPECTIVE PREMIUM 8. . INSPECTION FEES & EXPENSES 600. ADMIN. AND GENERAL, S1000/YR. 6925. TOTAL FIXED COSTS, $1000/YR. 41578. TOTAL VARIABLE COSTS, S1000/YR. 983. TOTAL ANNUAL 0 & M COSTS, $1000/YR. 42561. FIXED UNIT 0 & M COSTS, MILLS (kWh(E) 4.65 VARIABLE UNIT O & M COSTS, MILLS /kWh(E) 0.11 TOTAL UNIT 0 & M COSTS, MILLS /kWh(E) 4.76 ! 7-14
TABLE 7-8 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE (Constant $1981) t
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS , FOR BASE-LOAD STEAM-ELECTRIC POWER PLANTS IN 1981.0 -' , PLANT TYPE IS COAL WITH EVAPORATIVE COOLING TOWERS NUMBER OF UNITS PER STATION 1 WITH FGD SYSTEMS THERMAL INPUT PER UNIT IS 3299. MWe '. PLANT NET HEAT RATE 9078. PLANT NET EFFICIENCY, PERCENT 37.59 EACH UNIT IS 1240. MWe NET RATING ANNUAL NET GENERATION, MILLION kWh 7609 WITH A PLANT FACTOR OF 0.70 STAFF, $1000/YR. 8462. (259 PERSONS AT $32673.) i ,- MAINTENANCE MATERIAL, S1000/YR. 3429. ( FIXED 2593. VARIABLE 836. SUPPLIES AND EXPENSES, $1000/YR. 20302. FIXED 2400. VAR. - PLANT 756.
- ASH & FGD SLUDGE 17146. r ADMIN. AND GENERAL, S1000/YR. 2691 TOTAL FIXED COSTS, $1000/YR. 16116.
TOTAL VARIABLE COSTS, $1000/YR. 18738. l TOTAL ANNUAL 0 6 M COSTS, $1000/YR. 34854. , FIXED UNIT 0 & M COSTS, MILLS /kWh(E) 2.13 VARIABLE UNIT 0 6 M COSTS, MILLS /kWh(E) 2.48 TOTAL UNIT 0 & M COSTS, MILLS /kWh(E) 4.61 i 7-15 t
- ,, , y . . - m.#---,. .,
__,-,__._m_ - _ _ _ _ - . - , - , . - - . , . . . , - - - - - - _ . _ , _ . , . , - , , - -
TABLE 7-9
- Effective Date - 1/1/81' ENERGY ECONOMIC DATA BASE (Constant-$1981)
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR BASE-LOAD STEAM-ELECTRIC POWER PLANTS IN 1961.0 PLANT TYPE IS COAL WITH EVAPORATIVE COOLING TOWERS NUMBER OF UNITS PER STATION 1 , WITH FGD SYSTEMS THERMAL INPUT PER UNIT IS 2210. MWt PLANT NET HEAT RATE 9485 PLANT NET EFFICIENCY, PERCENT 35.97 EACH UNIT IS 795. MWe NET RATING ANNUAL NET GENERATION, MILLION kWh 4878. WITH A PLANT FACTOR OF 0.70 STAFF, $1000/YR. 8462. (259 PERSONS AT $32673.)
~
MAINTENANCE MATERIAL, $1000/YR. 3429. ( FIXED 2593. VARIABLE 836. SUPPLIES AND EXPENSES, $1000/YR. 14877. FIXED 2400. VAR. - PLANT 488.
- ASH & FGD SLUDGE 11989.
ADMIN. AND GENERAL, $1000/YR. 2691. TOTAL FIXED COSTS, $1000/YR. 16116 i TOTAL VARIABLE COSTS, $1000/YR. 13313. TOTAL ANNUAL 0 6 M COSTS, $1000/YR. 29429 FIXED UNIT 0 6 M COSTS, MILLS /kWh(E) 3.31 VARIABLE UNIT O & M COSTS, MILLS /kWh(E) 2.73 TOTAL UNIT 0 & M COSTS, MILLS /kWh(E) 6.04 I 7-16 l I
* -n--* w - ~ ~ - ,, -
TABLE 7-10
- Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE' (Constant $1981)
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR BASE-LOAD STEAM-ELECTRIC POWER PLANTS IN 1981.0 PLANT TYPE IS COAL WITH EVAPORATIVE COOLING TOWERS NUMBER OF UNITS PER STATION 1 WITH FCD SYSTEMS THERMAL INPUT PER UNIT IS 3442. MWt PLANT NET HEAT RATE 9441. PLANT NET EFFICIENCY, PERCENT 36.14 EACH UNIT IS 1244. MWe NET RATING ANNUAL NET GENERATION, MILLION kWh 7633. WITH A PLANT FACTOR OF 0.70 STAFF, $1000/YR. 8462. (259 PERSONS AT $32673.) . MAINTENANCE MATERIAL, $1000/YR. 3429. [ FIXED 2593. VARIABLE 836. SUPPLIES AND EXPENSES, $1000/YR. 8738. FIXED 2400. VAR. - PLANT 1138.
- ASH & FGD SLUDGE 5200.
ADMINs AND GENERAL, $1000/YR. 2691. TOTAL FIXED COSTS, S1000/YR. 16146. TOTAL VARIABLE COSTS, $1000/YR. 7174. TOTAL ANNUAL 0 & M COSTS, $1000/YR. 23320. FIXED UNIT 0 & M COSTS, MILLS /kWh(E) 2.13 VARIABLE UNIT 0 & M COSTS, MILLS /kWh(E) 0.95 TOTAL UNIT 0 & M COSTS, MILLS /kWh(E) 3.08 l l l 7-17 1 l t
i ! i 1 i TABLE 7-11 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE (Constant $1981) , .i
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR BASE-LOAD STEAM-ELECTRIC POWER PLANTS IN 1981.0 1 PLANT TYPE IS COAL l WITH EVAPORATIVE COOLING TOWERS I NUMBER OF UNITS PER STATION 1 i WITH FGD SYSTEMS THERMAL INPUT PER UNIT IS 2307. MWt
- PLANT NET HEAT RATE 9902.
. PLANT NET EFFICIENCY, PERCENT 34.46 EACH UNIT IS 795. MWe NET RATING ANNUAL NET GENERATION, MILLION kWh 4878. WITH A PLANT FACTOR OF 0.70 STAFF, $1000/YR. 8462. (259 PERSONS AT $82673.)
MAINTENANCE MATERIAL, $1000/YR. 3429.
FIXED 2593. VARIABLE 836. SUPPLIES AND EXPENSES, $1000/YR. 6451. FIXED 2400. VAR. - PLANT 732.
- ASH 6 FGD SLUDGE 3319.
ADMIN. AND GENERAL, $1000/YR. 2691. l TOTAL FIXED COSTS, $1000/YR. 16146. l TOTAL VARIABLE COSTS, $1000/YR. 4887. l TOTAL ANNUAL 0 6 M COSTS, $1000/YR. 21033. l FIXED UNIT 0 6 M COSTS, MILLS /kWh(E) 3.31 l VARIABLE UNIT 0 6 M COSTS, MILLS /kWh 1.00 I TOTAL UNIT 0 6 M COSTS, MILLS /kWh 4.71 i I I 1 7-18 I,-._,_-.. . _ . - _ . . . , . _ _ . . . . . _ _ . . . . _ _ . _ . _ . -
1 Effective Date - 1/1/81 TABLE 7-12 ENERGY ECONOMIC DATA BASE ~
) (Constant $1981)
SUMMARY
OF ANNUAL NONFUEL OPERATION AND MAINTENANCE COSTS FOR BASE-LOAD STEAM-ELECTRIC POWER PLAhTS IN 1981.0 PLAhT TYPE IS CGCC WITH NATURAL DRAFT DRY COOLING TOWER NUMBER OF UNITS PER STATION 1 - WIIH FGD SYSTEMS THERMAL INPUT PER UNIT IS 1523 MWt PLAhT NET HEAT RATE 8250 - PLANT NET EFFICIENCY, PERCEhi.41.37 EACH UNIT IS 630 MWe NET RATING ANNUAL NET GENERATION, MILLION kWh 3863 1 WITH A PLANT FACTOR OF 0.70 STAFF, $1000/YR 5564. MAINTENAN'CE MATERIAL, $1000/YR 2053. FIXED 1547. VARIABLE 506. SUPPLIES AND EXPENSES, $1000/YR 2825. FIXED 1544. VARIABLE - PLANT - 389.
- - ASH & SULFUR DISPOSAL 392.
1 ADMINISTRATIVE AND GENERAL, $1000/YR 1091. TOTAL FIXED COSTS, $1000/YR 9746. TOTAL VARIABLE COSTS, $1000/YR 1787- . TOTAL ANNUAL O&M COSTS, $1000/YR 11533. FIXED UNIT O&M COSTS, MILLS /kWh (E) 2.52 VARIABLE UNIT O&M COSTS, MILLS /kWh (E) .46 TOTAL UNIT O&M COSTS, MILLS /kWh (E) 2.98 j 7-19 i s
- .- - , . - . , , , , _ , - , , _ _ . - - _ _ , . . - - . ~ - ., , _ , , _ _ _ , _ , _ _ - . , . - . _ _ _ _ . .
I
~
TABLE 7-13 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE STAFF REQUIREMENT F,0R LWR POWER PLANTS UNIT SIZE RANGE M!f(E) 701-1300 NO. UNITS PER SITE 1 2 3 4 i PLANT MANAGER'S OFFICE i MANAGER , 1 1 1 1
, ASSISTANT 1 2 3 4 i QUALITY ASSURANCE 6 6 7 8 i ENVIRONMENTAL CONTROL 1 1 1 1 PUBLIC RELATIONS 1 1 1 1 TRAINING 12 12 12 12 SAFETY 1 2 3 4 ADMIN. & SERVICES 49 55 65 78 I HEALTH SERVICES 2 2 2 2 I
SECURITY 94 94 94 94 SUBTOTAL . 168 176 189 205 OPERATIONS SUPERVISION (EXC. SHIFT) 9 9 18 18 SHIFTS 52 104 156 208 SUBTOTAL 61 113 174 226 MAINTENANCE SUPERVISION 12 14 26 28 CRAFTS 55 71 87 103 PEAK MAINT. ANNUALIZED 55 110 165 220 SUBTOTAL 122 195 278 351 TECHNICAL AND ENGINEERING REACTOR 5 5 7 7 l RADIO-CHEMICAL 8 8 12 12
- I&C 16 16 16 16 l PERFORM., REPORTS, TECH. 21 30 39 48 l
' SUBTOTAL 50 59 74 83 TOTAL 401 543 715 865 LESS SECURITY 307 445 621 771 LESS SEC., PEAK MAINT. 252 339 456 551 7-20
--,---.---,-e - , , , - - . . , , , . , , - - - - - -
-_ _ . - ___ . . , . ~ - - _ _ _ . . - _ _ - , _ _ _
't TABLE 7-14 Effective Date - 1/1/81 1 ENERGY ECONOMIC DATA BASE j STAFF REQUIREMENT FOR HTGR POWER PLANTS UNIT SIZE RANGE MW(E) 700-1300 NO. UNITS PER SITE 1 2 3 4 PLANT MANAGER'S OFFICE MANAGER 1 1 1 1 ASSISTANT 1 2 3 4 QUALITY ASSURANCE 6 6 7 8 ENVIRONMENTAL CONTROL 1 1 1 1 l PUBLIC RELATIONS 1 1 1 1 ! TRAINING 12' 12 12 12
! SAFETY 1 2 3 4 ADMIN. & SERVICES 49 55 65 78 HEALTH SERVICES 2 2 2 2 SECURITY 94 94 94 94 SUBTOTAL 168 176 189 205
- OPERATIONS J
, SUPERVISION (EXC. SHIFT) 9 9 18 18 SHIFTS 52 104 156 208 SUBTOTAL 61 113 174 226 MAINTENANCE SUPERVISION 12 14 26 28 l CRAFTS 55 71 87 103 l PEAK MAINT. ANNUALIZED 55 110 165 220 SUBTOTAL 122 195 278 351 TECHNICAL AND ENGINEERING REACTOR 5 5 7 7 RADIO-CHEMICAL 8 8 12 12 I&C 16 16 16 16 PERFORM., REPORTS, TECH. 21 30 39 48 SUBTOTAL 50 59 74 83 TOTAL 401 543 715 865 LESS SECURITY 307 445 621 771 LESS SEC., PEAK MAINT. 252 339 456 551 7-21
- . - . -- - . _ - . - . ~ . , - _ , _ _ _ _ . - , - . - . ~ _. _ - - _ _ _ _
TABLE 7-15 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE j STAFF REQUIREMENT FOR PHWR POWER PLANTS UNIT SIZE RANGE (Mk'(E) 700-1300 NO. UNITS PER SITE . 1 2 3 4 PLANT MANAGER'S OFFICE . MANAGER 1 1 1 1 ASSISTANT 1 2 3 4
! QUALITY ASSURANCE 6 6 7 8 ENVIRONMENTAL CONTROL 1 1 1 1 PUBLIC RELATIONS 1 1 1 1 TRAINING 12 12 12 12 SAFETY 1 2 3 4 j ADMIN. & SERVICES 49 55 65 78 4 HEALTH SERVICES 2 2 2 2 SECURITY 94 94 94 94 SUBTOTAL 168 176 189 205 i f OPERATIONS SUPERVISION (EXC. SHIFT) 9 9 18 18 SHIFTS 52 104 156 208 SUBTOTAL 61 113 174 226 MAINTENANCE SUPERVISION 12 14 26 28 CRAFTS . 55 71 87 103 l PEAK MAINT. ANNUALIZED 55 110 165 220 SUBTOTAL 122 195 278 351 TECHNICAL AND ENGINEERING l
l REACTOR 5 5 7 7 RADIO-CHEMICAL 8 8 12 12 I&C 16 16 16 16 PERFORM., REPORTS, TECH. 21 30 39 48 SUBTOTAL 50 59 74 83 TOTAL 401 543 715 865
- ::= ::= :::
LESS SECURIn' 307 445 621 771 LESS SEC., PEAK MAINT. 252 339 456 551 7-22 l
. . _ _ ~ _ _ . . . _
Effective Date - 1/1/81 TABLE 7-16 ENERGY ECONOMIC DATA BASE STAFF REQUIREMENT POR HTCR-PROCESS STEAM COCENERATION PCWER PLANTS UNIT SIZE MW(t)* 1170 NO. UNITS PER SITE 1 2 3 4 PLAhT MANAGER'S OFFICE MANAGER 1 ASSISTAhi 3 QUALITY ASSURANCE 3 ENVIRONMENTAL CONTROL 1 PUBLIC RELATIONS 1 TRAINING 12 SAFETY 1 ADMIN. & SERVICES
- 13 HEALTH SERVICES 1 SECURITY 53 ,
SUBTOTAL 89 l OPERATIONS SUPERVISION (EXC. SHIFT) 3 SHIFTS 34 SUBTOTAL 37 MAIhTENANCE SUPERVISION 6 CRAFTS 24 PEAK MAINT. ANNUALIZED 41 SUBTOTAL 71 TECHNICAL AND ENGINEERING REACTOR 3 RADIO-CllEMICAL 3 I&C 4 PERFORM., REPORTS, TECH 10 SUBTOTAL 20 , TOTAL 217 LESS SECURITY 164 LESS SEC., PEAK MAINT 123
- Process Steam - Cogeneration Plant 7-23
j . TABLE 7-17 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE STAFF REQUIREMENT FOR LMFBR POWER PLANTS UNIT SIZE RANGE MW(E) 700-1500 NO. UNITS PER SITE 1 2 3 4 PLANT MANAGER'S OFFICE MANAGER 1 1 1 1 ASSISTANT 1 2 3 4 QUALITY ASSURANCE 6 6 7 8 ENVIRONMENTAL CONTROL 1 1 1 1 PUBLIC RELATIONS 1 1 1 1 TRAINING 12 12 12 12 SAFETY 1 2 3 4 ADMIN. & SERVICES 49 55 65 78 HEALTH SERVICES 2 2 2 2 SECURITY 94 94 94 94 SUBTOTAL - 168 176 189 205 OPERATIONS SUPERVISION (EXC. SHIFT) 9 9 18 18 SHIFTS 52 104 156 208 SUBTOTAL 61 113 174 226 MAINTENANCE SUPERVISION 12 14 26 28 CRAFTS 55 71 87 103 PEAK MAINT. ANNUALIZED 55 110 165 220 SUBTOTAL 122 195 278 351 TECHNICAL AND ENGINEERING REACTOR 5 5 7 7 RADIO-CHEMICAL 8 8 12 12 I&C 16 16 16 16 PERFORM., REPORTS, TECH. 21 30 39 48 SUBTOTAL 50 59 74 83 TOTAL 401 543 715- 865 EEE 333 EMS EXE LESS SECURITY 307 445 621 771 LESS SEC., PEAK MAINT. 252 339 456 551 7-24
] I 4 TABLE 7-18 Effective Date - 1/1/81 ENERGY ECONOMIC DATA BASE i r STAFF REQUIREMENT FOR COAL-FIRED POWER PLANTS
! WITH FGD SYSTEMS i
UNIT SIZE RANCE MW(E) 8 400-700 701-1300 NO. UNITS PER SITE NO. UNITS PER SITE 1 2 3 4 1 2 3 4 PLANT MANAGER'S OFFICE i MANAGER 1 1 1 1 1 1 1 1 4 ASSISTANT 1 2 3 4 1 2 3 4
- ENVIRONMENTAL CONTROL 1 1 1 1 1 1 1 1 l PUBLIC RELATIONS 1 1 1 1 1 1 1 1 i TRAINING 1 1 1 1 1 1 1 1 i SAFETY 1 1 1 1 1 1 1 1 ADMIN. & SERVICES 13 14 15 16 13 14 15 16 j HEALIR SERVICES 1 1 1 2 1 1 1 2 SECURITY 7 7 9 14 7 7 9 14 SUBTOTAL 27 29 33 41 27 29 33 41
\ OPERATIONS l
1 SUPERVISION (EXC. SHIFT) 3 3 5 5 3 3 5 5 SHIFTS 45 50 60 65 45 50 60 65 ! FUEL AND LIMESTONE REC. 12 12 12 18 12 12 12 18
- WASTE SYSTEMS 15 30 45 60 15 30 45 60 SUBTOTAL 75 95 122 148 75 95 122 148 MAINTENANCE i
SUPERVISION 8 8 10 12 8 8 10 12 I CRAFTS 90 115 135 155 95 120 140 160 PEAK MAINT. ANNUALIZED 33 66 99 132 35 70 105 140 7 SUBTOTAL 131 189 244 299 138 198 255 312 TECHNICAL AND ENGINEERING WASTE 1 2 3 4 1 2 3 4 RADIO-CHEMICAL 2 2 3 4 2 2 3 4 I&C 2 2 3 4 2 2 3 4 PERFORM., REPORTS, TECH. 14 17 21 24 14 17 21 24 SUBTOTAL 19 23 30 36 19 23 30 36 TOTAL 252 336 429 524 259 345 440 537 7-25 i e, ,-- - -.---v,..,. - - - ,,..,..n., ,- n--, -. .. , _ , , - . _ , - - . . - , . ~ - - . _ - - . - _ - _ . - _ - - - - , , , . . - . - - - . .
SECTION 8
8.0 REFERENCES
AND GLOSSARY
8.1 REFERENCES
AND BIBLIOGRAPHY
- 1. " Commercial Electric Power Cost Studies," United Engineers & Con-structors Inc., Philadelphia, PA 19101, NUREG: U.S. Nuclear Regu-latory Commission and/or COO: U.S. Energy Research and Develop-ment Administration.
- a. " Capital Cost: Pressurized Water Reactor Plant," Volumes 1 and 2, NUREG-0241, C00-2477-5, June 1977.
- b. " Capital Cost: Boiling Water Reactor Plant," Volumes 1 and 2, NUREG-0242, C00-2477-6, June 1977.
- c. " Capital Cost: High and Low Sulfur Coal Plants - 1200 MWe (Nominal)," Volumes 1, 2 and 3, NUREG-0243, C00-2477-1, June 1977.
- d. " Capital Cost: Low and High Sulfur Coal Plants - 800 MWe (Nominal)," Volumes 1, 2 and 3, NUREG-0244, C00-2477-8, June 1977.
- e. " Capital Cost Addendum: Multi-Unit Coal and Nuclear Stations,"
Volume 1, NUREC-0245, C00-2477-9, June 1977.
- f. " Fuel Supply Investment Cost: Coal and Nuclear," Volume 1 NUREC-0246, C00-2477-10, April 1979.
- g. " Cooling Systems Addendum: Capital and Total Generating Cost Studies," Volume 1, NUREG-0247, C00-2477-ll, September 1978.
- h. " Total Generating Costs: Coal and Nuclear Plants," Volume 1 NUREG-0248, C00-2477-12, February 1979.
- i. " Capital Cost: Pressurized Heavy Water Reactor Plant," Volumes 1 and 2, C00-2477-13, June 1977.
- j. " Capital Cost: Gas Cooled Fast Reactor Plant," Volume 1, C00-2477-16, September 1977.
- 2. "NSSS Capital Costs for a Mature LMFBR Industry for Energy Economic Data Base Program-Phase I," Combustion Enginee. ring, Inc.,
Windsor, CT 06095, CE-FBR-78-532, United Engineers & Constructors Inc. Subcontract, October 1978. 8-1
T l 8.1 (Cont'd)
- 3. "3360 MWt HTGR-Steam Cycle Reference Plant Design," United Engineers
,- & Constructors'Inc., Philadelphia, PA 19101, Volumes I through X, General Atomic Company Subcontract SC558623 Proprietary, August 1977..
t i
- 4. " Study of Electric Plant Applications for Low Btu Gasification of Coal for Electric Power Generation," Combustion Engineering, Inc.
Windsor, CT 06905, U.S. Department of Energy Contract FE-1545-TK59.
- 5. " Final Report on Nuclear Fuel Cycle Consulting Services for Energy Economic Data Base Program-Phase 1," NUS Corporation, Rockville, MD 20850, NUS-3273 (Proprietary), United Engineers & Constructors Inc. '
Subcontract, October 1978. 4
! a. " Fuel Cycle Cost Estimates for LWR, HTGR, CANDU Type HWR, LMFBR and GCFR," NUS-3190.
l
- b. " Cost of Enrichment Services," NUS-3196.
- c. *"UF 6 Conversion Cost," NUS-3198.
- , d. " Heavy Water Production Costs," NUS-3199.
k " Spent Fuel and Reprocessing Waste Disposition," NUS-3203. j ' e.
- f. " Costs for Spent Fuel Shipping," NUS-3204.
- g. "HTGR Fuel Cycle, "NUS-3207.
i
- h. " Costs of U 0 ," NUS-3209.
38 , i
- 1. "A Survey of Fuel Costs for U.S. Nuclear Power 1973-1977,"
NUS-3223.
- j. " Reprocessing Cost Model for LWR, LMFBR and GCFR," NUS-3224.
I
- k. " Recommendations Relating to Acquisition ci Mass Flow Data for the EEDB Program," NUS-3237, i
l 1. " Fabrication Costs for ' Rodded' Nuclear Fuels," NUS-3242.
- m. " Recommendations Relating to Evaluation of Nuclear Fuel Unit-Cost data for. EEDB Program," NUS-3243.
- n. " Additional Fuel Cost Studies - Escalation, 2001 Startup and CANDU Thorium System," NUS-3244 f 6. " Fuel Cycle Cost Projections", Batelle Pacific Northwest Laboratory,
{ Richland, WA 99352, NUREG/CR-1041, December, 1979. 8-2 4 e-,nn.,-- ,-- r - - - - - - - - - - - , - - - - . . - - - - - - - - - - - .. -,
8.1 (Cont'd)
- 7. "Non-Proliferation Alternative Systems Assessment Program (NASAP)",
U.S. Department of Energy, Washington, D.C. 20545, DOE /NE-0001/9, June, 1980.
- 8. " Coal and Nuclear: A Comparison of the Cost of Generating Base-load Electricity by Region", U.S. Nuclear Regulatory Commission, Washington, D.C. 20555, NUREG 0430, December, 1978.
- 9. Messing, R. F. and Harris, H.E.: " Comparative Energy Values to 1990," Report No. R770602, Impact Securities Corp. , (Subsidiary),
Arthur D. Little, Inc., Cambridge, MA 02140, June 1977.
- 10. Browne, Thomas E., et al. (Seven Authors): " Supply 77-EPRI Annual Energy Supply Forecasts," Report No. EA-634-SR, Electric Power Research Institute, Palo Alto, CA 94304, May 1978.
- 11. Private Communication " Estimates of Baseline Delivered Coal Costs,"
(PWC Job No. 3592), Paul Weir Co., 20 North Wacker Drive, Chicago, IL 60606, October 13, 1978.
- 12. Monthly Energy Review, U.S. Department of Energy, Energy Information Administration, Washingt'on, DC 20461, (Monthly Through June 1980).
- 13. Myers, M.C., Fuller, L.C., "A Procedure for Estimating Non-Fuel Operating and Maintenance Costs for Large Steam - Electric Power Plants," Oak Ridge National Laboratory, Oak Ridge, TN 37830, ORNL/TM-6467, January 1979.
- 14. Myers, M.C., " Guidelines for Estimating Non-Fuel Operation and liaintenance Costs for Alternative Nuclear Power Plants," Oak Ridge National Laboratory, Oak Ridge, TN 37830, ORNL/TM-6860, September 1979.
- 15. Private Communication "1979 Update of Operating and Maintenance Costs", Telephone Conversion, United Engineers & Constructors, Inc.
Philadelphia, PA, Job No. 7149.050, Er J. Ziegler to M. C. Myers, October 30, 1980
- 16. Phung, Doan L. , Perry , Alf red M. , Whittle , Charles E. , " Economics of Coal and Nuclear Electricity - A Treatment of Inflation and Dif ferential Cost Increases," Volume 39, pp 407-415, PIoceedings of the American Power Conference, 1977.
- 17. Stauffer, T. R., Palmer, R. S., Wy:koff, H. L., " Breeder Reactor Economics," Unnumbered: Breeder Reactor Corporation, July 1975.
8-3
8.1 (Cont'd)
- 18. " Engineering Economics, A Manager's Guide to Economic Decision Making," Third Edition, American Telephone and Telegraph Company, 1977
- 19. Crowley, J. H., et al, "The Need for and Deployment of Inexhaustible Energy Resource Technologies," Report of Technology Study Panel Inexhaustible Energy Resources Study by United Engineers & Con-structors Inc., Philadelphia, PA 19101, Unnumbered Report:
U.S. Energy Research and Development Administration September 1977.
- 20. "The HTGR for Electric Power Generation - Design and Cost Evalua-tion," United Engineers and Constructors, Inc. , Philadelphia, PA 19101, Gas Cooled Reactor Associates Contract GCRA/AE/78-1 Pro-prietary, September,1980 (Supercedes Reference 3).
- 21. " Conceptual Design of a large HWR for U.S. Siting," CEND-379; Combustion Engineering, Inc. , Windsor, CT 06905 and United Engineers
& Constructors, Inc. , Philadelphia, PA 19101, U.S. Department of Energy Contract EN-77-C-01-5068, September, 1979 (Supercedes Reference li).
- 22. "1170 MWe, HTGR Steamer Cogeneration Plant - Design and Cost Study," UE&C/ DOE 800716; United Engineers & Constructors, Inc. , .
Philadelphia, PA 19101 and General Atomic Company, La Jolla, CA, U.S. Department of Energy Contract DE-AC02-78ET34222, August, 1980
- 23. "NSSS Capital Costs for a Mature LMFBR Industry for Energy Economic Data Base Program - Phase I: Addendum," Combustion Engineering, Inc.,
Windsor, CT 06095, CE-ADD-60-310, United Engineers & Constructors, Inc. Subcontract, September 25, 1980 (Addendum to Reference 2).
- 24. " Final Report and Initial Update of the Energy Economic Data Base (EEDB) Program - Phase I", United Engineers & Constructors, Inc.,
Philadelphia, PA 19101, UE&C/ DOE-790930, U.S. Department of Energy Contract EN-78-C-02-4954, December, 1979.
- 25. " Phase II Final Report and Second Update of the Energy Economic Date Base (EEDB) Program", United Engineers & Constructors, Inc.,
Philadelphia, PA. 19101, UE&C/ DOE-8104 30, U.S. Department of Energy Contract DE-AC02-78ET33020, (fo rmerly EN-78-C-02-4954) , July, 1981.
- 26. " Phase III Final Report and Third Update of the Energy Economic Date Base (EEDB) Program", United Engineers & Constructors, Inc. ,
Philadelphia, PA. 19101, UE&C/ DOE-810731, U.S. Department of Epergy Contract DE-AC02-78ET33020, (formerlv EN-78-C-02-4954) , July, 1981. 8-4
8.1 (Con'd)
- 27. " Projections of Cost, Durations, and On-site Manual Labor Require-ments for Constructing Electric Generating Plants, 1979 - 1983",
D02/IR-057: DOL /CLDS/PPZ, U.S. Department of Labor and U.S. ; Department of Energy, September, 1979.
- 28. Kenneth C. Kusterer. " Labor Productivity in Heavy Construction:
Impact on Synfuels Program Employment," Argonne National Labora-tory, June, 1980. E 8-5
8.2 GLOSSARY OF ACRONYMS AND ABBREVIATIONS 8.2.1 Governmental Organizations AEC - Atomic Energy Commission ISucceeded first by ERDA and then by DOE) ANL - Argonne National Laboratory I l BNL - Brookhaven National Laboratory I C00 - Chicago Operations Office - DOE i l D0D (DoD) - Department of Defense DOE (doe) - Department of Energy (Successor to ERDA and AEC) DOI - Department of the Interior EIA - Energy Information Administration EPA - Environmental Protection Agency ERDA - Energy Research and Development Administration (Succeeded AEC and was then superseded by DOE) FEA - Federal Energy Administration-FERC - Federal Energy Regulatory Commission HEDL - Hanford Engineering Development Laboratory LASL - Los Alamos Scientific Laboratory LLL - Lawrence Livermore Laboratory '- NRC - Nuclear Regulatory Commission ORNL - Oak Ridge National Laboratory SC - Sandia Corporation SL - Sandia Laboratories US - United States 8- 6
8.2.2 Other Organizations ' ADL - Arthur D. Little, Inc. ASTM - American Society for Testing Materials CE - Combustion Engineering, Inc.
~
EEI - Edison' Electric Institute - EPRI - Electric Power Research Institute GAC - General Atomic Company A GE - General Electric Company NUS - NUS Corporation (Formerly Nuclear Utility Services Corporation ) UE&C - United Engineers & Constructors Inc. , (A Raytheon Subsidiary) . UMW - United Mine Workers WE - Westinghouse Electric Corporation WECO 1 e I i i l l { 8-7
8.2.3 Technical Identification and Programs BBL - Barrels bbl /d - Barrels per day , BOP - Balance of Plant Stu - British Thermal Unit BTU = 1055 Joules BWR - Boiling Water Reactor C - Temperature - Degrees Celsius (sometimes - incorrectly - Centigrade) CANDU . - Canadian D_euterium U_ranium (Alternate ' designation for PHWR) CAP - Het Electrical Capac'ity CF , Capacity' Factor CGCC - Coal Gasification Combined Cycle Plant CO - Carbon Monoxide CO 2 - Carbon Dioxide CONCICE - Conceptual Construction Investment Cost Estimate - UE&C Proprietary Code I COS - Carbonyl Sulfide - Carbon Oxysulfide j CPGS - Comparison Power Generating Station CRBR - Clinch River Breeder Reactor CY - Calendar Year cy CY - Cubic Yard - yd3 et - Escalation rate for money inflation - %/y d e, - Escalation rate for scarcity - reduced productivity - %/y 8-8 _ - _ - _ _ _ _ . . . . ~ . _ . . , . _ _,, _ __
i 8.2.3 (Cont'd) EBR - Experimental Breeder Reactor (Two versions: -1 and -II) EEDB - Energy Economic Data Base EHS - Eastern High Sulfur Coal F - Temperature - Degrees Fahrenheit FBR - Fast Breeder Reactor FCR - Fixed Charge Rate FGD - Flue Gas De-Sulfurization FIT - Federal Income Tax FPCS - Fossil Fired Power (Electrical) Generating Station FUELCOST-V - A NUS proprietary code FY - Fiscal Year
, fy GCFR - Gas Cooled Fast (Breeder) Reactor (Sometimes GCFBR)
GCR - Gas Cooled Reactor - general designation for all gas-cooled reactor systems GESSAR - General Electric Standard Safety Analysis Report GSU - Generator Step-Up Transformer i GW - Gigawatt = 109 Watts h - Hour HLW - High Level Waste (Radioactive) HM - Heavy Metal - fuels containing mixtures of U + Pu, U + Th, Pu + Th HP - !!orsepower hr - Hour RR - Net Station Heat Rate in Btu /kWh HS - High Sulfur ( > 1.0%) 8-9
3.2.3 (Cont'd) HSC - High Sulfur Coal HS8 - High Sulfur 800 MWe Coal-Fired Power Generating Station HS12 - High Sulfur 1200 MWe Coal-Fired Power Generating Station HTGR - High Temperature Gas (Cooled) Reactor HS 2 - Hydrogen Sulfide NWR - Heavy Water Reactor I&C - Instrumentation and Control in HgA - Inches of Mercury Pressure - Absolute
= 25.4 Torr kgH - Kilograms Heavy Metal kgHM kgU - Kilograms Uranium kV - Volts x 103 - Kilovolts
[ kVA - Volt Amperes x 103 - Kilovolt-Amperes kW
- Watts x 103 - Kilowatt = 3414 Btu /hr kWh - Kilowatt-IIour - 3414 Btu L3 (ib.) - Pound (s)
LF - Linear Feet LF - Levelization Factor LMFBR - Liquid Metal Fast Breeder Reactor LS - Low Sulfur (51.0%) LS8 - Low Sulfur 800 MWe Coal-Fired Power Generating Station LS12 - Low Sulfur 1200 MWe Coal-Fired Power Generating Station LT - Lot LWR - Light Water Reactor (includes BWR and PWR) 6-In
l 8.2.3 (Cont'd) - I m - Minute c/MBtu - Cents per Btu x 10 6 6 -
$/MBtu - Dollars per Btu x 10 min - Minute m/kWh - Mills per Kilowatt Hour - $ x 10-3 per kWh mm Hg - Millimeter of Mercury Pressure MOX - Mixed Oxide Fuel - Mixed UO2 - Puo2 Fuel MT - Metric Tons - 2205 Pounds MTH - Metric Tons of Heavy Metal - HM MTEM MTU - Metric Tons of Uranium MVA - Volt Amperes x 10 6
/ MW - Watts x 106 - Megawatt mwd /IIT - Megawatt-Days per Metric Ton MWD /T - Megawatt-Days per Ton MWe - Megawatts (Watts x 10 6 ) - Electrical MWt - Megawatts (Watts x 106 ) - Thermal Na - Element No. 11 - Sodium
- Liquid Metal Coolant NaK - Sodium / Potassium - Liquid Metal Coolant Mixture NASAP - Nonproliferation Alternative Systems Assessment i Program l
NASAP Codes
. e (DE) - Denatured (U-233/U-235 mixed with U-238) e (HE) - High Enrichment
( e (LE) - Low Enrichment (in U-235) e (ME) - Medium Enrichment l l 8-11 f
8.2.3 (Cont'd) NASAP CODES (Continued) e (NAT) - Natural Uranium - 0.7 w/o U-235 e Pu - Plutonium (Fissile Pu) e RE - Reprocess e T - Throwaway e Th - Thorium e 20% - 20 Weight Percent U-235 e U - Uranium o US - Uranium-235 e U3 - Uranium-233 NNS - Non-Nuclear Safety Np - Element No. 93, Neptunium - Does not occur in nature - [ intermediate in formation of Pu-239 NPGS - Nuclear Power (Electrical) Generating Station NS - Nuclear Safety O&M - Operation and Maintenance
- An ORNL code for Operation and Maintenance costs OMCOST Pa - Element No. 91 - Protactinium PEGASUS - Power Plant Economic Generator And Scale-Up System -
UE6C Proprietary Code PHS - Pittsburgh High Sulfur (Steam) Coal PHWR - Pressurized Heavy Water Reactor PLBR - Prototype Large Breeder Reactor PSI (psi) - Pounds per Square Inch PSIA (psia) - Founds per Square Inch - Absolute PSIG (psig) - Pounds per Square Inch - Gauge (14.7 psia = 0 psig) Pu - Element No. 94 - Plutonium - Does not occur in nature; two isotopes thermally fissile Pu-239, Pu-241 6-17
1 8.2.3 (Cont'd)
'Pu02 - Plutonium Dioxide
- Plutonium Sesquioxide Pu203 Pu-241 - Thermally Fissile Isotopes of Pu produced by neutron Fu-239 capture in U-238 PWR - Pressurized Water Reactor i
. QA ' - Quality Assurance QC - Quality Control
- r - Revolutions rev RESAR - Westinghouse Reference Safety Analysis Report ROI - Return on Investment RPCW - Reactor Plant Cooling Water
+
/ RPM - Revolutions per Mdnute .(
r/m s - Second SCF - Standard Cubic Feet - one cubic foot of gas at 00C and 760 Torr SCFD Standard Cubic Feet (per) Day SCF/D - (Also SCFM (per minute) and SCFH (per hour) sef/d 0 760 Torr and 0 C) sec - Second
- Square Feet - ft 2 SF S0 - Sulfur Dioxide 2
SRC - Solvent Refined Coal ST - Tons >a short ton = 2000 pounds SWU - Separative Work Unit - for Uranium Enrichment TEC - Thermal Energy Costs l Th - Element No. 90. Thorium - fertile Th-232 - the naturally occuring Th isotoperN#100% abundance l 8-13
,-n-..-_.-.,, . . - - - - -
8.2.3 (Cont'd) TM-xxxx - Technical Memorandum S/t-mi - Dollars per Ton Mile (coal transportation) TN - Ton (s) - A short ton = 2000 pounds Torr - Torricelli - 1 mm mercury; 760 Torr = 1 atmosphere = 14.7 pounds /in.2 U - Element No. 92 - Uranium UC - Uranium Monocarbide (also uranium carbide) UC2 - Uranium Dicarbide UC23 - Uranium Sesquioxide UF 6 - Uranium Hexafloride (Gas) UO 3 - Uranium Dioxide - Fuel U038 - Triuranium Octoxide - Raw Uranium Oxide Yellowcake - i / Uranium Oxide U-233 - Thermally Fissile Isotope of Uranium produced by neutron irradiation of Th-232 , U-235 - Thermally Fissile Isotope of Uranium; only naturally occurring fissile element - abundance 0.7% U-238 - Not Thermally Fissile Isotope of Uranium; most 4 abundant naturally occurring, abundance 99.3% fertile target for production of thermally fissile Pu-239 Watt - Btu /HR x 3.414 Watts /hr = Btu W(e) - Watts - Electrical W(t) - Watts - Thermal
'iLL - Western Lou Sulfur Coal Y
yr - Year = 8760 Hours = 3.154 x 107sec. 8-14
6 APPENDIX - Al PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM l i f i t l
APPENDIX A-1 DESCRIPTION OF STANDARD HYPOTHETICAL MIDDLER 0k'N SITE FOR NUCLEAR POWER PIMrS SITE DESCRIPTION A1.1 GENERAL This site description provides the site and environmental data, derived fcom Appendix A of " Guide for Economic Evaluation of Nuclear Reactor Plant Designs", USAEC Report NL'S-531, modified to reflect current requirements. These data form the bases of the criteria used for designing the facility and for eval-uating the routine and accidental release of radioactive liquids and gases to the environment. A1.2 TOPOGRAPHY AND GENERAL SITE CHARACTERISTICS I The site is located on the east bank of the North River a't a didtance of f twenty-five miles south of Middletown, the nearest large city. The North River flows from north to south and is one-half mile (2600 ft) wide adjacent to the plant site. A flood plain extends from both river banks an average distance of one-half mile, ending with hilltops generally 150 to 250 ft above the river level. Beyond this area, the topography is gently rolling, with no major critical topographical features. The plant site itself extends from river level to elevations of 50 ft above river level. The containment build-ing, other seismic Category I structures and the switchyard are located on level ground at an elevation of 18 ft above the mean river level. This eleva-tion is ten feet above the 100-year maximum river level, according to U.S. Army Corps of Engineers' studies of the area. In order to optimize land area requirements for the nuclear power plant site, maximum use of the river location is employed. The containment structure is located approximately 400 ft from the east bank of the river. The site land area is taken as approximately 500 acres. A-1-1 1
A13 SITE ACCESS Highway access is provided to the hypothetical site by five miles of secondary road connecting to a state highway; this road is in good condition and needs no additional improvements. Railroad access is provided by the construction of a spur which intersects the B&M Railroad. The length of the required spur from the main line to the plant site is assumed to be five miles in length. The North River is navigable throughout the year with a 40 ft wide by 12 ft deep channel. The distance from the shoreline to the center of the ship channel is 2000 ft. All plant shipments are assumed to be made overland except that heavy equipment (such as reactor vessel and generator stator) may be transported by barge. The Middletown Municipal Airport is located three miles west of the State highway.,15 miles south of Middletown, and ten miles ( north of the site. A1.4 POPULATION DENSITY AND 1AND USE The hypothetical site is near a large city (Middletown, 250,000 population) but in an area of low population density. Variation in population with distance from the site boundary is: i Cumulative Miles Population 0.5 0 1.0 310 2.0 1,370 5.0 5,020 10.0 28,600 20.0 133,000 30.0 1,010,000 A-1-2
1 There are five industrial manufacturing plants within 15 miles of the hypo-thetical site. Four are small plants, employing less than 100 people each. The fifth, near the airport, employs 2,500 people. Closely populated areas are found only in the centers of the small towns so that the local land area used for housing is small. The remaining land, including that across the river, is used as forest or cultivated crop land, except for railroads and highways. A1.5 NEARBY FACILITIES Utilities are available as follows: e Natural gas service is available two miles from the site boundary on the same side of the river. e Communication lines are furnished to the project boundaries
, at no Cost.
(' e Power and water for construction activities are available at the southwest corner of the site boundary. e Two independent effsite power sources (one at 500 kV and one at 230 kV) are available at the switchyard. AL6 METEOROLOGY AND CLIMATOLOGY AL6.1 Ambient Temperatures I The winters in the Middletown area are moderately cold, with average tempera-tures in the low 30s. The summers are fairly humid with average temperatures in the low 70s, and with high temperatures averaging around 82*F. The historic maximum wet bulb and dry bulb temperatures are 78'F and 99'F respectively. l The year-round temperature duration curves for the dry bulb temperatures and l coincident wet bulb temperatures are shown in Figure Al. l. A-1-3 i i l,,.,,.___. _ - - _ . . - - . - - - --
A1.6.2 Prevailing Wind According to Weather Bureau records at the Middletown Airport, located ten miles north of the site on a low plateau just east of the North River, surface winds are predominantly southwesterly 4 - 10 knots during the warm months of the year, and westerly 6 - 13 knots during the cool months. There are no large diurnal variations in wind speed or direction. Observa-tions of wind velocities at altitudes indicate a gradual increase in mean velocity and a gradual veering of the prevailing wind direction from south-west and west near the surface to westerly and northwesterly aloft. In addition to the above, studies of the area indicate that there is a sig-nificant. channeling of the winds below the surrounding hills into the north-( south orientation of the North River. It is estimated that winds within the river valley blow approximately parallel to the valley orientation in excess of 50 percent of the time. A1.6.3 Atmoseheric Diffusion Properties The transport and dilution of radioactive materials in the form of aerosols, vapors or gases released into the atmosphere from the Middletown nuclear power station are a function of the state of the atmosphere along the plu=e path, the topography of the region, and the characteristics of the effluents themselves. For a routine airborne release, the concentration of radioactive materials in the surrounding region depends on the amount of effluent released, the height of the release, the wind speed, atmospheric stability, and airflow , patterns of the site, and various effluent removal mechanisms. Geographic features such as hills and valleys influence diffusion and airflow patterns. A-1-4
l
/
Of the diffusion models that have been developed, the straight-line tra-jectory model is utilized to calculate the atmospheric diffusion from the Middletown site. The straight-line trajectory model assumes that the airflow transports and diffuses effluents along a straigh't line through the entire region of interest in the airflow direction at the release point. The version of this model which is used is the Gaussian straight-line trajectory model. In this model, the wind speed and atmospheric stability at the release point are assumed to determine the atmospheric diffusion characteristics in the direction of airflow. A long-term continuous release is assumed whose effluent is distributed [ evenly across a 22-1/2 degree sector. The model treats elevated-only, ground-level only, or mixed elevated-ground level releases, as determined by the interaction of plant characteristics and wind speeds. For elevated releases, the basic equation, modified from Turner (1970), is: l 2 h'
- (x,k ) ,
2.032 R F k( x ) y DEPL;1k ( x ) DEC; (x) f ;1.k '* P
*( 2 ,2.(x) rj
{;) U x u; agj (x) where (*>k I = average effluent concentration normalized by source strength at distance x and direction k; u; = mid-point values of the ith wind speed class; a gj(x) = vertical (z) spread of effluent at distance x for the jth stability class; A-1-5
fjp = joint probability of the ith wind speed class, jth stability class, and kth wind direction; x = downwind distance from release point or building;
, h, = effective plume height; DEC;(x) = reduction factor due to radioactive decay at distance x for the ith wind speed class; DEPL;p (x) = reduction factor due to plume depletion at distance x
'for the ith wind speed class, jth stability class, and kth wind direction; and RFk (x) = c rrection factor for air recirculation and stagnation at distance x and kth wind direction.
Ground release concentrations are calculated using the following two equations modified from Turner (1970): [ (x,k) = 2 032 RF((x) DEPL;g(x) DEC;(x) f;g u; ( a (x) +2g D jg'd (2) 2 2 h ( x,k ) , RFk (x) DEPL;g(x ) DEC; (x) f;p (d u; e,) (x) ) (3) il Where D 2 is the building height which is used to describe the dilution due to the building wake, from Yanskey, et al (1966). Equation 3 represents the maximum building wake dilution allowe"; the higher value of X/Q calculated from Equations 2 and 3 is utilized. Values of ( x,k ) are calculated at 22 downwind distances between 0.25 and I 50 miles. Each of the 16 directional sectors are divided into 10 downwind segments and an average value is determined for each sector as follows: A-1-6 1
, ,e ~ -, - -. - - - - , - - , - , - - , - , ,
- - - - - ,n,, , - - - - . - - - - - - . - . . - . - - - , , , - - , , --------c--, -, -----
R j ( X/Q) Rj' 'l (X /Q), + + rn ( X/Q ),n + R2 (X/Q)R 2 ( X / Q )5'9 : (4) R j+r++r j n
+R 2
where ,
, (X/Q)3,g = average value of X/O for the segment; (X /O ), = (x e r,k ) calculated at distance r; Rj,R2 = the downwind distance of the segment boundaries; and r j.. . r = selected radii between Rt and R2-2 7 The effluent plume is depleted via dry deposition using Figures 2 through 5
- of Regulatory Guide 1.111, Rev. 1 (1977). Ihese depletion factors are adjusted for changes in topography.
From Slade (1968) the reduction factor due to radioactive decay is: DEC: EXP ( .693 t;/ T ) (5) where t; = x/[86400 u ; ), (6) such that DEC = reduction factor due to radioactive decay; T = half life, in days, of the radioactive material; t; = travel time, in days; x = travel distance, in meters; and u; = midpoint of the windspeed class, in meters /second. Finally, for the Middletown site, the X/Q values are amended so that they are not substantially underestimated due to the effects of the regional A-1-7
, y--. - _,,-r , - - , --
recirculation and stagnation of the air. For downvalley airflow, the rela-tive concentrations are multiplied by five for distances less than 20 miles. For upvalley airflow, the con entrations are multiplied by 1.5 for all distances. . The relative deposition per unit area, D/Q, is calculated by sector for 22 downwind distances and 10 downwind segments between 0.25 and 50 miles. Elevated-only, ground-level only, or mixed elevated ground level release are utilized depending on the ratio of the effluent exit velocity to the exit level windspeed. For a 22-1/2 degree sector, the basic equation to calculate the average D/Q for a specified downwind distance is: (- RF I*I' D ( x, k ) . k u O'l
'~ f 'l'k o
(7) (2 w /16 ) x where L ( x,k ) = average relative deposition per unit area at a downwind O distance x and direction k, in meters-2; . D ij = the relative deposition rate from Figures 6 through 9 of Regulatory Guide 1.111 for the ith wind speed class (since plume height is dependent c:: windspeed) and jth stability class, in meters-1; f ijk = joint probability of the ith windspeed class, jth stability class, and kth wind direction; x = downwind distance, in meters; and RF k(x) = correction factor for air recirculation and stagnation at distance x and kth wind direction. Equation 4 is used to calculate average values of D/Q for the downwind seg-ments, with D replacing X in tho equation. l A-1-8 l
4 I i A1.6.4 Severe Meteorological Phenomena A maximum instantaneous wind velocity of 100 mph has been recorded at the site. During the past 50 years, three tropical storms, all of them in the final dissipation stages, have passed within 50 miles of the site. Some heavy precipitation and winds in excess of 40 miles per hour were recorded, but no significant damage other than to crops resulted. The area near the site experiences an average of 35 thunderstorms a year, with maximum frequency in early summer. High winds near 60 mph, heavy precipitation, and hail are recorded about_once every four years. In forty years of record keeping, there have been twenty tornadoes reported 7 within fif ty miles of the site. This moderately high frequency of tornado activity indicates a need to design Seismic Category I structures at the site for the possibility of an on-site tornado occurrence. Maximum tornado frequency occurs in May and June. During the past forty years, there have been ten storms in which freezing rain has caused power transmission line disruptions. Most of these storms have occurred in early December.
/UL.6.5 Potential Accident Release Meteorology In _the event of an accidental release of fission products to the atmosphere, transport and diffusion is determined by the meteorological conditions at the site for the duration of the accident, which is assumed to be 30 days.
The methodology required to calculate radiation dosages from accidental releases involves a series of procedures. The dosages are based upon a A-1-9
l
. l ground level release only. Each directional sector from the plant requires a separate X G value for the EAB (Exclusion Area Boundary) and the LPZ (Low Population Zone) distances. To evaluate the accident dosages, both the short-term ( $ 2 hrs) and the annual X/Q values are calculated. The annual X/Q value methodology is taken from Regulatory Guide 1.111, Section C.1.c with the effective height defined as:
h, = h s- h e where hs = stack height he = terrain height The short-term X/Q values are derived from the conditional equations y 'z I X/Q 2 1/(U10 " X/Q = 1/ 'U(w g a a +A/2) ~ (2) X/O r1/(U 10( ' # y #z with ulO = wind speed at ten meters above ground level, a ,e = horizontal and vertical dispersion coefficients, A = minimum cross-sectional area of building from which effluent is released, Iy = lateral pluce spread; a function of atmospheric stability, vind speed and downwind distance. For distances greater than 800 meiters,I y ( M -1 ) a # Y' V800 m M is a function of atmospheric stability and wind speed, as presented in Regulatory Guide 1.145 (1979), Figure 1. For distances less than 800 meters, IrMa y y A 10
1 The choice of the proper equation decennining short-term X/Q values depends upon the procedure below:
- 1. The higher X/Q value is chosen between equations (2) and (3).
- 2. If the wind speed is less than 6m/sec and the stability class is greater than or equal to D (i.e.; D, E, F or G stabilities),
then the lower X/a value given by equation (1) or by the higher value of equation (2) or (3) is chosen. q In other words, the values computed from equations (2) and (3) are compared and the higher value is selected. Then, if the meteorological conditions given in Item 2 above are true, the selected value computed from equation (2) oe (3) is compared with the value from equation (1), and the lower of these two values is chosen. l The X/Q value selected as the accident dosage is a function of the effective probability level Pc given by p, P(N/n) (4) S 9 where P = probability level which is mandated as five percent for a conservative estimate and 50 percent for realistic. N = total number of valid observations. n = total number of valid observations within a given sector. S = number of sectors. The short-term X/Q values for each meteorological condition during a given time period are tallied in a cumulative distribution table and normalized to 100 percent. The X/Q distributions for each direction are plotted on cumulative probability paper. The conservative and realistic average A-1-11
N short-term X/Q values are selectea from the graph using the effective probability values. Logarithmic interpolation is performed between the graph-selected X/Q values and the annual average X/Q values at time intervals of eight hours, 16 hours, three days and 26 days for each sector and distance of interest. For each distance, the X/Q accident values for the 16 direc-tions are compared and the highest value is selected. A1.7 HYDROLOGY The North River provides an adequate source of raw make-up water for the statioc. The average maximum temperature is 75'F, and the average minimum , is 39'F. The mean annual temperature is 57'F. U.S. Army Corps of Engineers' studies indicate that the 100 year maximum flood level rose to eight feet above the mean river level. There are no dams near the site whose failure could cause the river to rise above the eight foot level. A1.8 GEOLOGY AND SEISMOLOGY A1.8.1 Soil Profiles and Load Bearing Characteristics Soil profiles for the site show alluvial soil and rock fill to a depth of eight feet; Brassfield limestone to a depth of 30 ft; blue weathered shale and fossiliferous Richmond limestone to a depth of 50 ft; and bedrock over a depth of 50 ft. Allowable soil bearing is 6,000 psf and rock bearing characteristics are 18,000 psf and 15,000 psf for Brassfield and Richmond strata, respectively. No underground cavities exist in the limestone. A-1-12
i I A1.8.2 Seismology The site is located in a generally seismically inactive region. Historical records show three earthquakes-have~ occurred in the region between 1870 and 1975. A safe shutdown earthquake (SSE) with a horizontal ground acceleration
, of 0.25 g provides conservative design margin. For design purposes, the horizontal and vertical component Design Response Spectra given in NRC Regu-latory Guide 1.60, Rev.1, December 1973, are linearly scaled to a horizontal ground acceleration of 0.25 g.
A1.9 SEWAGE AND RADIOACTIVE WASTE DISPOSAL A1.9.1 Sewage All sewage receive primary and secondary treatment prior to discharge into the North River. A1.9.2 Caseous and Liquid Radioactive Wastes The gaseous and liquid effluent releases from this plant comply with 10 CFR Part 20 and the intent of Appendix I of 10 CFR Part 50. A1.9.3 ' Solid Radioactive Wastes Storage on site for decay is permissible but no ultimate disposal on site is planned. i A-1-13
I References Briggs, G. A., Plume Rise, AEC Critical Review Series, TID-25075, 1969, Clearinghouse for Federal Scientific and Technical Information, Springfield, Virginia. Turner, D. B., Workbook of Atmospheric Dispersion Estimates, 1970, Office of Air Programs Publication No. AP-26, Environmental Protection Agency, Research Triangle Park, North Carolina. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.111, Revision 1, Methods for Estimating Atmospheric Transport and Dispersion of Gaseous Effluents in Routine Releases from Light-Water-Cooled Reactors, 1977, USNRC Office of Standards Development, Washington, D. C. Yanskey, G. R. , Markee, E. H. , Jr. , and Richter, A. P. , Climacography of the National Reactor Testing Station,1960, Idaho Operations office, USAEC, IDO-12048, Idaho Falls, Idaho. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.145, Atmospheric Dispersion Models for Potential Accident Consequence Assessments at 7 Nuclear Power Plants, July 1979, USNRC Office of Standards Development, Washington, D.C. ( A-1-14
FIGURE A1.1 TEMPERATURE DURATION CURVES; MIDDLETOWN, U.S.A.
- 40 100 -
SITE ELEVATION: SEA LEVEL 30 80 - U o DRY BULB d 20 o 5 g 60 -
> g Q
C E D E 4 u y - 10 2 e g W WET BULB g 40 - N 0 20 -
-10 0 ' ' ' ' ' ' ' '
O 1000 2000 3000 4000 5000 6000 7000 8000 9000 CUMULATIVE DURATION, HOURS
h s b A w D
~ s
_ . > .- APPENDIX - A2
.i E IV FINAL itEPORT AND FOURTH LTPDATE OF THE ENERGY. ECONOMIC DATA BAf;E (EEDB) PROGRMi g.
O 4 lame. -* x *
+
9
=
m 9 g 4 wY V6 V ,
~ s
/
Ya
%m, 60 4
9
.e'%
e
)
9 l
l APPENDIX A-2 DESCRIPTION OF STANDAPD HYPOTHETICAL MIDDLETOWN SITE FOR COAL-F!dED POWER PLANTS SITE DESCRIPTION ; l A2.1 GENERAL This site description provides the site and environmental data as derived from
' Appendix A of " Guide for Economic Evaluat. ion of Nuclear Reactor Plant Designs",
USAEC Report NUS-531, and modified to reflect coal plant sitiEg. These data
> h form the bases of the criteria used fdr designing the facility sad for eval- '
i uating the release of liquids and 'g' arcs to the environment. 4 ' i A2.2 TOPOGRAPHY AND GtKERAL SITE CHARA TERISTICS The site is located on'th'e east bank of the North River at a distance of approximately twenty-five miles south of Middletown, the nearest large city. The North River flows from north to south and is one-half mile (2600 ft) wide i 1 adjacent to the plant site. A flood plain extends from both river banks an . - i s
+ ,
average distance of one-half mile, ending with hilltops generally 150 to 250 ft g' (r r above the river level. Beyond this area, the topography is gently rolling, with no major critical topographical features. The plant site itself extends from river level to elevations of 50 f t above river level. The primary struc- i tures and the switchyard are located on level ground at an elevation of 18 f t i above the mean river level. This elevation is ten feet alove the 100 year ' maximum river level, according to U.S. Army Corps of Engineers' studies of ' - the area. ' In order to optimize land area requirements for the coal fueled pla e site, maximum use of the river location is employed. The primary structure is ' located 1200 ft from the east bank of the river. The site land area is j approximatdly 500 acres. An additional 2,000 acres, approximately six miles from the plant site, are available for solid waste disposal. A-2-1
J j i l A2.3 SITE ACCESS Highway access is provided to the hypothetical site by five miles of secondary road connecting to a State highway. This road is in good con-dition and needs no additional improvements. Railroad access is provided by constructing a railroad spur which interseccc the B&M Railroad. The length of the required spur from the main line to the plant site is assumed
; to be five miles in length. The North River is navigable throughout the j year with a 40 ft wide by 12 ft deep channel. The distance from the t ; shoreline to the center of the ship channel is 2,000 f t. All plant ship-t ments are assumed to be made overland except that heavy equipment may be ,
transported by barge. The Middletown Municipal Airport is located three 7 miles west of the State highway,1.5 miles south of Middletown, and ten ] miles north of the site. A24 POPULATION DENSITY AND LAND USE The hypothetical site is near a large city (Middletown, of 250,000 population) but in an area of low population density. Variation in population with distance from the site boundary is: Cumulative Miles Population 0.5 0 1.0 310 i 2.0 1,370 5.0 5,020 10.0 28,600 20.0 133,000 30.0 1,010,000 A-2-2
There are five industrial manufacturing plants within 15 miles of the hypothetical site. Four are small plants employing less than 100 people each. The fifth, near the airport, employs 2,500 people. Closely populated i 4 areas are found only in the centers of the small towns, so the total land area used for housing is small. The remaining land, including that across i the river, is used as forest or cultivated crop land, except for railroads and highways. A2.5 NEARBY FACILITIES l Utilities are available as.follows: e Natural gas service is available two miles from the site boundary on the same side of the river. o Communication lines will be furnished to the project boundaries at no cost. e Power and water foi custruction activities are available at the southwest corner of the side boundary. e Two connections to the utility grid (one at 500 kV for the generator connection and one at 230 kV for the reserve auxiliary transformer connection) are available at the switchyard, t A2.6 METEOROLOGY AND CLIMATOLOGY A2.6.1 Ambient Temperatures I The winters in the Middletown area are moderately cold, with average temperatures in the low 30s. The summers are fairly humid with average temperatures in the low 70s, and with high temperatures averaging around [ 82*F. The historic maximum wet bulb and dry bulb temperatures are 78'F and 99'F respectively. The year-round temperature duration curves for the dry bulb temperatures and coincident wet bulb temperatures are shown in Figure A2.1. A-2-3 I I t
. A2.6.2 Prevailing Wind According to Weather Bureau records at the Middletown Airport, located ten miles North of the site on a low plateau just east of the North River, surface winds are predominantly southwesterly 4-10 knots during the warm months of th., year, and westerly 6-13 knots during the cool months.
There are no large diurnal variations in wind speed or direction. Observations of wind velocities at altitudes indicate a gradual increase in mean velocity and a gradual veering of the prevailing wind direction from 1 i southwest and west near the surface to westerly and northwesterly aloft. i In addition to the above, studies of the area indicate that there is a significant channeling of the winds below the surrounding hills into the north-south orientation of the North River. It is estimated that these winds within the river valley blow approximately parallel to the valley orientation in excess of 50 percent of the time. A2. 6. 3 Atmospheric Diffusion Properties The transport and dilution of materials in the form of aerosols, vapors, or gases released into the atmosphere from the Middletown coal power station are a function of the state of the atmosphere along the plume path, the l topography of the region, and the characteristics of the effluents them-l l selves. For a routine airborne release, the concentration of materials in the surrounding region depends on the amount of effluent released, the height of the release, the windspeed, atmospheric stability, and airflow patterns of the site, and various effluent removal mechanisms. Geographic features such as hills and valleys influence diffusion and airflow patterns. A-2-4 L
e 4 Of the diffusion models that have been developed, the straight line trajectory model is utilized to calculate the atmospheric diffusion from the Middletown site. The straight-line trajectory model assumes that the airflow transports and diffuses effluents along a straight line through the entire region of interest in the airflow direction at the release point. The version of this model which is used is the Gaussian straight-line trajectory model. In this model, the windspeed and atmospheric stability at the release point are assumed to determine the atmospheric diffusion characteristics in the direction of airflow. A2.6.4 Severe Meteorological Phenomena [
\
A maximum instantaneous wind velocity of 100 mph has been recorded at the site. During the past 50 years, three tropical storms, all of them in the ' final dissipation stages, have passed within 50 miles of the site. Some heavy precipitation and winds in excess of 40 miles /h were recorded, but no significant damage other than to crops resulted. The area near the site experiences an average of 35 thunderstorms a year, , epith maximum frequency in early summer. High winds near 60 mph, heavy j precipitation, and hail are recorded about once every four years. In forty years of record, there have been twenty tornadoes reported within fifty miles of the site. Maximum tornado frequency occurs during the months of May and June. A-2-5
During the past forty years, there have been ten storms in which freezing rain has caused power transmission line disruptions.- Most of these storms have occurred early in December. A2.6.5 Ambient Background Concentrations Background concentrations of SO2, NOx and particulates are typical of a rural area approximately 30 miles from a major industrial metropolitan center. They are considered when determining the plant's adherence to the guidelines. A2.6.6 Air Quality Estimation Ambient pollutant levels are estimated through the application of atmospheric g diffusion models. The estimates are based primarily upon the pollutant emissions, meteorology, topography, and background concentration as previously described. Modeling techniques described in the Turner Atmospheric Dispersion Workbook are used for concentration estimates.* A2.7 HYDROLOGY The North River provides an adequate source of raw makeup water for the station. The average maximum t emperature is 75'F and the average minimum is 39'F. The mean annual temperature is 57'F.
- Turner, D. B. , " Workbook of Atmospheric Dispersion Estimates", Public i Health Service Publication No. 999-AP-26, U.S. Department of Health, Education, and Welfare, Public Health Service, Consumer Protection and Environmental Health Service, National Air Pollution Control l Administration, Cincinnati, Ohio, Revised 1969.
i A-2-6
U.S. Army Corps of Engineers' studies indicate that the 100 year maximum
- flood level rose to eight feet above the mean river level. There are no dams near the site whose failure could cause the river to rise above the
[ eight foct level. i A2.8 GEOLOGY AND SEISMOLOGY A2.8.1 Soil Profiles and Load Bearing Characteristics Soil profiles for the site show alluvial soil and rock fill to a depth of eight feet; Brassfield limestone to a depth of 30 ft; blue weathered shale and fossiliferous Richmond limestone to a depth of 50 f t; and bedrock over a depth of 50 ft. Allowable soil bearing is 6,000 psf and rock bearing characteristics are 18,000 psf and 15,000 psf for Brassfield and Richmond strata, respectively. No underground cavities exist in the limestone. A2.8.2 Seismology The site is located in a generally seismically inactive region. Historical records show three earthquakes have occurred in the region between 1870 and 1975. A2.9 SEWAGE AND LIQUID EFFLUENTS All sewage receives primary and secondary treatment prior to discharge into the North River. Other wastewater is discharged in compliance with EPA I effluent standards _ as promulgated in 40 CFR 423. A-2-7
FIGURE A2.1 TEMPERATURE DURATION CURVES; MIDDLETOWN, U.S.A. 40 100 - SITE ELEVATION: SEA LEVEL 30 80 - U o DRY BULB d 20 o $ g 60 - Q Y $ $ { Q
=
10 $ I" y WET BULB g 40 - 0 20 -
-10 0 ' ' ' ' ' ' ' '
O 1000 2000 3000 4000 5000 6000 7000 8000 9000 CUMULATIVE DURATION, HOURS
O b G A?PENDIX - B PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM [. O e
APPENDIX B FIXED CHARGE RATES (without Inflation) B.1 GENERAL Fixed charges consist of many components which vary markedly with such factors as charter and financial structure of electric utilities, local conditions, accounting methods, etc. Therefore, although in generalized studies an
" average" fixed charge rate may be used, in practice that average will probably not apply to any individual company. The following discussion introduces the concepts involved and addresses methods of calculation of fixed charges applicable to investor-owned utilities.
For every investment made in a capital asset, the owner company commits it-self to a program of payments over the life of that asset. These payments,
/
or charges against income wwich the company expects to realize from its in-vestment, are generally fixed in nature, related only to the actual initial investment, and independent of the actual usage of the asset. These payments are commonly called fixed charges (also referred to as annual or carrying charges) and represent the absolute minimum revenue requirements which the investment must command. Because the investment in plant is recovered over its life by periodic depreciation or amortization charges, the net investment declines and consequently the fixed charges, as a percent of initial investment, vary from year to year. Therefore, it is convenient to know a "lovelized" fixed charge value, which will incorporate not only the actual year by year values of fixed charges, but also the time variance in payments. This levelized annual value (or uniform annual equivalent) permits the engineer l B-1 i l
i The fixed charges on investment plus operating and maintgnance expenses , represent the total revenue requirements needed to support the project, and can, therefore, be used for economic comparisons of alternative investment plans. The plan having the smallest revenue requirement yields the lowest costs to 1 the consumer or, where income is fixed, the greatest net return for the company. Fixed charges include the following basic items:
- 1. Return on investment - and/or - cost of borrowed money.
- 2. Depreciation - or - amortization - or - repayment of principal.
- 3. Taxes on inccme.
4 State and local taxes
- 5. Insurance
- 6. Interim replacements.
Since the components of fixed charges are all related only to the initial investment, it is usually more convenient to work with fixed charge rates rather than actual dollars. The levelized annual rate, consisting of the summation of individual rates in the above areas and levelized by present-worth methods, can then be applied to the alternative investments to yield the uniform annual equivalent total fixed charges in dollars. The concept of capital recovery encompasses the first two components of fixed charges tabulated above, namely return on investment (rate of return) and depreciation, commonly referred to as interest and principal respectively. The capital recovery rate is a levelized annual charge and is a function of the weighted rate of return and the life of the asset (book life for accounting purposes). B-3
R (1 + R)" where "R" is the rate of It is calculated from the expression (1 + R)n _1 , return expressed as a decimal and "n" is the life of the asset in years. , Capital recovery factors are tabulated in many interest tables. The factor gives that annual charge which would pay all cost of money and fully recover the invested capital over the life of the asset in equal payments. Again using the money pool concept, any schedule of payments which accomplishes the same results over the same period will have the same present-worth as the uniform annual payment schedule. For instance, the capital recovery factor for 3.50 percent and 30 years is 0.0544. This meaas that a payment of $5.44 per $100 of investment, made each year for 30 years, would fully support return plus depreciation. Now for the same case, consider paying interest on the full investment each ( year, and putting an amount into the interest-bearing money pool such that at the end of 30 years we could withdraw $100 to retire the principal. That annual deposit can be calculated from the expression R which is (1 + R)n _1 called a sinking fund factor. For our example, it comes out to be 0.0194 or
$1.94 per $100 of investment. Therefore, the total $5.44 annual capital recovery can be considered to consist of:
$3.50 (3.507.) return
+ 1.94 sinking fund depreciation SS.44 annual capital recovery B-4
9 On the other hand, we may choose to retire the $100 principal in 30 equal annual installments of $3.33, which represents a straight line depreciation rate of 3.33 percent ( 1=1 = 0.033). It is now necessary to pay interest or n 30
; return on only the net investment (outstanding balance). The interest pay-ments therefore decrease annually as shown below:
Year Net Investment Interest at 3.50% 1 $100.00 $3.50 10 70.00 2.45 20 36.67 1.28 30 3.33 0.12 ] If we compute the present-worth of all interest payments over the full 30 years, and then the uniform annual interest, the levelized payment is $2.11. Therefore, the $5.44 annual capital recovery can be considered to consist of:
$2.11 (2.11%) levelized return
+ 3.33 straight line depreciation
$5.44 annual capital recovery However, the more common presentation is in the former format, i.e., return plus sinking fund depreciation.
i In summary, it can be demonstrated that any pay-back schedule results in the 1 same levelized annual total for return plus depreciation which is readily found by using the capital recovery factor. The various components of fixed charges as they apply to private (investor owned) utilities, are discussed in Section B.2. B-5
B.2 INVESTOR-0WED UTILITIES ? - B.2.1 Return
- The weighted rate of return is the average cost of money to the utility and is 4 a composite of interest on debt and earnings for equity. Debt money comes from bondholders, while equity money is supplied by the stockholder. For a particular project, the economic analysis must be based on the average capital i
structure of the company, since in actual operation the investment under study i will become just a part of total investment in the business. 1, l For investor-owned utilities a 50/50 debt-equity ratio is not uncommon, and the range of 40/60 to 60/40 probably includes most companies. Most indentures of trust limit the debt to not more than 2/3 of added property. In some states, the percentage of total capital raised by deb't is limited by law. State and Federal Regulatory Commissions also have some control. Having established the debt-equity ratio, the interest or earnings on each component must be determined. Here the bond interest rate, to be used in f i studies, must be that which would have to be paid for new bonds, not an average of all outstanding debt, which might be considerably lower. The interest i rate must also be commensurate with risk, i.e., a company with traditionally high debt financing will require the bondholders to incur hith er risk, and they in turn will command higher rates. Equity earnings must also reflect the risk involved, and must be in proper perspective to debt interest. The weighted rate of return, illustrated in the example below, must also be checked for its reasonableness. In practice, return of the regulated electric utility industry is controlled within rather close limits. B-6 i
EXNIPLE OF WEIGHTED RATE OF RETURN .
- (Without Inflation) t Calculated j Required Yields (3) Weighted Capitalization Ratios (2)
Without Inflation Rate Of Return (Average 1955-1978) (Average 1955-1978) (Average 1955-1978) 1 52.6% Bonds 2.5% 0.013 Debt 10.9% Preferred Stock 2.7% 0.003 Equity 36.5% Common Stock 5.1% 0.019 Equity Total: 0.035 or 3.5% ( } Capitalization Ratios Ratios were obtained from DOE /EIA-0044,'5tatistics of Privately Owned Electric Utilities in the United States - 1978 and earlier editions," for the years 1955-1978 and averaged. (3) Calculated Required Yields Without Inflation Required yields without inflation were calculated for each year over the , period 1955-1978 and averaged, for bonds, preferred stock and common stock.
- The sources of the data, and the procedure used for calculating the yields without inflation are as follows
a) Bond and Preferred Stock Yields (With Inflation)
- Yields with inflation were obtained from " Moody's Public Utility Manual -1979;" Table entitled "The Market For New Utility Capital" page a3 for the year 1955-1978.
b) Common Stock Yields (With Inflation) Total yields with inflation were calculated from the following
' expression for the years 1955-1978:
Total Yield With Inflation = f + g where: fisthedividenddividedbymarket price per share g is the expected growth in dividend per year, which equals (Retained Earninas) + (Book Value) The data necessary for calculations, such as Market Prices, Earnings, Dividends, Payout Ratios and Book Values were obtained from " Moody's Public Utility Manual - 1979," Tables entitled " Utility Common Stocks - End-of-Month Averages " page a10, and " Selected Statistics On Moody's 24 Electric Utilities," pages a12 and a13. 1 B-7
.__. _ _ _ _ _ _ = - _ - _ _ . -._ . _ . . . _ . . _ _ -.____ _. _ . . _ .
l . J i i c) Calculating Yields Without Inflation i The above Bond, Preferred Stock and Common Stock yields with inflation were converted to yields without inflation by the following expression: Yield Without Inflation = (1 + d)/(1 + 1) - 1 . where: d is the yield with inflation i i is the annual rate of general inflation as measured by the implicit price deflator (IPD) for gross national product, obtained from " Business Statistics," 1979 edition, U.S. Department of Commerce / Bureau of Economic Analysis, for years 1955-1978. l 1 t i l' i i B-8
, , = _ . - . - . - _ . _ . - . . . . _ .. -. .
B. 2. 2' Depreciation 1 Dapreciation or amortization represents retirement of principal. For book purposes (plant valuation), property is depreciated lineraly over its book life. This straight line method can be represented by an annual charge at the rate of 1, as discussed earlier, or'in levelized form by the appropriate n sinking fund factor. The life selected should be the best estimate of life expectancy considering both physical deterioration and economic obsolescence factors. Commonly used lives of fossil-fired and nuclear plants are approxi-mately 30 years. In comparison, hydroelectric installations are often assigned lives of 40 to 50 years or more. . Some components of the total investment cost of a generating plant are for r non-depreciable property, the prime example of which is land. In some very detailed economic studies the cost of land and other non-depreciable com-ponents of capital investment, such as materials and supplies and working capital, are segregated and are handled by a different fixed charge rate, which does not include depreciation and hence does not decline over the years. However, in many economic studies this distinction is not made, because the i resulting error is not significant unless land is responsible for an unusually high percentage of the total capital cost. B.2.3 Taxes on Income of the revenue required to cover fixed charges, all components, except equity earnings, are expense items which are deductible from gross income for income tax purposes. However, to any requirement of revenue for equity earnings 3 must also be added the necessary revenue to pay the income tax. For example, i l st the present corporate federal income tax rate of 46 percent, it would take B-9
$100 in gross revenue to net $54 of equity return. Each year federal income tax liability declines with net investment. The levelized annual income tax rate can be calculated from the levelized equity earnings, as shown below in an example using previously cited sample data:
T l
~
e . [CRF AI (1 - T) \ n/ \ R / where T = federal income tax rate, here 0.46 and where (CRF 1)" = levelized return, computed previously as the difference between capital recovery factor and straight line depreciation rate, here 5.44 - 3.33 - 2.11 for 3.50 percent return and 30 year life. andwhere(R-bi)=thefractionoflevelizedreturnwhich is equity earnings. R = overall return, here 0.035 b = bond ratio, here 0.526 i = bond interest, here 0.025 Levelized income tax t= ~ #
.46)(0.0211) (.03 0.03 State income taxes, where applicable, can generally be handled in a similar fashion, as can any other taxes on income. Calculations often can be simpli-fled by working with a composite tax rate which is the sum of federal plus state plus other income tax rates. In this study, however, " Taxes on Income" are restricted to federal taxes only.
While the industry almost universally uses the straight-1ine method for book depreciation, liberalized or accelerated depreciation methods are commonly used for tax purposes. These methods do not reduce the total tax dollars paid over the life of the asset. but they do lead to reduction of the B-10
lavelized annual tax charge by deferring some of the taxes in the early years to later payments. There are two commonly used methods of calculating , accelerated tax depreciation. They are sum-of-years-digits (SYD) and double rate declining balance (DRDB or DDB). With SYD, the annual tax depreciation rate is a fraction whose denominator is the summation of all the numbers from one to plant life in years. The numer-30 ators decrease from plant life in years down to one. For 30 years. E yn = 465. Therefore, the first year depreciation rate is 30 second year 12. . . .down to 465 465 1 in the last year. It is obvious that
- 465 29 4 28 30 3 2 1 4 ,,,4 4 4 = 100%
465 465 465 465 465 465 I Double declining balance tax depreciation is calculated each year as twice the straight line rate times net investment. For example, for 30-years life, the normal straight line rcte is - = 3.33 percent and the DDB rate is 6.67 percent. The computation procedure is as follows: Year Net Investment -% DDB Depreciation - % 1 100.00 6.67 2 93.33 6.23 3 87.10 5.81 4 81.29 5.42 If this computation were continued for 30 years, the summation of annual depreciation entries in the DDB column will not yield 1.00 or 100 percent. It is therefore necessary to switch to the straight line method about half-way through plant life. B-ll
. There are rather complex formulae for computing the levelized annual value of accelerated depreciation. These are presented in.the sample calculations at the end of this discussion in Section B.3. 'Also given is a formula, which is , used to levelize income tax using previously calculated levelized accelerated depreciation. The tax formula reflects the fact that the tax saving attrib-T utable to accelerated depreciation is 1-T times the difference between straight line and the levelized annual tax depreciation. The federal investment tax credit (10 percent of qualified investment de-ductible from income tax in the first year only) also produces a slight re-duction in the levelized income tax charge. This reduction is calculated as the annual capital recovery of the present worth of the 10' percent credit in f year one, and is calculated to be 0.0039 or 0.39 percent as shown in Section B.3.4. .
~
Calculation of fixed charges on a flow-through basis (benefits passed on to consumers), incorporating liberalized tax depreciation and the 10 percent credit as used by most companies, yields minimum revenue requirements since the income tax component is reduced. 3.2.4 State and Local Tax _e_s, There are a variety of other types of taxation which are encountered in the investor-owned utilities industry. The more important ones are property, franchise and gross revenue taxes. Property taxes n.e IcvIed by the local community, and the rate is applied to the original (undepreciated) value of the asset. B-12
; In several of the states where the franchise tax is paid, the levy is on net income. Therefore, it is treated as a state income tax, which has been 4
discussed previously. The gross revenue or gross receipts tax, on the other hand, is levied on all revenue which the utility collects without deductions or exemptions. The tax 1 then is a revenue requirement in itself, and when used must be added to the i. subtotal of all other fixed charges. It must be noted that unlike other I types of taxation, the gross receipts tax revenue requirement must also be added to operation, maintenance and fuel expenses in economic studies. q However, since in comparison of alternatives, the effect of a gross revenue tax in to increase the differential costs between plans by the tax rate , 1 percentage, it is sometimes handled just that way, instead of carrying it
,t through individual plan fixed charge rate and operating expense calculations.
The fixed charge rate of 2.56 percent for state and local taxes, shown in Section B.2.7, is based upon information reported in DOE /EIA-044(78), " Statistics of Privately Owned Electric Utilities In The United States - 1978." It is an average for the years 1972 through 1978 (the last seven years of published data), and does not reflect the effects of general inflation over the life of the plant. l O i i B-13 I f i
, . - - - - - - . - ~
_ - - _ . . -- - -= . - B.2.5 Insurance Insurance coverage for power plants include both property damage and public liability. Liability coverage is not directly related to plant invectment and is therefore included in O&M costs.. The fixed charge rate of 0.06 percent for property damage, shown in Section B.2.7, is based upon data reported in DOE /EIA-0044(78). It is an average of the ratios of the property insurance paid by privately-owned utilities to their total investment in plant and equipment, for the years 1972 through 1978.
. i In total, annual charges for insurance usually amount to less than one percent J
of the capital investment, 2nd in some cases are even considered negligible in developing the total fixed charge rate.
/
B.2.6 Interim Replacements 1 Some utilities include a rate for interim replacements in their fixed charges. The charges represent large expenditures for replacing major equipment com-ponents of the asset during its life, where failure of such components would i impair the integrity of the asset. , Interim replacement charges, as used here, ! do not include normal maintenance costs or cost of additions made after the original construction. When used, the most commonly applied rate is 0.35 per-cent annually, which is based upon fossil-fueled power station experience. Long term expet ience upon which to base the value of this allowance for i i nuclear plants is lacking. However, it is believed that the 0.35 percent value is conservative for them, since safety-related nuclear components are subj ect to more stringent design specifications and quality control inspections. l l B-14 l l l - _
The fixed charge rate of 0.35 percent for interim replacements, shown in Section B.2.7, does not reflect the effects of general inflation over the life of the plant.
'B . 2 . 7 Typical Fixed Charges for Investor-Owned Utility Nuclear and Fossil Power Gdnerating Stations While it has been stated that there is in essence no such thing as an " average" fixed charge rate, it is nevertheless recognized that such a value is often desired. In this case, an inflation-free value of 8.67 percent, subject to additions and adjustments based upon the particular area or project under consideration, is suggested for a privately-owned utility. The levelized 8.67 percent rate (without inflation) is made up as follows:
Return: 52.6% Bonds @ 2.5% = 1.3 ( 10.9% Preferred Stock @ 2.7% = 0.3 36.5% Common Stock @ 5.1% = 1.9 Weighted Rate of Return 3.5 percent Depreciation (30 year sinking fund) 1.94 Federal Income Tax (including 10% credit and based on SYD depreciation) 0.26 State and Local Taxes 2.56 Insurance 0.06 Interim Replacements 0.35 , 8.67 percent B-15
i I
! B.3 FORMULAE AND SAMPLE CALCULATIONS FOR '
LEVELIZED VALUE OF ACCELERATED TAX DEPRECIATION Note: All sample calculations are based on the following parameters: 3.5% Weighted Rate of Return (R = .035) 52.6/47.4 Debt / Equity Ratio (b = .526) (Debt / Capital Structure Ratio) i 2.5% Bond Interest (i = .025) 30 Year Life (n = 30) B.3.1 Double Declining Balance (DDB) Depreciat-ion _D = SFF (CAF) + R (1- )" l R+ - Where: D = Levelized annual depreciation SFF= Sinking fund factor (SFF = .194 from interest tables for 30 year life and 3.5 percent return) n = Life (n = 30) CAF= Single payment compound
- amount factor (CAF = 2.81 from tables)
R = Rate of Return (R = .035) Sample calculation: 30 30 (2.81)+ .035 \ll D = .0194 30) = .0366 or 3.66%
.033 +
-f- -
i e B-16
B.3.2 Sum of Years Digits (SYD) Delreciation CRF 1
- 5. 2R (N + 1) n_
Where: D = Levelized annual' depreciation CRF = Capital recovery factor (CRF = .0544 from interest tables for 30 year life and 3.5 percent return n = Life (n = 30) R = Weighted Rate Of Return (R = .035) Sample calculation: D= 2(.0544-h = .0388 or 3.88
.035 (30 + 1)
B.3.3 Federal Income Tax t= 1 T R-d- (R - d,) Where: I = Levelized annual federal income tax T = Federal income tax rate (T = .46) currently 46 percent R = Rate of return (R = .035) d = D - SFF or Difference between levelized depreciation for a particular method and sinking fund depreciation b = Bond ratio (b = .526) i = Bond interest rate (i = .025) d = 1 - SFF or Difference between straight line and sinking fund depreciation B-17
t i i i Sample calculations: A. With straight line tax depreciation (not accelerated) i t d=d 0 = n1 - SFF = 301 .0194 = 0139 l
.46 (.526)(.025) t=1 .46 .035 .0139 - (.035 .0139) = .0112
.035 or 1.12%
j B. With double declining balance tax depreciation d = 3 - SFI = .0366 .0194 = .0172 g' d o 1 - SFF = .0139 as above
.46 t.
1 .46 .035 .0172 - (.526)(.025) (.035 .0139) = .0084 j .035 or 0.84% C. With SYD tax depreciation d = D - SFF = .0388 .0194 = .0194 do= n1 - SFF = .0139 as above
.46 t .
.46
.035 .0194 - (.526)(.025) (.035 .0139) = .0065 1 .035 or 0.65%
t B-18 i
/
B.3.4 Levelized Effect of 10 Percent Investment Tax Credit in First Year _. (4) t =
.10 (PWFy ) (CRF) (.75)
Where: I = Levelized effect of 10 percent tax credit in year one PWF y
= Single payment present-worth factor for. year one CRF = Capital recovery factor
.75 = Portion of investment qualified for investment tax credit t = .10 1.035 (.0544)(.75) = .0039 = 0.39%
( ) At times a before tax investment tax credit is utilized to offset
,the levelized annual federal income tax component of the fixed charge rate. This has the effect of slightly reducing the fixed charge rate. ~B.3.5 Summary of Sample Calculations Levelized Annual Federal Income Levelized Annual Tax in Percent Tax Depreciation Depreciation in 10% Credit in Method Percent Tax Year 1-Levelized Net Tax D t t t-t e c Straight Line 3.33 1.12 0.39 0.73 Double Declining 3.66 0.84 0.39 0.45 Balance Sum of Years Digits 3.88 0.65 0.39 ,
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APPENDIX C1 TECHNICAL MODEL INITIAL UPDATE This appendix contains Sections 5.4.1 through 5.4.9 (pages 5-4 through 5-23) ' of the " Final Report and Initial Update of the Energy Economic Data Base (EEDB) Program-Phase I", UE&C-DOE-790930. The purpose of including this material in 1 the " Phase IV Fin'al Report and Fourth Update of the Energy Economic Data Base (EEDB) Program" is to provide a convenient reference to the changes made to the Base Data Studies and Reports during the Initial Update (1978). Appendices C2 and C3 contain similar material for the Second and Third Updates respectively. i C-1-1
. _ _ _ - ~ -_ _
5.4.1 EEDB Model Number A1, Model Tvoe RWR, EEDB Initial Update
- Base Data Study: Commercial Electric Power Cost Studies - Capital Cost -
Boiling Water Reactor Plant (NUREG-0242, C00-2477-6) ACCOUNT 214 Security Building Plant security is revised to meet the requirements of Regulatory Guide 1.17,
" Protection of Nuclear Plants Against Industrial Sabotage" (Revision 1, 6/73).
The security building and upgraded security system are added to meet plant physical security requirements as currently interpreted by UE&C. The build-ing provides a controlled means of access to the plant to prevent industrial sabotage or the theft of nuclear materials. It is a reinforced concrete, Seismic Category I, structure located at grade. The building is 53 feet wide, 63 feet long and one story or 20 feet high, with a volume of approxi-mately 66,800 cubic feet. The upgraded security system costs are included in Account 253.22. ACCOUNT 218A Control Room / Diesel-Generator Building The control building and electrical tunnels are modified to meet the require-ments of Regulatory Guide 1.120, " Fire Protection Guidelines for Nuclear Power Plants" (Revision 1, 11/77). The control building is modified by add-ing a fourth floor above the control room for cable spreading. This modi-fication provides over and under cable spreading areas for the control room which allows each electrical channel to have its own spreading area separated by three-hour rated fire walls. The electrical tunnels are also modified to separate each channel with three-hour rated fire walls. 5-4
/
ACCOUNT 218T Ultimate Heat Sink Structure The ultimate heat sink basin capacity is increased from 7 to 30 days storage to meet the requirements of Regulatory Guide 1.27, " Ultimate Heat Sinks for i Nuclear Power Plants" (Revision 2, 1/76). No change is made to the super-structure which includes the north and south bays and cooling towers. ACCOUNT 224 Radwaste Processing The liquid, gaseous and solid waste systems are upgraded to improve system performance and operability. ACCOUNT 225 Fuel Handling and Storage The spent fuel pool cooling system is changed from one loop with redundant components to two separate redundant loops. This revision is made to preclude the loss of spent fuel pool cooling in the event of a pipe or valve failure in a single loop. ACCOUNT 226 Other peactor Equipment J . The boron recycle system is upgraded, consistent with changes made to the liquid radwaste system (see Account 224 above), to improve system performance and operability. ACCOUNT 234 Feed Heating System The two turbine driven boiler feed-water pumps are increased from 57 percent capacity to 80 percent capacity each to prevent reactor trip from the loss of one pump. S-S
ACCOUNT 252 Air, Water and Steam Service System The plant fire protection system is modified to meet the requirements of the additional floor in the control building and additional separation in the electrical tunnels (see Account 218A above). ACCOUNT 253 Communications Equipment The communications system is modified to meet the requirements of the addi-tional floor in the control building and additional separation in the elec-trical tunnels (see Account 218A above). The security system is revised to meet the requirements of Regulatory Guide 1.17 (see Account 214 above).. (e O t 9 S-6
5.4.2 EEDB Model Number A2, Model Type HTCR, EEDB Initial Update Base' Data Study: 3360 MWt HTGR-Steam Cycle Reference Plant Design (General Atomic Company-SC 558623) ACCOUNT 211 Yardwork The Yardwork account is modified to adjust for the "Middletown" site condi-tions described in Appendix A-1 and a single unit design versus the first of two units design of the Base Data Study. Excavation quantities are changed to reflect a rock site from the firm soil site of the Base Data Study. ACCOUNT 214 Security Building Same as subsection 5.4.1, BWR, Account 214 modification. ACCOUNT 215 Reactor Service Building, ACCOUNT 217 Fuel Storage Building ACCOUNT 218E Helium Storage Area, ACCOUNT 218I Access Building, ACCOUNT 218S Holding Pond. ACCOUNT 261.1 Makeup Water Intake and Discharge Structures These structures are reduced in size to reflect a single unit design. Fuel storage is set at 0.3 core in containerized fuel modules. ACCOUNT 224 Radwaste Processing, ACCOUNT 225 Nuclear Fuel Handling and Storage These systems and components are reduced in size and/or number to reflect a single unit design. ACCOUNT 226 Other Reactor Plant Equipment The helium storage and transfer system is reduced in size to reflect a single unit design. The nuclear service water cross connection between Units 1 and 2 is deleted. 5-7 -
't ACCOUNT 233 Condensing System The bulk chemical storage tanks for the condensate polishing system are reduced in capacity to reflect a single unit design. ACCOUNT 24 Electric Plant Equipment Offsite power connections are changed from 345 kV and 115 kV to 500 kV and 230 kV respectively. ACCOUNT 252 Auxiliary Water and Steam Service System The auxiliary steam system interconnecting piping between Units 1 and 2 is deleted, f 5-8
- ~er- - e ye -
e- ' -
5.4.3 EEDB Model Number A3, Model Type PWR, EEDB Initial Update Base Data Study: Commercial Electric Power Cost Studies - Capital Cost - Pressurized Water Reactor Flant (NUREG-0241, C00-2477-5) ACCOUNT 214 Security Building Same as subsection 5.4.1, BWR, Account 214 modification. ACCOUNT 218A Control Room / Diesel-Generator Building Same as subsection 5.4.1, BWR, Account 218A modification. ACCOUNT 218T Ultimate Heat Sink Structure same as subsection 5.4.1, BWR, Account 218T modification. ACCOUNT 224 Radwaste Processing Same as subsection 5.4.1, BWR, Account 224 modification. Additionally, a flash tank and pumps are added to the steam generator blowdown system to balance steam flow rates from the steam generators. I ACCOUNT 225 Fuel Handling and Storage Same as subsection 5.4.1. BWR, Account 225 modification. ACCOUNT 226 Other Reactor Plant Equipment Same as subsection 5.4.1, 3WR, Account 226 modification. ACCOUNT 234 Feed-Heating System Same as subsection 5.4.1, BWR, Account 234 modification. ACCOUNT 252 Air, Water and Steam Service System Same as subsection 5.4.1, BWR, Account 252 modification. ACCOUNT 253 Communications Equipment Same as subsection 5.4.1, BWR, Account 253 modification. 5-9
5.4.4 EEDB Model Number A4, Model Type PWR, EEDB Initial Update Base Data Study: Commercial Electric Power Cost Studies - Capital Cost - Pressurized Heavy Water Reactor Plant (COO-2477-13) ACCOUNT 211 Yardwork Excavation quantities are reduced to reflect replacement of PWR scaled buildings with unique PHWR design buildings. ACCOUNT 212 Reactor Containment Building, ACCOUNT 215 Reactor Service and Fuel Handling Building Material quantities are revised to reflect replacement of PWR scaled buildings with unique PHWR design buildings. ACCOUNT 214 Security Building Same as subsection 5.4.1 BWR Account 214 modification. ACCOUNT 218A Control Room / Diesel-Generator Building Same as subsection 5.4.1. BWR, Account 218A modification.
~
ACCOUNT 218T Ultimate Heat Sink Structure Same as subsection 5.4.1. BWR, Account 218T modification. ACCOUNT 23 Turbine Plant Equipment, ACCOUNT 24 Electric Plant Equipment, ACCOUNT 25 Miscellaneous Plant Equipment, ACCOUNT 26 Main Condenser Heat Re_iection System
~
System design is revised to reflect replacement of PWR designs with unique PHWR designs based on ongoing DOE studies. 5-10 1
l 5.4.5 EEDB Model Number B1, Model Type CCFR, EEDB Initial Update Base Data Study: Capital Cost - Gas Cooled Fast Reactor Plant (C00-2477-16) ACCOUNT 212 Reactor Containment Building Design of secondary containment is modified to improve constructibility and decrease cost. ACCOUNT 214 Security Building Same as subsection 5.4.1, BWR, Account 214 modification. ACCOUNT 222 Main Heat Transfer System Estimate for manhours to install steam generators is improved. f ACCOUNT 223 Safeguards Cooling System Design conservatism is reduced to reflect current practice by replacing two 100 percent pumps in each of two loops of the Core Auxiliary ' Cooling Water (CACW) system with one 50 percent pump per loop. _ ACCOUNT 226 Other Reactor Plant Equipment Design of Reactor Plant Cooling Water (RPCW) system is improved to reflect current practice by adding one RPCW heat exchanger. l ACCOUNT 227 Instrumentation and Control i Instrumentation and Control quantities are revised to reflect current practice for reactor plant diagnostic and instrumentation tubing. l ACCOUNT 233 Condensing System I l Instrumentation and Control material and labor manhours for the condensate polishing system are reduced to reflect current practice. I I 5-11 1
Y ACCOUNT 234 Feed Heating System Design conservatism is reduced to reflect current practice by deleting one of four emergency feed-water pumps and drives. Labor manhours for installation of a booster pump is increased to provide technical model consistency. ACCOUNT 237 Turbine Plant Miscellaneous Items Pipe Insulation, Account 237.31, is deleted to provide technical model consistency and eliminate double accounting. Pipe insulation is included in the individual piping system accounts. 4 l 4 5-12
5.4.6 EEDB Model Number B2, Model Type UKFBR, EEDB Initial Update Base Data Study: Technical Comparison of Prototype Large Breeder Reactor (PLBR) Phase II Competing Designs (31-109-38-3547) In the case of the LMFBR, the Base Data Studies could not be used directly as for the other Nuclear Plant Models for the following reasons:
- 1. PLBR Phase II Competing Designs were not structured in a uniform code-of-accounts for either technical or cost tabulation.
- 2. PLBR Phase II Competing Designs varied widely and were, therefore, difficult to compare or consolidate.
- 3. Quantities, commodities and costs varied widely and appeared to be overly conservative for an nth-of-a-kind plant when compared at the component level with other reactor types.
For the purposes of the EEDB Initial Update, it was desirable to include an UHFBR NPGS based on target costs of a commercially viable reactor, deployed in a time frame when the target goals have a high probability of being realized. LMFBR NPGS Target Economics Philosophy For the LMFBR NPGS to become an economically viable concept, certain cost criteria need to be met. Namely, the sum of the three cost factors contri-buting to energy cost (Capital, Fuel Cycle, and O&M) must combine to provide an energy cost equal to or less than competing forms of energy production. The Light Water Reactor Nuclear Power Generating Station as represented by the PWR NPGS is chosen as the present competition for the LMFBR NPCS. The current EEDB goal is to eliminate cost over-conservatism and cost uncertainties which have prevailed over the past few years by developing a commercial cost estimate for a LMFBR NPGS, based upon an nth-of-a-kind unit, designed to com-mercial type nuclear standards and regulations. The year 2001 is selected as 5-13
h the target date when the LMFBR NPGS should become competitive. This date takes into account the present research and development requirements of the concept, as well as allowing for the predicted increase in the cost of uranium to a minimum value of $62 per pound (in constant $1978), where a break-even point is more likely. A review of Tables 4-6 and 5-3 provides insight into the required relative target cost of the LMFBR vs. the PWR to achieve a m/kWh break-even energy cost. A goal of UHFBR NPGS capital cost equal to about 1.25 times the PWR cost is established. This ratio equates to a maximum delta of approximately 135 $/kWe (in $1978) by which the Base Construction cost of a 3800 MWt LKFBR NPGS can exceed that of a PWR NPCS of the same thermal capacity. To achieve these goals a set of target costs is established which, if met, would create a competitive LMFBR. The largest legally licensable plant (3800 MWt) is selected since the economy of scale will have a positive effect in achieving the goal. Basic ground-rules to govern the cost estimating are also established to ensure that the costs reflect a realistic commercial concept within the bounds of current regulations. I The method utilized to evaluate and control the costs is to compare the UTFBR cost estimates on a commodity basis, such as $/Ft2, $/HP, etc., with that of the PWR. When a significant difference is noted without reasonable technical i justification, additional attention is focused to bring the cost to a reason-able value. In this manner, costs estimated on an overly-pessimistic basis can be improved, 5-14 l l
In future work, an effort should be made to define concept improvements, which although not necessarily licensable at the present time, can. reasonably be assumed to be licensable by the year 2000. Items such as expansion joints instead of expansion loops in sodium piping and new cost saving materials need to be evaluated for further cost improvements. LMFBR NPGS Cost Basis To implement the Target Economics philosophy, a 1390 MWe, loop type, LMTBR central station power plant is selected for the study. Using the experience gained from the Base Data Studies, UE&C designed the Balance of Plant systems, and retained Combustion Engineering, Inc. to develop a Nuclear Steam Supply System, in accordance with the above philosophy. .
/ The plant design incorporates a 3800 MWt (1390 MWe), 8500F, 2200 psig LMFBR Nuclear Steam Supply System, which is described in Combustion Engineering, Inc.
Report CE-FBR-78-532, "NSSS Capital Costs for a Mature LMFBR Industry." A copy of this report may be found in Appendix D-1. Further discussion of the Target Economics Philosophy for the LMTEP NPGS is included in Appendix D-2. A plant size of 3800 MWe is selected to achieve the maximum benefit of economy of scale within the current regulatory limit. Other design features to mini-mize costs that are incorporated, within the lLaits of currenc regulatory requirements, are as follows: o The safety related NSSS buildings are clustered around the contain-ment building and share a common base mat founded on rock. 5-15
o The reactor plant incorporates four primary and four secondary loops with four intermediate heat exchangers and four primary and four secondary pumps. Four primary loop check valves are located within the reactor vessel. o The steam generation system is of the Benson Cycle type, utilizing two single wall tube steam generators for each of the four loops, o The turbine plant consists of a cross-compound turbine with four double flow low pressure stages. The inlet conditions to the high pressure turbine are 8500F @ 2200 psia. o The safety related decay heat removal function is fulfilled by two 100 percent Auxiliary Heat Transfer Systems which cool the primary sodium directly from the reactor vessel without requiring the primary loops to be operating. o The secondary loops provide no emergency function and are classi-fied non-nuclear downstream of the external isolation valves at the containment. o The steam generators are classified as non-nuclear, and the steam generator buildings are non-Seismic Category I. Fuel handling is of the "under-the-head" type with 1/3 core storage o inside the containment structure, isolated from the primary con-tainment volume to permit fuel transfer during normal reactor operations. o Guard vessels for the primary system have been eliminated by the utilization of filler block around the reactor vessel, and siphon breaker lines. For the EEDB Initial Update sodium, NaK and Dowtherm inventories are not included. Results The LMFBR/PWR capital cost ($/kW basis) ratio goal of 1.25 is not realized during this first attempt at target economics. However, a cost ratio of 1.32 (refer to Table 5-3) is achieved. This ratio achieves a slightly lower than break-even cost for the LMFBR vs. the PWR, because a uranium cost of approxi-mately $62 per pound (constant $1978) is used in the fuel cycle study for j the year 2001. (Refer to Table 4-7) l 5-16 l
5.4.7 EEDB Model Number Cl, Model Tyse HS12, EEDB Initial Update EEDB Model Number C3, Model Type LS12, EEDB Initial Update i Base Data Study: Commercial Electric Power Cost Studies - Capital Cost - High and Low Sulfur Coal Plants - 1200 MWe (Nominal) (NUREG-0243, C00-2477-7) ACCOUNT 219 Stack Structure The stack height is increased from 600 feet to 750 feet to meet the require-ments of the Clean A'r Act Amendments of 1977. The stack structure is changed from a brick to steel liner due to the increase in height. ACCOUNT 223 Ash and Dust Handling System The ash and dust handling systems are upgraded to improve system performance and operability. r ACCOUNT 233 Condensing Systems The condenser design is upgraded to improve system heat rate. Licensability As discussed in subsection 4.5.1, these coal-fired power plants are not designed to meet the proposed revisions to the emission standards current on January 1, 1978. However, cost adders are given in subsection 4.5.1 to permit the adjustment of the EEDB Initial Update capital costs, to reflect the impact of including these proposed changes. It should be pointed out, there is some doubt that coal-fired power plants designed to meet emission standards requirements current for January 1, 1978, can be sited where desired in all cases. The' most desirable location may be a lightly to heavily industrialized area. For such sites, where topograph-ical features are not optimum, there is a probability that additional capital 5-17
expenditures may be required for the plant to remain in compliance con-tinuously. Appendix D-3 addresses this subjec't in greater detail. No attempt has been made, during this initial update, to predict levels of potential additional capital expenditure requirements, because the emission standards are currently in a state of change.
/
i 5-18
5.4.8 EEDB Model Number C2, Model Type HS8, EEDB Initial Update EEDB Model Number C4, Model Type LS8, EEDB Initial Update Base Data Study: Commercial Electric Power Cost Studies - Capital Cost - Low and High Sulfur Coal Plants - 800 MWe (Nominal) (NUREG-0244, C00-2477-8) ACCOUNT 219 Stack Structures
- Same as subsection 5.4.7, HS12/LS12, Account 219 modification.
ACCOUNT 223 Ash and Dust Handling System Same as subsection 5.4.7, HS12/LS12, Account 223 modification.
. ACCOUNT 233 Condensing System Same as subsection 5.4.7, HS12/LS12 Account 233 modification.
, Licensability Same as subsection 5.4.7, HS12/LS12, Licensabil.ity. a 5-19
l i 5.4.9 EEDB Model Number Dl, Model Tvpe CGCC, EEDB Initial Update Base Data Study: Study of Electric Plant Applications for Low Btu Gasifi-cation of Coal for Electric Power Generation (FE-1545-59) s The technical description and cost estimate for the coal gasification power plant are based on a conceptual balance-of-plant study performed by UE&C for Combustion Engineering, Inc. This study has been extended to a complete plant under the Energy Economic Data Base program. Combustion Engineering provided costs and design data for several systems. Combustion Engineering has been developing this concept since 1970, supported in part by the Department of Energy and the Electric Power Research Institute. A process demonstration unit is now operating, and demonstration plant pre-liminary designs are being prepared. Except for the gasification process unit and the gas turbines, all plant com-ponents are readily available commercial equipment which are commonly used in power plants or natural gas processing facilities. The gasifier itself is very similar to pulverized coal-fired boilers. The gas turbines utilize current technology but are not now on the market. Because the plant produces elemental sulfur as a by-product, the environmental effects are significantly less than direct coal-fired plants with 502 scrubbers. Technical Description This plant is a combined cycle electric power plant which is fired by gasified coal. The coal is gasified in an air-blown, entrained bed gasifier. The resulting gas, which has a low heating value, is cleaned and the sulfur is removed using the Stretford process. The clean gas is compressed and burned 5-20
I i in gas turbines,. which generate a total of 283 MWe. The exhaust gas from the gas turbines passes through vaste heat boilers to produce steam, which drives a 372 MWe steam turbine-generator. The net plant catput is 630 MWe. The net station heat rate is 8250 Beu/kWh. Plant thermal efficiency is about 41 percent. Coal Handling System The coal handling system is standard for a power plant of this size. Rail- , road cars dump to a hopper-type unloader. The coal is stacked out, reclaimed by lowering wells, crushed, and pulverized. Thaw sheds, car shakers, and distribution and sampling systems are included. Coal storage space holds a 90-day reserve. The plant uses 195 tons per hour of Pittsburgh Steam coal (13,480 Btu /lb-Dry. 2.6 percent sulfur, 2.4 percent moisture). However, the entrained bed gasi-fier can handle most types of coal. Ash Handling System The ash handling system is a standard system handling 18 tons per hour of molten slag. Casifier The two gasifiers are air-blown, entrained bed gasifiers. They are similar to standard water-wall boilers and have superheater and reheater sections. The gasifier provides about one-half of the steam produced in the plant. The gasifier produces 2.3 million pounds per hour of fuel gas, a mixture of carbon monoxide, carbon dioxide, methane, hydrogen, and nitrogen. Sulfur in 5-21
j i i the gas is 90 percent H2S and 10 percent carbonyl sulfide (COS). The heating - t value of the gas is assumed to be about 110 Btu /SCF, although recent pilot , j plant data has been reported in the 120 to 140 Btu /SCF. range. Gas Clean-up System Cyclones remove most of the particulates in the raw gas, which are recycled into the gasifier. Fine cleaning is accomplished with a wet scrubber, with wastes recycled to the gasifier. The H2S is then removed by the Stretford process. About 90 tons per day of elemental sulfur are produced, with a small waste stream, which is also recycled to the gasifier. In this plant, the COS is burned with the fuel gas, producing S02 which is released. Because only 10 percent of the sulfur occurs as COS, the plant will
/
comply with regulations requiring 90 percent sulfur removal. If this level of S02 removal violates future regulations, the COS can be shifted to H2S j before Stretford processing. , Gas Turbine-Generators Four gas turbine-generator units compress and burn the fuel gas, with a net output of 70.8 MWe each. The gas turbines are rated at an inlet temperature of 2200 F, which is somewhat higher than currently available turbines. Re-l ducing the inlet temperature would cause a reduction in plant efficiency. Waste Heat Boilers Four waste heat boilers convert the exhaust heat to steam. Primary steam production is about 500,000 lb/hr at 2600 psig and 10000F. Reheat to 1000oF i
, is included, and low pressure steam is produced in another section, i
5-22 l 7 mmp- -e.--n.--- + ,i,,-y- _ , - - - .
~ , - - - - - ,,r -- -
Steam Turbine-Generator The standard steam turbine-generator system produces 372 MWe. The design steam flow is 1.99 million pounds per hour, with a back pressure of 2.0 inches of mercury. The generator is rated at 410 MVA. Cooling System The main cooling system utilizes a wet, natural draft, hyperbolic cooling tower, approximately 300 feet in diameter and 400 feet high. Waste Treatment The waste treatment system. handles the relatively small quantity of waste from the. cooling and ash handling systems. The system includes filtration, neutralizing, and a sediment basin.
/
Economic Description The costs estimated for the coal gasification combined cycle power plant are an extension of studies performed for DOE and EPRI by Combustion Engineering, Inc. United Engineers & Constructors Inc. estimated balance-of-plant costs for C-E. The cost design basis is not entirely consistent with the other plants esti-mated for the EEDB Initial Update; however, the differences are considered to i be negligible. I 5-23 I
O O l l t APPENDIX - C2 PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM i l { l i
APPENDIX C2 TECHNICAL MODEL SECOND UPDATE This appendix contains Sections 5.4.2.1, 5.4.2.2, 5.4.2, and 5.4.3 (pages 5-5 through 5-7 o'f the Phace II Final Report and Second Update of Energy Economic Data Base (EEDB) Program", UE&C/ DOE-810430. "The purpose of including this material in the " Phase IV Final Report sud Fourth Update of the Energy Economic Data Base (EEDB) Program" is to provide a convenient reference to the changes made to the Base Data Studies and Reports and Initial Update (1978) modifications during the Second Update (1979). Appendices C1 and C3 contain similar material for the Initial and Third Updates respectively, s f l l C-2-1 l
5.4.2 Specific Modifications 5.4.2.1 EEDB Model Number A5. Model Type LMFBR, EEDB Second Update Base Data Study: NSSS Capital Costs for a Mature LMFBR Industry (Combustion Engineering, Inc. CE-FBR-78-532) The NSSS for the Initial Update is based on the cost estimate provided by the Base Data Study. Due to limited time and funding, the Balance of Plant (BOP) for the Initial Update cost estimate is based on numerous assumptions and scaling of structure and system costs of other EEDB models. The 1978 cost included 1/3 core fuel storage, and a scaled fossil plant type, cross-compound turbine generator based on an estimated plant efficiency of 36.6%. Total net output was 1390 MWe. For the EEDB Second Update, the entire plant was reviewed and a conceptual design prepared sufficient for detailed costing basis. Structures were de-signed where necessary, and commodities of all structures were determined. BOP systems were designed, as necessary, in sufficient detail for detailed cost estimates and mini-specification development. The NSSS for 1979 was based on the Base Data Study, escalated to 1979 dollars. This also included a 1/3 core storage. The BOP was based on a steam cycle proposed by Brown Boveri. This steam cycle included a two stage steam re-heat with a large tandem-compound turbine-generator with a plant efficiency of 38.3*. This increased the net electric output from 1390 MWe reported in the Initial Update cost estimate to 1457 MWe for the Second Update. 5-5
During the Second Update, a Topical Report was prepared on a new approach to the LMFBR Demonstration Program. The report discusses the feasibility of building a 1500 MWe demonstration LMFBR NPGS, utilizing a nominal 750 MWe conceptual design as an intermediate step. This report is presented in Appendix E. , The basic Target Economic philosophy, described in Appendix C, remains as the basis for the LMFBR NPGS cost estimate. The principle result of the effort described above is to expand the detail for the LMFBR Technical and Cost Models to the ninth-digit level of detail. This expansion provides a more detailed equipment list with. mini-specifications, a more detailed cost breakdown and sufficient detail to provide a material and commodity tabulation. 5.4.2.2 EEDB Model Number D2, Model Type CLIQ, EEDB and Second Update Base Data Study: Recycle SRC Processing for Liquid and Solid Fuels, Gulf Mineral Resources Company This Model has been deleted from the EEDB because adequate data for an up-date is not available. 5.4.3 Ongoing Modifications f During the course of preparing the Second Update of the EEDB, it became l apparent that modiciations were required for some of the Technical Models l that would take more effort than could be allotted to the resources avail-able for a single update. Consequently, these efforts are spread over Second and Thir'd Updates but, although they are initiated in the Second 5-6
Update, the results will not be reported until the Third Update is completed Among these efforts are the following: e Replacement of the 3360 MWe HTGR NPGS (Model A2) with a smaller sized unit, consistent with the current thinking and emphasis of General Atomic Company and Gas Cooled Reactor Associates (a Utility Sponsored HTGR NPGS Development Group).
- e. Replacement of the 1162 MWe PHWR NPCS (Model A4) based on the Canadian CANDU design with a large PHWR NPGS based on a U.S.
design. e Continued upgrading of the LMFBR NPGS (Model A5) to reflect information contained in current commercialization studies, within the framework of the Target Economic approach, and to incorporate under-the-head refueling and one-and-one-third core storage. e Evaluation of the Flue Gas Desulfurization system design for the High Sulfur Coal FPGS (Models C1 and C2), with respect to the revised New Source Performance Standards. e Addition of the Flue Gas Desulfurization Systems to the Low Sulfur Coal FPGS (Models C3 and C4), to meet the revised New Source Performance Standards. e Reevaluation of the major cost drivers which comprise 85% of the plant cost; specifically Structures, Nuclear Steam Supply Systens, Turbine-Generator Units, Piping Systems, and Electric and Instrumentation and Control Systems. e Evaluation of installation labor hours to reflect the growing realization in the industry that these hours may be understated for NPCS. i 5-7
O P El APPENDIX - C3 PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM C 1
APPENDIX C3 TECHNICAL MODEL THIRD UPDATE This appendix contains Sections 5.4.2.1 through 5.4.2.11.(pages 5-6 through
~
5-28) of the " Phase III Final Report and Third Update of the Energy Economic Data Base (EEDB) Program", UE&C-DOE-810731. The purpose of including this material in the " Phase IV Final Report and Fourth Update of the Energy Economic Data Base (EEDB) Pregram" is to provide a convenient reference to the changes made to the Base Data Studies and Reports and the Initial and following updates during the Third Update. Appendices C1 and C2 contain similar material for the Initial and Second Update respectively. C-3-1
5.4.2.1 EEDB Model Number Al, Model Type BWR, EEDB Third (1980) Update Base Data Study: Commercial Electric Power Cost Studies - Capital Cost - Boiling Water Reactor Plant (NUREG-0242, C00-2477-6) ACCOUNT 220A Nuclear Steam Supply System (NSSS) The nuclear steam supply package is reviewed for conformance with current manufacturers' quotations. No significant technical changes are required. ACCOUNT 231 Turb ine-Gene rato r The turbine-generator is reviewed for conformance with current manufacturers' quotations. No significant technical changes are required. ACCOUNT 233 Condensing Systems The main condenser tube material is changed from 90-10 copper-nickel to
/
stainless steel to reflect the current trend in BWR plant design. ACCOUNT 241 Switchgear ACCOUNT 242 Station Service Equipment ACCOUNT 245 Electric Structures and Wiring Containers ACCOUNT 246 Power and Control Wiring The electrical distribution system is modified to support the changes to the main cooling towers (refer to Account 262). ACCOUNT 262 Main Condenser Heat Rejection System / Mechanical Equipment The design of the main cooling towers is changed to reflect current vendor capabilities and practice. The quantity and diameter of the towers are changed from three and 260 feet to two and 285 feet, respectively. The number of fans per tower is changed from 12 to 16. 5-6
1 5.4.2.2 EEDB Model Number A2, Model Type HTGR-SC, EEDB Third (1980) Update i The six loop, 3360 MWe, 1330 MWe HTGR NPGS is replaced in the Third Update
~
with a four loop, 2240 MWe, 858 MW HTGR-SC (Steam Cycle) NPGS. Considerable work has been performed during the last several years to improve the commercial viability of the HTGR concept. This work has been done by Gas Cooled Reactor Associates (GCRA), an electric utility consortium, in conjunction with General Atomic Company (GAC), and with the assistance of USDOE funding. The decision to replace the six loop plant with the four loop plant in the EEDB is based on two facts. First, the ongoing GCRA work has rendered the EEDB six-loop model obsolete. Second, GCRA and GAC are currently concentrating
~i their ef forts on the smaller plant as the preferred concept. The basis for the EEDB four, loop plant is the following study.
Base Data Study: The HTGR for Electric Power Generation. - Design and Cost Evaluation (GCRA/AE/78-1) The conceptual design and cost estimates described in this base data study are directly compatible with the EEDB Program. Therefore, the study results are directly incorporated into the EEDB with the following modifications to meet the EEDB groundrules and the revisions incorporated in the Third Update:
- 1. Minor modifications are made to transfer the conceptual design from an Eastern Pennsylvania site to the " Middle-town" site.
- 2. Minor modifications are made to obtain conformance to the EEDB Code-of-Accounts.
i 5-7
5.4.2.3 EEDB Model Number A3, Model Type PWR, EEDB Third (1980) Update Base Data Study: Commercial Electric Power Cost Studies - Capital Cost - Pressurized Water Reactor Plant (NUREG-0241, C00-2477-5) ACCOUNT 220A Nuclear Steam Supply System (NSSS) The nuclear steam supply package is reviewed for conformance with current manufacturers' quotations. No significant technical changes are required. ACCOUNT 231 Turbine-Generator The turbire-generator is reviewed for conformance with current manufacturers' quotations. No significant technical changes are required. ACCOUNT 241 Switchgear
- ACCOUNT 242 Station Service Equipment ACCOUNT 245 Electric Structures and Wiring Containers ACCOUNT 246 Power and Control Wiring The electrical distribution system is modified to support the changes to the main cooling towers (refer to Account 262).
ACCOUNT 262 Main Condenser Heat Rejection System / Mechanical Equipment The design of the main cooling towers is changed to reflect current vendor capabilities and' practice. The quantity and diameter of the towers are changed from three and 250 feet to two and 285 feet, respectively. The number of fans per tower is changed from 12 to 16. l 5-9
5.4.2.4 EEDB Model Number A4, Model Type PHWR, EEDB Third (1980) Update The three loop, 3800 MWt, 1162 MWe CANDU type PHWR NPGS is replaced in the Third Update with a two loop 3800 MWt, 1260 MWe PHWR NPGS, specifically designed for U.S. siting. This replacement is made to accommodate the desire of USDOE to meet the EEDB objective with alternatives based on U.S. designs sited in the contiguous United States. The study selected as the basis for this change is the following joint Combustion Engineering / United Engineers study, funded by USDOE. Base Data Study: Conceptual Design of a Large NWR for U.S. Siting (Combustion Engineering, Inc. CEND-379) The conceptual design and cost estimates described in this base data study are / directly compatible with the EEDB Program. Therefore, the study results are directly incorporated into the EEDB with the following modifications to meet the EEDB groundrules and the revisions incorporated in the Third Update:
- 1. Modifications are made to replace refrigeration systems, used for primary, moderator and reactor plant service cooling, with conventional water systems.
- 2. Modifications are made in the Structural Electric Plant and Miscellaneous Plant account's to support the replacement of the refrigeration systems used for primary, moderator and reactor plant service cooling.
3. Modifications are made to increase the construction site labor manhours to approximately 17 manhours per kilowatt (Refer to Section 5.5.1)
- 4. The design of the main cooling towers is modified to reflect current vendor capabilities and practice.
5-10
5.4.2.5A EEDB Model Number B1, Model Type GCFR, EEDB Third (1980) Update - Deleted_ Base Data Study: Capital Cost - Gas Cooled Fast Reactor Plant (C00-2177-16) The Gas Cooled Fast Breeder Reactor NPGS is deleted from the data base in the Third Update. The decision to make this deletion is based on two facts. First, the ongoing GCRA/GAC work on the HTGR, described in Section 5.4.2.2, has been incorporated into the GAC GCFR NPGS development, rendering the EEDB conceptual design obsolete. Second, the extensive revisions required to. update the GCFR NPGS cannot be currently accommodated by the priorities set and the resources available for the EEDB Program. 1 7 5-11 a
---m ,
5.4.2.5B EEDB Model Number B1, Model Type HTGR-PS, EEDB Third (1980) Update An 1170 MWt, 150 MWe HTGR-PS (Process Steam Cogeneration) NPGS is added to the data base in the Third Update. The decision to add the HTGR-PS NPGS is based upon the need to expand the data base into the area of nuclear cogeneration in general and process steam from HTGRs in particular. The basis for this additon is the following USDOE sponsored study. Base Data Study: 1170 MWt HTGR Steamer Cogeneration Plant - Design and Cost Study (UE6C/ DOE-800716) The conceptual design and cost estimates described in this base data study are directly compatible with the EEDB Program. Therefore, the study results are directly incorporated into the EEDB with the following modifications to meet the EEDB groundrules and the revisions incorporated in the Third Update:
- 1. Minor modifications are made to transfer the conceptual design from an Eastern Pennsylvania site to the " Middle-town" site.
- 2. Minor modifications are made to obtain conformance to the EEDB Code-of-Accounts.
- 3. Modifications are made to increase the construction site labor manhours to approximately 17 manhours per kilowatt (Refer to Section 5.5.1).
- 4. The design of the main cooling towers is changed to reflect current vendor capabilities and practice.
5-12
. . - - - - . . _ _ _ - _ . . _ _ , _ . _ _ _ - - , , - ._.____.m -. ..- -___ -
5.4.2.6 EEDB Model Number A5, Model Tvpe UHFBR, EEDB Third (1980) Update Base Data Study: NSSS Capital Costs for a Mature LMFBR Industry and Addendum (Combustion Engineering Inc. - CE-FBR 532 6 CE-ADD-80-310) ACCOUNT 211 Yardwork The excavation for the nuclear island buildings is increased. The increase is the result of revisions to the nuclear island building plan and location of the base mat, 24 feet deeper in the ground (refer to Account 212). ACCOUNT 212 Reactor Containment Building The containment building is increased in overall height by 24 feet to provide additional space for miscellaneous equipment and the containment cell gas cooling systems (refer to Account 220A). In addition, the internal structure is revised to accommodate a larger reactor vessel, a reactor guard vessel, revised fuel handling, and the removal of the ex-vessel fuel storage tank
.(refer to Account 220A). The cylindrical portion of the containment has an inside diameter of 187 feet. It measures 227 feet from the top of the foundation mat to the springline of the dome. The inside height from the top of the mat to the dome is 274.5 feet. The gross volume of the containment is 7,100,000 cubic feet.
ACCOUNT 215 Reactor Service Building The reactor service building is revised to accommodate an increased fuel handling requirement which includes the housing of a larger (1-1/3 core capacity) ex-vessel storage tank (refer to Account 220A). This building is increased in height to maintain compatibility with the containmer.t building and to provide additional equipment space. 5-13
)
]
l The major portion of the reactor service building is 146 feet high, abuts the containment and has one straight side of l31 feet, and the other side is
~"
3 145 feet. The overall volume is 2,280 x 10 cubic feet. ACCOUNT 218E Steam Generator Buildings The steam generator buildings are revised to adjust the structures to account for an additional 24 feet of below-grade design. Overall height of the build-ings remains unchanged (refer to Account 212). ACCOUNT 218W Auxiliary Heat Transport System Bays The bay adjacent to the reactor service building is revised to be compatible with the floor plans of the new reactor service building (refer to Account 215). ACCOUNT 220A Nuclear Steam Supply System (NSSS) This account is revised based on Combustion Engineering Report CE-ADD-80-310, "NSSS Capital Costs for a Mature UHFBR Industry - Addendum." A copy of this report is included in Appendix E. This revision includes a larger reactor vessel with internal downcomers and a reactor vessel guard-vessel. Also incorporated in this addendum is a revised fuel handling system with a 1-1/3 core fuel storage capability. The larger fuel storage vessel and guard-vessel are located in the reactor service building and replace the 1/3 core fuel storage vessel located in the reactor containment building in EEDB Phases 1 & 11 Conceptual design. The primary sodium loop isolation valves are eliminated in the Third Update. ACCOUNT 222 Main Heat Trans fer Transport Svstem This account is revised to reflect the decrease in primary sodium loop piping which results from the increase in reactor vessel diameter (refer to Account 220A). 5-14
ACCOUNT 225 Fuel Handling The fuel handling system installation is revised to reflect the changes in NSSS fuel handling equipment (refer to Account 220A). The ex-vessel storage 1 tank (EVST) cooling system capacity is increased to accommodate the need to remove 1-1/3 core spent fuel decay heat, f ACCOUNT 226 Other Reactor Plant Equipment The cell cooling systems are revised to conform to the latest NSSS configura-tion (refer to Account 220A). Two systems, the reactor head, and the machinery dome cooling systems'are deleted. A system' to cool the cell that contains the EVST sodium cooling system is added. - ACCOUNT 241 Switchgear
. ACCOUNT 242 Station Service Equipment ACCOUNT 245 Electric Structures and Wiring Containers ACCOUNT 246 Power and Control Wiring The electrical distribution system is modified to support the changes to the Nuclear Steam Supply System and the main cooling towers (refer to Accounts 220A and 262).
ACCOUNT 252 Air, Water And Steam Service System The passive sodium fire protection systems are revised to reflect current technology. ACCOUNT 262 Mechanical Equipment The design of the main cooling towers is changed to reflect current vendor capabilities and practice. The number of cooling towers is changed from 3 to 2. The new towers are 285 feet in diameter and 35 feet to the fan deck,iEach tower uses 16 - 33 foot diameter f ans per tower. I t 5-15
1 1 1 Revised 10/06/81 ! 5.4.2.7 EEDB " 1 Number Cl, Model Type HS12, EEDB Third (1980) Update
- Base Data Study: Commercial Electric Power Cost Stuoies - Capital Cost -
High and Low Sulfur Coal Plan'es - 1200 MWe (Nominal) (NUREG-0243, C00-2477-7) ACCOUNT 220A Fossil Steam Supply Steam The fossil steam supply system package is reviewed for conformance with current manufacturers' quotations. No significant technical changes are required. ACCOUNT 222 Draft System The electrostatic precipitators (which are part of the draf t system account) are upgraded to meet the 1979 Mew Source Performance Standards (NSPS) particu-late limit of 0.03 pounds per million Btu heat input. ACCOUNT 225 Flue Cas Desulfurization Structures The flue gas desulfurization structures are modified to accommodate the up-graded flue gas desulfurization system (refer to Account 226). ACCOUNT 226 Desulfurization Equipment The flue gas desulfurization system is upgraded to meet the 1979 New Source Performance Standards sulfur dioxide (SO 2
) limit f 0.60 pounds per million Btu heat input with S0 rem val between 70% and 90%.
2 ACCOUNT 2 31 Turbine-Generator The turbine-generator is reviewed for conformance with current manufacturers' quotations. No significant technical changes are required. 5-16
. _ . . . _ . , _ _ _ - _ _ ~ _ _ _ - - _ -
ACCOLNT 241 Switchgear ACCOLNT 242 Station Servica Equipment ACCOLNT 245 Electric Structures and Wiring Containers ACCOLNT 246 Power and Control Wiring The electrical distribution system is modified to support the changes to the
, precipitator, flue gas desulfurization system, and main cooling towers
.i (re'fer to Accounts 222,226 and 262). ACCOLNT 262 Main Condenser Heat Rejection System /$echanical Equipment The design of the main cooling towers is modified to reflect current vendor capabilities and practice. 4 1 I 1 5-17 i y_,___..__ __ _ _ _ , , , _ , _ _ . _ , _ _ _ . _ . _ _ _ , , . _ _ . _ _ _ _-_ _ , _
5.4.2.8 EEDB Model Number C2, Model Type HS8, EEDB Third (1980) Update Base Data Study: Commercial Electric Power Cost Studies - Capital Cost - Low and High Sulfur Coal Plants - 800 Ma'e (Nominal) (NUREG-0244, C00-2477-8) ACCOUNT 220A Fossil Steam Supply System The fossil steam supply system package is reviewed for conformance with current manufacturers' quotations. No significant technical changes are required. ACCOUNT 222 Draft System The electrostatic precipitators (which are part of the draft system account) j are upgraded to meet the 1979 New Source Performance Standards (NSPS) particu- { 1 ate limit of 0.03 pounds per million Btu heat input. ACCOUNT 225 Flue Gas Desulfurization Structures The flue gas desulfurization structures are modified to accommodate the up-i graded flue gas desulfurization system (refer to Account 226). ACCOUNT 226 Desulfurization Equipment The flue gas desulfurization system is upgraded to meet the 1979 New Source Performance Standards (NSPS) sulfur dioxide (SO 2
) limit f 0.06 pounds per million Btu heat input with S0 rem 2 val between 70% and 90%.
ACCOUNT 231 Turbine-Generator The turbine-generator is reviewed for conformance with current manufacturers' quotations. No significant technical changes are required. ' 5-17,
.m , . _ _ _ . , _ - _ _ _ _ _ . . , . _ _ , . - _ _ - . . _ _ . _ , _ , , . _ . _ . , _ . - _ . , _ . _ , _ .
ACCOUNT 241 Switchgear ACCOUNT 242 Station Service Equipment ACCOUNT 245 Electric Structures and Wiring Containers ACCOUNT 246 Power and Control Wiring - The electrical distribution system is modified to support the changes to the precipitator, flue gas desulfurization system, and main cooling towers (refer to Accounts 222, 226 and 262). s ACCOUNT 262 Main Condenser Heat Rejection System / Mechanical Equipment The design of the main cooling towers is modified to reflect current vendor. capabilities and practice. 5 I 5-19
5.4.2.9 EEDB Model Number C3, Model Type LS12. EEDB Third (1980) Update Base Data Study: Commercial Electric Power Cost Studies - Capital Cost - High and Low Sulfur Coal Plants - 1200 MWe (Nominal) (NUREG-0243, C00-2477-7) ACCOUNT 220A Fossil Steam Supply System The fossil steam supply system package is reviewed for conformance with current manufacturers' quotations. No significant technical changes are required. ACCOUNT 222 Draft System i The flue gas ductwork arrangement is modified and the induced draft (I.D.) fan is upgraded to accommodate the addition of the baghouse and dry flue gas desulfurization system (refer to Account 226). ACCOUNT 223 Ash and Dust Handling System l The fly ash system is modified to accommodate the increased number of pick-up points and dust loading associated with the dry flue gas desulfurization system (refer to Account 226). ACCOUNT 225 Flue Cas Desulfurization Structures The following structures associated with the baghouse and dry flue gas desulfurization system are added (refer to Account 226): e Lime unloading building e Lime preparation building e Spray dryer supports and enclosures e Baghouse supports and enclosures e Waste product disposal and recycling st ructures. 5-20
i ACCOUNT 226 Flue Gas Desulfurization System I A flue gas desulfurization system is added to comply with the 1979 New Source Performance Standards (NSPS) sulfur dioxide (50 ) limit f 0.06 pounds 2 per million Btu heat input with SO rem 2 val between 70% and 90%. The system is designed on the dry absorption principle, where lime slurry is injected into spray dryer absorbers. The S0 in2 the flue gas is absorbed by the lime slurry forming a pcwdery waste material which falls into the bottom of the spray dryer. Fly ash and other particulates carried over are collected in a baghouse which provides particulate removal in compliance with the 1979 New Source Performance Standards (NSPS) limit of 0.03 pounds per million Btu heat input. (The bag-house replaces the electrostatic precipitator previously used.) Part of the SO rem Val process also takes place in the baghouse. 2 The flue gas desulfurization system consists of the following major subsystems: e Dry Lime Handling Pebble lime is received from bottom-dump rail cars into receiving hoppers. From the hoppers, it is conveyed to the storage silos and eventually to the lime preparation building. All transfer areas are equipped with fabric filters to collect fugitive dust. e Lime Slaking Pebble lime is slaked in the lime preparation buildings in closed loop ball mill spiral classifier circuits. Lime is fed by weigh belt feeders into the ball mills which are supplied with the required amount of water for slaking. The slurry is latter transferred to the slurry feed tanks that supply the spray dryer absorbers. 5-21 ; I i
e Spray Dryer Absorbing The flue gas is introduced into each spray dryer absorber through a roof and a central gas disperser. A rotary atomizer placed in the center of the roof gas dispenser atomizes the lime slurry into fine droplets, providing an extremely large surface area for reaction with the incoming flue gas.
- e Particle Collection i
A portion of the fly ash and the reacted and unreacted reagent is collected in the bottom of the spra'y dryer absorbers. The main particulate control, however, is provided by the fabric l filter baghouse. The fabrid filter is properly sectionalized in order to assure suitable isolation capability. l e Ash Handling Fly ash from the baghouse hoppers is collected by a pneumatic conveying system and transferred into the ash disposal silos. A portion of the fly ash is transferred into the surge bin at the slaking / slurry preparation area for recycling. e Waste Disposal The waste product from the ash disposal silo is conveyed to the i waste surge silo, which is located in a designated on-site area. The material is metered from the waste surge sito into a mixer. Water is then added to the mixer in proportion to the solids to i achieve a damp, dustless blend. The mixer then discharges to a truck for the haul to the disposal area. 5-22 i
.__ - . . . - ~_
' ACCOUNT 241 Switchgear ACCOUNT 242 Station Service Equipment ACCOUNT 245 Electric Structures and~ Wiring Containers 2 ACCOUNT 246 Power and Control Wiring The electrical distribution system is modified to support the addition of the baghouse and the dry flue gas desulfurization system, the elimination of the precipitator, and the changes to the main cooling towers (refer to Accounts
; 222, 226 and 262),
ACCOUNT 262 Main Condenser Heat Rejection System / Mechanical Equipment The design of the main cooling towers is modified to reflect current vendor capabilities and practice. l 4 .i i 5-23
l 5.4.2.10 EEDB Model Number C4, Model Type LS8, EEDB Third (1980) Update i Base Data Study: Commercial Electric Power Cost Studies - Capital Cost - Low and High Sulfur Coal Plants - 800 MWe (Nominal) (NUREG-02'44, C00-2477-8) ACCOUNT 220A Fossil Steam Supply Syltem The fossil steam supply system package is reviewed for conformance with cur-rent manufacturers' quotations. No significant technical changes are required. ACCOUNT 222 Draft System The flue gas ductwork arrangement is modified and the induced draf t (I.D.) fan is upgraded to accommodate the addition of the baghouse and dry flue gas desulfurization system (refer to Account 226).
/ ACCOUNT 223 Ash and Dust Handling System The fly ash system is modified to accommodate the increased number of pick-up points and dust loading associated with the dry flue gas desulfurization system (refer to Account 226).
ACCOUNT 225 Flue Gas Desulfurization Structures The following structures associated with the baghouse and dry flue gas de-sulfurization system are added (refer to Account 226): e time unloading building e Lime preparation building e Spray dryer supports and enclosures i l e Baghouse supports and enclosures l e k'aste product disposal and recycling structures. i k 5-24
-- --.. - ,...,....,,_ ,-- , ._ , --,... ,_m. - . . . , - . _ . . - , . _ , . , _._ . - - - . _ _ - - - _ - . _ - . , . . - - , -
h ACCOUNT 226 Flue Gas Desulfurization System A flue gas desulfurization system is added to comply with the 1979 New Source Performance Standards (NSPS) sulfur dioxide (S0 2
) limit f 0.06 pounds per million Btu heat input with S0 rem val between 70% and 90%.
2 The system is designed on the dry absorption principle, where lime slurry is injected into spray dryer absorbers. The SO in the flue gas is absorbed 2 , by the lime slurry forming a powdery waste material which falls into the bottom of the spray dryer. Fly ash and other particulates carried over are collected in a baghouse which provides particulate removal in compliance with the 1979 New Source Performance Standards (NSPS) limit of 0.03 pounds per million Btu heat input. (The baghouse replaces the electrostatic precipitator previously used.) Part of the 50 2 removal process also takes place in the baghouse. The flue gas desulfurization system consists of the following major subsystems: e Dry Lime Handling Pebble lime is received from bottom-dump rail cars into receiving hoppers. From the hoppers, it is conveyed to the storage silos and eventually to the lime preparation building. All transfer areas are equipped with fabric filters to collect fugitive dust. e time Slaking Pebble lime is slaked in the lime preparation buildings in closed loop ball mill spiral classificr circuits. Lime is fed by weigh belt feeders into the ball mills which are supplied with the required amount of water for slaking. Th'e slurry is later transferred to the slurry feed tanks that supply the spray dryer absorbers. 5-25
e Spray Dryer Abosrbing The flue gas is introduced into each spray dryer absorber through a roof and a central gas disperser. A rotary atomizer placed in the center of the roof gas dispenser atomizes the lime slurry into fine droplets, providing an extremely large surface area for reaction with the incoming flue gas. e Particle Collection A portion of the fly ash and the reacted and unreacted reagent is collected in the bottom of the spray dryer abosrbers. The main particulate control, however, is provided by the fabric filter baghouse. The fabric filter is properly sectionalized in
/ order to assure suitable isolation capability, e Ash Handling Fly ash from the baghouse hoppers is collected by a pneumatic conveying system and transferred into the ash disposal silos.
A portion of the fly ash is transferred into the ash disposal silos. A portion of the fly ash is transferred into the surge bin at the slaking / slurry preparation area for recycling. l l e Waste Disposal The waste product from the ash disposal silo is conveyed to the waste surge silo, which is ' located in a designated on-site area. The material is metered from the waste surge silo into a mixer. Water is then added t'o the mixer in proportion to the solids to achieve a damp, dustlers blend. The mixer then discharges to a truck for the haul to the disposal area. 5-26
ACCOLHT 241 Switchgear ACCOUNT 242 Station Service Equipment ACCOUNT 245 Electric Structures and Wiring Container ACCOUNT 246 Power and Control Wiring The electrical distribution system is modified to support the addition of the baghouse and the dry flue gas desulfurization system, the elimination of the precipitator, and the changes to the main cooling towers (refer to Accounts 222, 226 and 262). ACCOUNT 262 Main Condenser Heat Rejection System / Mechanical Equipment ' The design of the main cooling towers is modified to reflect current vendor capabilities and practice. O I I 5-27
1 5.4.2.11 EEDB Model Number Dl, Model Type CGCC, EEDB Third (1980) Update Base Data Study: Study of Electric Plant Applications For Low Btu Gasification of Coal For Electric Power Generation (FE-1545-59) Minor modifications are made in the Third Update to bring the CGCC in closer conformance to the EEDB Groundrules. , I t 4 f i l I I l 5-28 I i
. , _ - - . . . _ . - . _ _ , _ _ _ . _ __._ . ~ _ _ _ _ _ , _ _ . _ _ _ . ~ - . _ _ _ _ . , , . . _ _ , _ , , , _ . . _ . _ _ _ , , _ _ . _ - _ _ _ _ _ _ _ _ _ . _ _ __,
6 O APPENDIX - D PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY ECONOMIC DATA BASE (EEDB) PROGRAM e
Effective Date - 1/1/81 APPENDIX D U.S. NUCLEAR REGULATORY COMMISSION REGULATORY GUIDE REVIEU This list shows the revision of Regulatory Guides in effect on January 1976, January 1980, and January 1981. Each guide is noted as follows: 0 - revision 0, or original issue 1, 2 or N - revision in effect NI - not issued. A column entitled, " Relates To," shows: D - related to design and/or licensing C - related to construction
/ 0 - related to operation NA - not applicable to nuclear power reactors C1 - Regulatory Guide revision has a significant cost impact.
D-1
REGULATORY GUIDES Division 1 Regul'atory Guides Power Reactors Revision in Relates
- Effect to Number Title 1/76 1/80 1/31.
1.1 Net Positive Suction Fead for Emergency 0 0 0 D Core Cooling and Containment Heat Removal System Pumps - 1.2 Thermal Shock to Reactor Pressure Vessels 0 0 0 D 1.3 Assumptions Used for Evaluating the Poten- 2 2 2 D tial Radiological Consequence of a Loss of Coolant Accident for Boiling Water Reactors 1.4 Assumptions Used for Evaluating the 2 2 2 D Potential Radiological Consequences of a Loss of Coolant Accident for Pressurized Water Reactors 1.5 Assumptions Used for Evaluating the 0 0 0 D Potential Radiological Consequences of a Steam Line Break Accident for Boiling Water Reactors 1.6 Independence Between Redundant Standby 0 0 0 D (Onsite) Power Sources and Between , Their Distribution Systems 1.7 Control of Combustible Gas Concentrations 0 2 2 D in Containment Following a Loss of Coolant Accident Supplement to Safety Guide 7, Back- 0 0 0 D fitting Considerations 1.8 Personnel Selection and Training 1 1 1 O 1.9 Selection of Diesel Generator Set 0 2 2 D Capacity for Standby Power Supplies 1.10 Mechanical (Cadweld) Splices in Rein- 1 1 1 D forcing Bars of Category I Concrete Structures 1.11 Instrument Lines Penetrating Primary 0 0 0 D Reactor Containment Supplement to Safety Guide 11, Back- 0 0 0 D fitting Considerations
- Refer to page D-1 ;- 2
l Revision in Relates
- Effect to Number Title ,
1/76 1/80 1/81 1.12 Instrumentation for Earthquakes 1 1 1 D l 1.13 Spent Fuel Storage Facility Design Basis 1 1 1 D l l 1.14 Reactor Coolant Pump Flywheel Integrity 1 1 1 D 1.15 Testing of Reinforcing Bars for Category I Concrete Structures 1 1 1 C 1.16 Reporting of Operating Information - 4 4 4 0 Appendix A Technical Specifications 1.17 Protection of Nuclear Plants Against 1 1 1 D, O (CI) Industrial Sabotage 1.18 Structural Acceptance Test for Concrete 1 1 1 C Primary Reactor Containments 1:19 Nondestructive Examination of Primary 1 1 1 C Containment Liner Welds 1.20 Comprehensive Vibration Assessment Pro- 1 2 2 0 gram for Reactor Internals During Pre-operational and Initial Startup Testing 1.21 Measuring, Evaluating, and Reporting 1 1 1 0 Radioactivity in Solid Wastes and Re-leases of Radioactivity in Liquid and Gaseous Ef fluents from Light Water Nuclear Power Plants 1.22 Periodic Testing of Protection System 0 0 0 0 Actuation Functions 0 0 0 0 1.23 Onsite Meteorological Programs 1.24 Assumptions Used for Evaluating the 0 0 0 D Potential Radiological Consequences of a Pressurized Water Reactor Gas Storage Tank Failure 1.25 Assu=ptionc Used for Evaluating the Po- 0 0 0 D tential Radiological Consequences of a Fuel Handling Accident in the Fuel Handling and Storage Facility for Boil-ing and Pressurized Water Reactors 0-3
Revision in Relates
- Effect to -
Number Title 1/76 1/80 1/81 1.26 Quality Group Classifications and 2 3 3 D Standards for Water , Steam- and Radio-Waste-Containing Components of Nuclear Power Plants 1.27 Ultimate Heat Sink for Nuclear Power 1 2 2 D Plants 1.28 Quality Assurance Program Requirements 0 2 2 D, C (Design and Construction) 1.29 Seismic Design Classification 1 3 3 D 1.30 Quality Assurance Requirements for the 0 0 0 C Installation, Inspection, and Testing of Instrumentation and Electric Equipment 1.31 Control of Ferrite Content in Stainless 1 3 3 C Steel Weld Metal 1.32 Criteria for Safety-Related Electric 1 2 2 D Power Systems for Nuclear Power Plants 1.33 Quality Assurance Program Requirements 0 2 2 0 (Operation) 1.34 Control of Electroslag Weld Properties 0 0 0 C 1.35 Inservice Inspection of Ungrouted 2 2 2 C Tendons in Prestressed Concrete Containment Structures 1.36 Nonmetallic Thermal Insulation for 0 0 0 D Austenitic Stainless Steel 1.J7 Quality Assurance Requirements for 0 0 0 C Cleaning of Fluid Systems and Associated Components of Water-Cooled Nuclear Power Plants 1.38 Quality Assurance Requirements for 1 2 2 C Packaging, Shipping, Receiving, Storage, and Handling of Items for Water-Cooled Nuclear Power Plants 1.39 Housekeeping Requirements for Water- 1 2 2 C, O Cooled Nuclear Power Plants
.4
Fevision in Relates
- Effect to Number Title 1/76 ILgD 1/81 1.40 Qualification Tests of Continuous-Duty 0 0 0 D Motors Installed Inside the Containment of Water-Cooled Nuclear Power Plants 1.41 Preoperational Testing of Redundant 0 0 0 C Onsite Electric Power Syste=s to Verify Proper Load Group Assignments 1.42 Interim Licensing Policy on As-Low-As- 0 (With- - -
Practicable for Gaseous Radio-Iodine drawn Releases from Light-Water-Cooled Nuclear 3/22/76) Power Reactors 1.43 Control of Stainless Steel Weld Cladding 0 0 0 C of Low-Alloy Steel Components 1.44 Control of the Use of Sensitized 0 0 0 C Stainless Steel 1.45 Reactor Coolant Pressure Boundary Leakage 0 0 0 D Detection Systems 1.46 Protection Against Pipe Whip Inside 0 0 0 D Containment 1.47 Bypassed and Inoperable Status Indica- 0 0 0 D, O tion for Nuclear Power Plant Safety Systems 1.48 Design Limits and Loading Combinations 0 0 0 D for Seismic Category I Fluid System Components 1.49 Power Levels of Nuclear Power Plants 1 1 1 D 1.50 Control of Preheat Temperature for Weld- 0 0 0 C ing of Low-Alloy Steel 1.51 Inservice Inspection of ASME Code Class (Withdrawn - - 2 and 3 Nuclear Power Plant Components 7/21/75) 1.52 Design, Testing, and Maintenance Cri- NI 2 2 D, O teria for Engineered-Safety-Feature Atmosphere Cleanup System Air Filtra-tion and Adsorption Units of Light-Water-Cooled Nuclear Power Plants 1.53 Application of the Single-Failure Cri- 0 0 0 D terion to Nuclear Power Plant Protection Systems D .t
Revision in Relates
- Effect to Numbe r Title 1/76 1/80 1/81 1.54 Quality Assurance Requirements for Pro- 0 0 0 D, C tective Coatings Applied to Water-Cooled Nuclear Power Plants 1.55 Concrete Placement in Category I Structures 0 0 0 C 1.56' Maintenance of Water Purity in Boiling 0 1 1 O Water Reactors 1.57 Design Limits and Loading Combinations 0 0 0 D for Metal Primary Reactor Containment System Components 1.58 Qualification of Nuclear Power Plant 0 0 1 C Inspection, Examination, and Testing Personnel 1.59 Disign Basis Floods for Nuclear Power 1 2 2# D Plants 1.60 Design Response Spectra for Seismic 1 1 1 D Design of Nuclear Power Plants 1.61 Damping Values for Seismic Design of 0 0 0 D Nuclear Power Plants 1.62 Manual Initiation of Protective Actions 0 0 0 D, 0 1.63 Electric Penetration Assembles in 0 2 2 D Containment Structures for Light-Water-Cooled Nuclear Power Plants 1.64 quality Assurance Requirements for the 1 2 2 D Design of Nuclear Power Plants 1.65 Materials and Inspection for Reactor 0 0 0 D, C, O Vessel Closure Studs 1.66 Nondestructive Examination of Tubular 0 (Withdrawn - -
Products 10/6/77) 1.67 Installation of Overpressure Protective 0 0 0 D, C Devices 1.68 Initial Test Programs for Water-cooled 0 2 2 C, O Reactor Power Plants 1.68.1 Preoperational and Initial Startup Test- NI 1 1 C, O ing of Feedwater and Condensate Systems for Boiling Water Reactor Power Plants E Errata Issued 7-6
P.evisi.on in Relates
- Effect to Number Title 1/76 1/80 1/81 1.68.2 Initial Startup Test Program to Demon- NI L 1 C, O strate Remote Shutdown Capability for Water-Cooled Nuclear Power Plants 1.69 Concrete Radiation Shields for Nuclear 0 0 0 D Power Plants 1.70 Standard Format and Content of Safety 2 3 3 D Analysis Reports for Nuclear Power Plants-LWR Edition 1.71 Welder Qualification for Areas of Limited 0 0 0 C Accessibility 1.72 Spray Pond Piping Made from Fibe.rglass- 0 2 2 D Reinforced Thermosetting Resin 1.73 Qualification Tests of Electric Valve 0 0 0 C Operators Installed Inside the Con-tainment of Nuclear Power Plants 1.74 Quality Assurance Terms and Definitions 0 0 0 D, C, 0 1.75 Physical Independence of Electric Systems 1 2 2 D 1.76 Design Basis Tornado for Nuclear 0 0 0 D Power Plants 1.77 Assumptions Used for Evaluating a 0 0 0 D Control Rod Ejection Accident for Pressurized Water Reactors 1.78 Assu=ptions for Evaluating the Habit- 0 0 0 D ability of a Nuclear Power Plant Control Room During a Postulated Hazardous Chemical Release 1.79 Preoperational Testing of Emergency Core 1 1 1 C, O Cooling Systems for Pressurized Water Reactors -
1.80 Preoperational Testing of Instrument Air 0 0 0 C, O Systems 1.81 Shared Emergency and Shutdown Electric 1 1 1 D Systems for Multi-Unit Plants 1.82 Sumps for Emergency Core Cooling and 0 0 0 D Containment Spray Syste=s D-1
I Revision in Relates
- Effect to Number Title 1/76 LLg1 1231 1.83 Inservice Inspection cf Pressurized Water 1 1 1 0 Reactor Steam Generator Tubes 1.84 Code Case Acceptability - ASME Section III 8 16 17 D, C, O Design and Fabrication ,
1.85 Code Case Acceptability - ASME Section III 8 16 17 D, C, O Materials 1.86 Termination of Operating Licenses for 0 0 0 0 Nuclear Reactors 1.87 Guidance for Construction of Class 1 1 1 1 D Components in Elevated-Temperature Reactors (Supplement to ASME Section III Code Classes 1592, 1593, 1594, 1595 and 1596) 1.88 Collection, Storage, and Maintenance of 1 2 2 D, C, 0 ! Nuclear Power Plant Quality
/ Assurance Records 1.89 Qualification of Class lE Equipment 0 0 0 D, C for Nuclear Power Plants 1.90 Inservice inspection of Prestressed 0 1 1 D, C, O Concrete Containment Structures with Grouted Tendons 1.91 Evaluation of Explosions Postulated to 0 1 1 D Occur en Transportation Routes Near Nuclear Power Plant Sites 1.92 Combining Modal Responses and Spatial 0 1 1 D Components in Seismic Response Analysis 1.93 Availability of Electric Power Sources 0 0 0 D 1.94 Quality Assurance Requirements for 0 1 1 C Installation, Inspection, and Test-ing of Structural Concrete and Structural Steel,During the Con-struction Phase of Nuclear Power Plants 1.95 Protection of Nuclear Power Plant Control 0 1 1 D Room Operators Against an Accidental Chlorine Release D-e
Revision in Relates
- Effect to Mu=ber Title 1/76 1L10 LLEL 1.96 Design of Main Steam Isolation Valve 0 1 1 D Leakage Control Systems for Boil-ing Water Reactor Nuclear Power Plants ,
1.97 Instrumentation for Light-Water-Cooled 0 1 2 D, O Nuclear Power Plants to Assess Plant Conditions During and Following an Accident 1.98 Assumptions Used for Evaluating the Po- NI O O D l tential Radiological Consequences of a Radioactive Offgas System Failure in a Boiling Water Reactor 1.99 Effects of Residual Elements on Predicted 0 1 1 D Radiation Damage to Reactor Vessel Materials 1.100 Seismic Qualification of Electric Equip- 0 1 1 D, C ment for Nuclear Power Plants 1.101 Emergency Planning for Nuclear Power 0 1 (Withdrawn - Plants 9/24/80) 1.102 Flood Protection for Nuclear Power Plants 0 1 1 D 1.103 Post-Tensioned Prestressing Systems for 0 1 1 D Concrete Reactor Vessels and Containments 1.104 Overhead Crane Handling Systems for NI (Withdrawn - - Nuclear Power Plants 8/16/79) 1.105 Instrument Setpoints 0 1 1 D, 0 1.106 Thermal Overload Protection for Electric 0 1 1 D Motors on Motor-Operated Valves 1.107 Qualifications for Cement Grouting for 0 1 1 C Prestressing Tendons in Containment Structures 1.108 Periodic Testing of Diesel Generator .0 1 1 0 Units Used as Onsite Electric Power Systems at Nuclear Power Plants 1.109 Calculation of Annual Doses to Man from NI 1 1 D Routine Releases of Reactor Effluents for the Purpose of Evaluating Com-pliance with 10 CFR Part 50, Appendix I D-9
1 Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 1.110 Cost-Benefit Analysis for Radwaste NI O O D Systems for Light-Water-Cooled Nuclear Power Reactors 1.111 Methods for Estimating Atmospheric Trans- NI 1 1 D, 0 port and Dispersion of Gaseous Effluents in Routine Releases from Light-Water-Cooled Reactors 1.112 Calculation of Releases of Radioactive NI O O D, O Materials in Gaseous and Liquid Effluents from Light-Water-Cooled Power Reactors 1.113 Estimating Aquatic Dispersion of NI 1 1 D, O Effluents from Accidental and Routine '
Reactor Releases for the Purpose of Implementing Appendix I 1.114 buidance on Being Operator at the Controls NI 1 1 0 of a Nuclear Power Plant 1.115 Protection Against Low-Trajectory NI 1 1 D Turbine Missiles 1.116 Quality Assurance Requirements for In- NI O O C stallation, Inspection, and Testing of Mechanical Equipment and Systems 1.117 Tornado Design Classification NI 1 1 D 1.118 Periodic Testing of Electric Poser and NI 2 2 0 Protective Systems 1.119 Surveillance Program for New Fuel NI (Withdrawn - - Assembly Designs 6/20/77) 1.120 Fire Protection Guidelines for Nuclear NI 1 1 D(CI) Power Plants 1.121 Bases for Plugging Degraded PWR Steam NI O O C Generator Tubes 1.122 Development of Floor Design Response NI 1 1 D' Spectra for Seismic Design of Floor-Supported Equipment or Components 1.123 Quality Assurance Requirements for Con- NI 1 1 D, C trol of Procurement of Items and Services for Nuclear Power Plants L-lO
Revision in Relates
- Effect to Number Title 1/76 1/80 1131 1.124 Service Limits and Loading Combinations NI 1 1 D for Class 1 Linear Type Component Supports 1.125 Physical Models for Design and Operation NI 1 1 D s of Hydraulic Structures and Systems for Nuclear Power Plants 1.126 An Acceptable Model and Related Statis- NI 1 1 0 tical Methods for the Analysis of Fuel Densification 1.127 Inspection of Water Control Structures NI 1 1 C, O Associated with Nuclear Power Plants 1.128 Installation Design and Installation of NI 1 1 D, C(CI)
Large Lead Storage Batteries for Nuclear Power Plants 1.129 Maintenance, Testing, and Replacement of NI 1 1 0 Large Lead Storage Batteries for Nuclear Pever Plants 1.130 Design Limits and Loading Combinations NI 1 1 D for Class 1 Plate-and-Shell-Type Component Supports 1.131 Qualification Tests of Electric Cables, NI O O C Field Splices, and Connections for Light-Water-Cooled Nuclear Power Plan ts 1.132 Site Investigations for Foundations of NI 1 1 D Nuclear Power Plants 1.133 Loose-Part Detection Program for the NI O O D, C, O Primary System of Light-Water-Cooled Reactors 1.134 Medical Certification and Monitoring of NI 1 1 0 Personnel Requiring Operator Licenses 1.135 Normal Water Level and Discharge at NI O O O Nuclear Power Plants 1.136 Material for Concrete Contain=ents NI 1 1 C 1.137 Fuel-011 Systems for Standby Diesel NI 1 1 D I Generators i D-11
Revision in Relates *
. Effect to Numbe r Title 1/76 1/80 ladLL 1.138 Laboratory Investigations of Soils NI O O D for Engineering Analysis and Design l of Nuclear Power Plants 1.139 Guidance for Residual Heat Removal NI O O D 4 1.140 Design, Testing and Maintenance NI 1 1 D Criteria for Normal Ventilation Exhaust System, Air Filtration and Absorption Units of Light-Water-Cooled Nuclear Power Plants 1.141 Containment Isolation Provisions NI O O D for Fluid Systems 1.142 Safety-Related Concrete Structures NI O O D for Nuclear Power Plants (Other than Reactor Vessels and Containments) 4 1.143 Design Guidance for R'adioactive NI 1 1 D f
Waste Management Systems, Structures, and Components Installed in Light-Water-Cooled Nuclear Power Plants 1.144 Auditing of Quality Assurance NI 0- 1 D Programs for Nuclear Power Plants 1.145 Atmospheric Dispersion Models NI O O D for Potential Accident Consequence Assessments at Nuclear Power Plants 1.146 Qualification of Quality Assurance NI NI O D Program Audit Personnel for Nuclear Power Plants l D-12
REGULATORY GUIDES
. Division 2 Regulatory Guides Research and Test Reactors Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 2.1 Shield Test Program for Evaluation of 0 0 0 NA Installed Biological Shielding in Research and Training Reactors 2.2 Development of Technical Specifications 0 0 0 NA for Experiments in Research Rgaetors 2.3 Quality Verification for Plate-Type 0 1 1 NA Uranium-Aluminum Fuel Elements for Use in Research Reactors ,
2.4 Review of Experiments for Research NI O O NA Reactors s 2.5 Quality Assurance Program Requirements NI O O NA for Research Reactors 2.6 Emergency Planning for Research Reactors NI O O NA
- Refer to page D-1 2-13
REGULATORY GUIDES Division 3 Regulatory Guides Fuels and Materials Facilities Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 3.1 Use of Borosilicate-Class Rashig Rings as 0 0 0 NA a Neutron Absorber in Solutions of Fissile Material 3.2 Efficiency Testing of Air-Cleaning Systems 0 0 0 NA Containing Devices for Removal of Particles 3.3 Quality Assurance Program Requirements 1 1 1 NA for Fuel Reprocessing Plants and for Plutonium Processing and Fuel Fabrication Plants 3.4 Nuclear Criticality in Safety Operations 0 1 1 NA with Fissionable Materials Outside Reactors 3.5 Standard Format and Content of License 0 1 1 NA Applications for Uranium Mills 3.6 Guide to Content of Technical Specifica- 0 0 0 NA tions for Fuel Reprocessing Plants 3.7 Monitoring of Combustible Cases and 0 0 0 NA Vapors in Plutonium Processing and Fuel Fabrication Plants 3.8 Preparation of Environmental Reports for 0 1 1 NA Uranium Fdlls 3.9 Concrete Radiation Shields 0 0 0 NA 3.10 Liquid Waste Treatment System Design 0 0 0 NA Guide for Ph:tonium Processing and Fuel Fabrication Plants 3.11 Design, Construction, and Inspection 1 2 2 NA of Embankment Retention Systems for Uranium Mills 3.12 General Design Guide for Ventilation 0 0 0 NA Systems of Plutonium Processing and Fuel Fabrication Plants 3.13 Guide for Acceptable Waste Storage 0 0 0 NA Methods at L76 Production Plants
- Refer to pagep-l g_y;
~
Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 3.14 Seismic Design Classification for 0 0 0 NA Plutonium Processing and Fuel Fabrication Plants 3.15 Standard Format and Content of License 0 0 0 NA Applications for Storage Only of Unirradiated Reactor Fuel and Associated Radioactive Material 3.16 General Fire Protection Guide for 0 0 0 NA Plutonium Processing and Fuel Fabrication Plants 3.17 Earthquake Instrumentation for Fuel 0 0 0 NA Reprocessing Plants 3.18 Confinement Barriers and Systems for Fuel 0 0 0 NA Reprocessing Plants 3.19 Reporting of Operating Information for 0 0 0 NA Fuel Reprocessing Plants 3.20 Process Offgas Systems for Fuel 0 0 0 EA Reprocessing Plants 3.21 Quality Assurance Requirements for Pro- 0 0 0 NA tective Coatings Applied to Fuel Re-processing Plants and to Plutonium Processing and Fuel Fabrication Plants 3.22 Periodic Testing of Fuel Reprocessing 0 0 (Uithdrawn -
Plant Protection System Actuation 10/21/80) Functions 3.23 Stabilization of Uranium-Thorium Milling 0 0 0 NA Waste Retention Systems 3.24 Guidance on the License Application, 0 0 0 NA Siting, Design, and Plant Protection for an Independent Spent Fuel Storage Installation 3.25 Standard Format and Content of Safety 0 0 0 NA Analysis Reports for Uranium Enrich-ment Facilities 3.26 Standard Format and Content of Safety 0 0 0 NA Analysis Reports for Fuel Reprocessing Plants 7-15
Revision in Relates
- Effect to Nu=ber Title 1/76 1/80 1/81 3.27 Nondestructive Examination of Welds 0 1 1 NA .
3 in the Liners of Concrete Barriers in Fuel Reprocessing Plants 3.28 Welder Qualification for Welding in 0 0 0 NA Areas of Limited Accessibility in Fuel Reprocessing Plants in Plutonium Processing and Fuel Fabrication Plants 3.29 Preheat and Interpass Temperature Control 0 0 0 NA for the Welding of Low-Alloy Steel for Use in Fuel Reprocessing Plants and in Plutonium Processing and Fuel Fabrication Plants 3.30 Selection, Application, and Inspection 0 0 0 NA of Protective Coatings (Paints) for Fuel Reprocessing Plants 3.31 Emergency Water Supply Systems for Fuel 0 0 0 NA Reprocessing Plants 3.32 General Design Guide for Ventilation 0 0 0 NA Systems for Fuel Reprocessing Plants 3.33 Assumptions Used for Evaluating the NI O O NA Potential Radiological Consequences of Accidental Nuclear Criticality in a Fuel Reprocessing Plant 3.34 Assumptions Used for Evaluating the NI 1 1 NA Potential Radiological Consequences of Accidental Nuclear Criticality in a Uranium Fuel Fabrication Plant 3.35 Assumptions Used for Evaluating the NI 1 1 NA Potential Radiological Consequences of Accidental Nuclear Criticality in a Plutonium Processing and Fuel Fabrication Plant 3.36 Nondestructive Examination of Tubular 0 (Withdrawn - - Products for Use in Fuel Reprocessing 1/24/79) ' Plants and in Plutonium Processing and Fuel Fabrication Plants 3.37 Guidance for Avoiding Intergranular Cor- 0 0 0 NA rosion and Stress Corrosion in Aus- , tenitic Stainless Steel Components of Fuel Reprocessing Plants D-16
Rsvision in Ralstas* Effect to Nu=ber Title 1/76 1/80 if81 3.38 General File Protection Guide for Fuel NI O O NA Reprocessing Plants , 3.39 Standard Format and Content of License 0 0 0 NA Applications for Plutonium Processing and Fuel Fabrication Plants 3.40 Design Basis Floods for Fuel Reprocessing NI 1 1 NA Plants and for Plutonium Processing and Fuel Fabrication Plants 3.41 Validation of Calculational Methods NI 1 1 NA for Nuclear Criticality Safety 3.42 Emergency Planning for Fuel Cycle NI 1 1 NA Facilities and Plants Licensed , Under 10 CFR Parts 50 and 70 3.43 Nuclear Criticality Safety in the NI 1 1 NA Storage of Fissile Materials 3.44 Standard Format and Content for the NI i 1 NA Safety Analysis Report to be Included in a License Application for the Storage of Spent Fuel 3.45 Nuclear Criticality Safety for Pipe NI NI O NA Intersections Containing Aqueous Solutions of Enriched Uranyl Nitrate D-17
REGULATORY GUIDES Division 4 Regulatory Guides Environmental and Siting Guides Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 4.1 Programs for Monitoring Radioactivity 0 1 1 0 in the Environs of Nuclear Power Plants 4.2 Preparation of Environmental Reports for 1 2 2 D Nuclear Power Stations 4.3 Measurements of Radionuclides in the 0 04thdrawn - -
Environment-Analysis of I-131 in Milk 12/9/76) 4.4 Reporting Procedures for Mathematical 0 0 0 0 Models Selected to Predict Heated Effluent Dispersion in Natural Water Bodies 4.5 Measurements of Radionuclides in the 0 0 0 0 Environment-Sampling and Analysis of Plutonium in Soil 4.6 Measurements of Radionuclides in the 0 0 0 0 Environment-Strontium-89 and Strontium-90 Analysis 4.7 General Site Suitability Criteria for 1 1 1 D Nuclear Power Stations 4.8 Environmental Technical Specifications 0 0 0 0 for Nuclear Power Plants 4.9 Preparation of Environmental Reports for 1 1 1 NA Commercial Uranium Enrichment Facilities 4.10 Irreversible and Irretrievable Commitments 0 (Withdrawn - - of Material Resources 11/17/77) 4.11 Terrestrial Environmental Studies for 0 1 1 D Nuclear Power Stations 4.13 Performance, Testing, and Procedural NI 1 1 0 Specifications for Thermoluminescence Dosimetry: Environmental Applications 4.14 Measuring, Evaluating, and Reporting NI O 1 0 Radioactivity in Releases of Radio-active Materials in Liquids and Air-borne Effluents fron Uranium Mills
- Refer to page D-1 D-18
Revision in Relates
- Effect to Numbe r Title 1/76 1/80 1/81 4.15 Quality Assurance for Radiological Moni- NI 1 1 0 toring Programs (Normal Operations) - s Effluent Streams and the Environment 4.16 Measuring, Evaluating and Reporting NI O O O Radioactivity in Releases of Radio-active Materials in Liquid and Air-borne Effluents from Nuclear Fuel Processing and Fabrication Plants 9
e n-39
l l l REGULATORY GUIDES Division 5 Regulatory Guides Materials and Plant Protection Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 5.1 Serial Numbering of Light-Water-Poser 0 0 0 0 Reactor Fuel Assemblies 5.2 Classification of Unirradiated 0 (Uithdrawn - -
Plutonium and Uranium Scrap 9/26/79) 5.3 Statistical Terminology and Notation 0 0 0 0 for Special Nuclear Materials Control Accountability 5.4 Standard Analytical Methods for the 0 0 0 NA Measurement of Uranium Tetrafluoride (UE4) and Uranium Hexafluoride (UF6) 5.5 Standard Methods for Chemical, Mass 0 0 0 NA Spectrometric, and Spectrochemical Analysis of Nuclear-Grade Uranium / Dioxide Powders and Pellets 5.6 Standard Methods for Chemical, Mass 0 0 0 NA Spectrochemical Analysis of Nuclear-Grade Plutonium Dioxide Powders and ; Pellets and Nuclear Grade Mixed Oxides (U, Pu, 02) 5.7 Control of Personnel Access to Protected 0 0 0 D, C, O(CI) Areas, Vital Areas, and Material 5.8 Design Considerations for Minimizing 1 1 1 NA Residual Holdup of Special Nuclear Material in Drying and Fluidized Bed Operations 5.9 Specifications of Ge(Li) Spectroscopy 1 1 1 NA Systems for Material Protection Meas-urements - Part I: Data Acquisition 5.10 Selection and Use of Pressure-Sensitive 0 0 0 0 Seals on Containers for Onsite Storage of Special Nuclear Materials 5.11 Nondestructive, Assay of Special Nuclear 0 0 0 NA Material Contained in Scrap and Waste
- Refer to page D-1 2-20
1 Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 5.12 General Use of Locks in the Protection 0 0 0 D, O and Control of Facilities and Special Nuclear Materials 5.13 Conduct of Nuclear Katerial Physical 0 0 0 0 Inventories 5.14 Visual Surveillance of Individuals in 0 0 1 0 Material Access Areas 5.15 Security Seals for the Protection and 0 0 0 0 Control of Special Nuclear Material 5.16 Standard Methods for Chemical, Mass 1 1 1 NA Spectrometric, Spectrochemical, Nuclear and Radiochemical Analysis of Nuclear-Grade Plutonium Nitrate Solutions and Plutonium Metal 5.17 Truck Identification Markings 0 0 0 0 5.18 Limit of Error Concepts and Principles 0 0 0 NA of Calculation in Nuclear Materials Control 5.19 Methods for the Accountability of 0 0 0 NA Plutonium Nitrate Solutions 5.20 Training, Equipping, and Qualifying of 0 0 0 0 Guards and Watchmen 5.21 Nondestructive Uranium-235 Enrichment 0 0 0 NA Assay by Gamma-Ray Spectrometry 5.22 Assessment of the Assumption of Normality 0 0 0 NA (Employing Individual Observed Values) 5.23 In-Situ Assay of Plutonium Residual Holdup 0 0 0 NA 5.24 Analysis and Use of Process Data for the 0 0 0 NA Protection of Special Nuclear Material in Equipment for Wet Process Operations 5.25 Design Considerations for Minimizing 0 0 0 NA i Residual Holdup of Special Nuclear Material in Equipment for Wet Process Operations 1 NA 5.26 Selection of Material Balance Areas and 1 1 Item Control Areas n-?1
Revision in Relates
- Effect to -
Number Title 1/76 1/80 1/81 5.27 SMM Doorway Monitors 0 0 0 D, 0 5.28 Evaluation of Shipper-Receiver 0 0 0 0 Differences in the Transfer of Special Nuclear Material 5.29 Nuclear Material Control Systems for 1 1 1 D, O Nuclear Power Plants 5.30 Materials Protection Contingency Measures 0 0 0 NA for Uranium and Plutonium Fuel Manufacturing Plants 5.31 Specially Designed Vehicle with Armed 1 1 1 0 Guards for Road Shipments of Special Nuclear Material 5.32 Communication with Transport Vehicles 1 1 1 0 5.33 Statistical Evaluation of Material 0 0 0 0 Unaccounted For 5.34 Nondestructive Assay of Plutonium in 0 0 0 NA Scrap by Spontaneous Fission Detection 5.35 Calorimetric Assay for Plutonium 0 (Withdrawn - - 8/18/77) 5.36 Recommended Practice for Dealing 0 0 0 NA With Outlying Observations 5.37 In-Situ Assay of Enriched Uranium 0 0 0 NA Residual Holdup 5.38 Nondestructive Assay of High-Enrichment 0 0 0 NA Uranium Fuel Plates by Gamma-Ray Spectromet ry 5.39 Ceneral Methods for the Analysis of 0 0 0 NA Uranyl Nitrate Solutions for Assay, Isotopic Distribution, and Impurity Determinations 5.40 Methods for the Accountability of 0 0 0 NA Plutonium Dioxide Powder 5.42 Design Considerations for Minimizing Re- 0 0 0 NA i sidual Holdup of Special Nuclear Material { in Equipment for Dry Process Operations l D-22
Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 5.43 Plant Security Force Duties 0 0 0 0 5.44 Perimeter Intrusion Alarm Systems 0 1 2 D, 0 5.45 Standard Format and Content for the 0 0 0 0 Special Nuclear Material Control and Accounting Section of a Special Nuclear Material License Application 5.47 Control and Accountability of Plutonium 0 0 0 NA in Waste Material 5.48 Design Considerations - Systems for 0 0 0 NA Measuring the Mass of Liquids 5.49 Internal Transfers of Special Nuclear 0 0 0 0 Material 5.51 Management Review of Nuclear Material 0 0 0 0 Control and Accounting Systems 5.52 Standard Format and Content for the NI l' 2 NA Physical Protection Section of a License Application (for Facilities Other than Nuclear Power Plants) 5.53 qualification, Calibration, and Error 0 0 0 NA Estimation Methods for Nondestructive Assay 5.54 Standard Format and Content of NI O O O Safeguards Contingency Plans for Nuclear Power Plants 5.55 Standard Format and Content of NI O O NA Safeguards Contingency Plans for Fuel Cycle Facilities 5.56 Standard Format and Content of NI O O NA Safeguards Contingency Plans for Transportation 5.57 Shipping and Receiving Control of NI O 1 0 Special Nuclesr Material 5.58 Considerations for Establishing Trace- NI O 1 o ability of Special Nuclear Materials Accounting Measurements D-23
I Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 5.59 Standard Format and Content for a NI NI O D, .0 Licensee Physical Security Plan for the Protection of Special Nuclear Material of Moderate or Low Strategic Significance 5.60 Standard Format and Content of a NI NI O O Licensee Physical Protection Plan for Strategic Special Nuclear Material in Transit 5.61 Intent and Scope of the Physical NI NI O O Protection Upgrade Rule Requirements for Fixed Sites 1
I l D-24
REGULATORY GUIDES Division 6 Regulatory Guides - Products Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 6.1 Leak Testing Radioactive Brachytherapy 1 1 1 NA Sources 6.2 Integrity and Test Specifications for 1 1 1 NA Selected Brachytherapy Sources 6.3 Design, Construction, and Use of Radio- 0 0 0 NA isotopic Power Generators for Certain Land and Sea Applications 6.4 Classification of Containment Properties 1 1 2 NA of Sealed Radioactive Sources Contained in Certain Devices to be Distributed for Use Under General License 6.5 General Safety Standard for Installations 0' O O NA Using Nonmedical Scaled Gamma-Ray Sources 6.6 Acceptance Sampling Procedures for 0 0 0 NA Exempted and Generally Licensed Items '
Containing Byproduct Material 6.7 Preparation to an Environmental Report to 0 1 1 NA Support a Rule Making Petition Seeking an Exemption for a Radionuclide-Containing Product 6.8 Identification Plaque for NI O O NA Irretrievable Well-Logging Sources
- Refer to page D-1 D-25
REGULATORY GUIDES Division 7 Regulatory Guides Transportation Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 7.1 Administrative Guide for Packaging and 0 0 0 0 Transporting Radioactive Material 7.2 Packaging and Transportation of Radio- 0 0 0 NA actively Contaminated Biological Materials 7.3 Procedures for Picking Up and Receiving 0 0 0 0 Packages of Radioactive Materials 7.4 Leakage Tests on Packages for Shipment 0 0 0 0 of Radioactive Materials 7.5 Administrative Guide for Obtaining 0 0 0 0 Exemptions from Certain NRC Require-ments over Radioactive Material
- Shipments 7.6 Stress Allowables for the Design of NI 1 1 D Shipping Cask Containment Vessels 7.7 Administrative Guide for Verifying Com- NI O O O pliance with Packaging Requirements for Shipments of Radioactive Materials 7.8 Load Combinations for the Structural NI O O D Analysis of Shipping Casks 7.9 Standard Format and Content of Part 71 NI O 1 0 Applications for Approval of Packaging of Type B, Large Quantity, and Fissile Radioactive Material
- Refer to page D-1 D-26
REGULATORY GUIDES Division 8 Regulatory Guides Occupational Health Revision in Relates
- Effect to Number Title 1/76 1/80 . 1/81 8.1 Radiation Symbol 0 0 0 0 8.2 Administrative Practices in Radiation 0 0 0 0 Monitoring 8.3 Film Badge Performance Criteria 0 0 0 0 8.4 Direct-Reading and Indirect-Reading 0 0 0 0 Pocket Dosimeters 8.5 Immediate Evacuation Signal 0 0 0 0 8.6 Standard Test Procedure for Geiger- 0 0 0 0 Muller Counters 8.7 Occupational Radiation Exposure Records 0 0 0 0 Systems
- 8. 8 Information Relevant to Ensuring that 1 3 3 D, 0 Occupational Radiation Exposures at Nuclear Power Stations will be as Low as is Reasonably Achievable 8.9 Acceptable Concepts, Models, Equations, 0 0 0 0 and Assumptions for a Bioassay Program 8.10 Operating Philosophy for Maintaining 1 1 1 0 Occupational Radiation Exposures as Low as is Reasonably Achievable (Nuclear Power Reactors) 8.11 Application of Bioassay for Uranium 0 0 0 0 8.12 Criticality Accident Alarm Systems 0 0 0 0 8.13 Instruction Concerning Prenatal 1 1 1 0 Radiation Exposure 8.14 Personnel Neutron Dosimeters 0 1 1 0 8.15 Acceptable Programs for Respiratory NI O O O Protection
- Refer to page D-1 D-27
l Revision in Relates
- Effect to Number Title 1/76 1/80_ [431, 8.18 Information Relevant to Ensuring that NI O O NA Occupational Radiation Exposures at Medical Institutions will be as Low as Reasonably Achievable 8.19 Occupational Radiation Dose Assessment NI l 1 D, O in Light-Water Reactor Power Plants Design Stage Man-Rem Estimates 8.20 Application of Bioassay for I-125 and NI 1 1 0 I-131 8.21 Health Physics Surveys for NI 1 1 0 By-Product Material at NRC-Licensed Processing and Manufacturing Plants 8.22 Bioassay at Uranium Mills NI O O NA 8.24 Health Physics Surveys During NI 1 1 NA Enriched Uranium-235 Processing and Fuel Fabrication s
8.25 Calibration and Error Limit of Air NI NI O O Sampling Instruments for Total Volume of Air Sampled 8.26 Application of Bioassay for Fission NI NI O O and Activation Products D-28
REGULATORY GUIDES Division 9 Regulatory Guides Antitrust Review Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 9.1 Regulatory Staff Position Statement on 0 0 0 D Antitrust Matters 9.2 Information Needed by the 2:RC Staff in 0 1 1 D Connection with its Antitrust Review of Construction Permit Applications for Nuclear Power Plants 9.3 Information Needed by the NRC Staff in 0 0 0 D Connection with its Antitrust Review of Operating License Applications for Nuclear Power Plants 9.4 Suggested Format for Cash Flow NI O O O Statements Submitted as Guarantees of Payment of Retrospective Payments
- Refer to page D-1 n-29
REGULATORY GUIDES Division 10 Regulatory Guides General Guides Revision in Relates
- Effect to Number Title 1/76 1/80 1/81 10.1 Compilation of Reporting Requirements for Persons Subject to NRC 1 3 3 0 Regulations 10.2 Guidance to Academic Institutions 0 1 1 NA Applying for Specific Byproduct Material Licenses of Limited Scope 10.3 Guide for the Preparation of 0 1 1 O Applications for Special Nuclear Material Licenses of Less than Critical Mass Quantities 10.4 Guide for the Preparation of Appli- 0 1 1 O cations for Licenses to Process Source Material 10.5 Guide for the Preparation of Appli- NI O O O cations for Type A Licenses of Broad Scope for Byproduct Material 10.6 Guide for the Preparation of Appli- NI O O C cations for the Use of Sealed Sources and Devices for the Per-formance of Industrial Radiography 10.7 Guide for the Preparation of Appli- NI 1 1 NA cations for Licenses for Laboratory Use of Small Quantities of Byproduct Material 10.8 Guide for the Preparation of Appli- NI O 1 NA cations for Medical Programs NI NI O NA 10.9 Guide for the Preparation of Appli-cations for Licenses
- Refer to page D-1 D-30
APPENDIX - E PHASE IV FINAL REPORT AND FOURTH UPDATE OF THE ENERGY EC.0NOMIC DATA BASE (EEDB) PROGRAM A
APPENDIX E DESCRIPTION OF REACTOR TYPES AND THEIR FUEL CYCLES In the course of the NUS Corporation study, performed for the fuel cycle eval-uation in the EEDB Initial Update, the economics for the fuel cycles of a number of reactor types and their options were reviewed. The material pre-sented here covers only those reactor types and options previously defined for the establishT.ent of the EEDB, and are summarized in Table E-1. Table E-2 gives a brief summary of the basic features of the baseline reactor types and their fuel cycle. A determination is made that differences between the two LWR types, the Boiling Water Reactor (BWR) and the Pressurized Water Reactor (PWR), have a relatively insignificant effect on the overall fuel cycle costs. Consequently, in performing the fuel cycle cost study, NUS Corporation, with the concurrence of USDOE and United Engineers, agreed that data developed for the PWR cases also apply to the BWR, The fuel cycle cost calculations are based on the NASAP reactor design data. The rated powers of the nuclear systems studied in EEDB differ in some cases f rom the nominal thermal powers listed for the NASAP systems in Table E-1. , However, the mass flow relationships remain unchanged for a determinate reactor type over a relatively large range of output power. Thus, although the total mass of fuel used (200 MTU vs. 150 MTU) is dif ferent .for two PWRs of dif ferent thermal power, the level of initial enrichment ( ~ 37.) , the l average burnup (30,000 mwd /T) and the heat rate (10,200 Beu/kWh) are approxi-mately the same. Therefore, the total cost of fuel is different, but the 1 specific costs in $/M3tu or nills /kWh, are the same for the same p.ortions of the nuclear fuel cycle. Consequently, the differences between the EEDB nuclear systems rated power and the nominal NASAP rated power do not affect E-1
6 the calculated costs of the nuclear fuel cycle for the reactor types studied.
- As noted in the preceding paragraph, the real differences between the PWR and the BWR are insufficient to change the calculated costs for LWRs by a signi-ficant amount.
E.1 LIGHT WATER REACTORS Light water reactors, operating primarily on the thermal neutron spectrum, 4 include the Boiling Water Reactor (BWR), and the Pressurized Water Reactor (PWR). The differences between the two reactor types with respect to the fuel cycle are relatively minor. In general, the BWR carries the burnup of its fuel, in terms of megawatt-days-per-ton, to a lower final level than the PWR. Related to this, are the differences in initial enrichment for the two reactor types, with the BWR having enrichments around 2.7 to 2.8 weight percent and the PWR having enrichments between 3.0 and 3.3 weight percent of fissile U-235. A summary of a typical PWR design and a schematic of the PWR fuel cycle for both the disposal case and for the fuel reprocessing case are shown in
. Table E-3 and Figure E.1. A summary of a. typical BWR design and a schematic of the BWR fuel cycle for both the disposal case and the fuel reprocessing case are shown in Table E-4 and Figure E.1.
The calculation of fuel cycle costs is based on equilibrium operation. The l equilibrium operation assumes approximately uniform exposure of each batch of nuclear fuel. A batch is a quantity of reactor fuel which is some substantial fraction (0.25 - 0.33) of the total reactor core load. At initial plant start-up, a fully loaded core is in place. After about one year of operation, a E-2
I l 1 fraction of the core is replaced with fresh fuel. At intervals of about one year thereafter, additional equal core fractions are removed and replaced with fresh fuel, until the entire initial core has been replaced. Assuming that the core fraction removed / replaced is approximately one-third of the full core loading and that the reload interval is one year, the first segment of the initial core receives an exposure of one year and the last segment is exposed for three years. Subsequently, each batch is operational for about three years prior to replacement. Data for the PWR were obtained from Combustion Engineering, Inc. for the system designed by them. Data for the BWR system were obtained fror General Electric Company. The sources of data for the LWRs and the remaining r'eactor fuel cycles, discussed in this appendix, are given in Table E-5. E.2 THE HIGH TEMPERATURE GAS COOLED REACTOR - HTGR The plant design of the HTGR, as well as the fuel block configuration, permits l ) a variety of fuel loadings in various configurations within the reactor core without changes in the plant design. The initial charge for the HTGR uses enriched uranium at an enrichment level of approximately 19.8 weight percent U-235. The balance of the fuel in these fuel rods is U-238. The chemical form of the fuel, unlike that used in the LWR, is uranium carbide. In addi-tion to the uranium carbide fuel, other fuel elements can be made containing various mixtures of fissile or fertile materials. In the ideal case for the HTGR, the fertile material is thorium oxide. Neutron capture in the abundant (approximately 100 percent in nature) Th-232, produces a small number of ' fissions but results primarily in captures leading to Th-233. Upon beta E-3 i a
. - - - - - - ,-n. , - . . , , , _ _ - - - - , - - , . , , . - - . - -
t, decay, Th-233 becomes Pa-233, which also und'ergoes beta decay to become U-233. U-233 is a thermally fissile material suitable for use in thermal reactors as a direct substitute for U-235, the only thermally fissile material occurring naturally. Since the overall abundance of thorium in the earth's crust is believed to be about ten times that of uranium, the potential for converting significant portions of this material to U-233 is important. The mass flow characteristics for the HTGR are given in Table E-6. A schematic of the
" throw-away" cycle and the U-233 recycle are shown in Figure E.2. Only one full scale version of this reactor type has been operated in the United States. This is the Fort St. Vrain reactor in Colorado, which embodies a number of technological innovations, as well as the use of the HTCR fuel cycle.
Information on the HTGR was provided by General Atomic Company. E.3 THE PRESSURIZED HEAVY UATER REACTOR (PHWR) The PHWR, in the Initial Update of the EEDB, is also referred to as the CANDU Heavy Water Reactor. (The acronym CANDU is derived from Canada Deuterium Uranium). It is based upon the concept of using natural uranium in a heavy water environment, which serves as the moderator, with very low neutron absorption. Reactors of this type have been designed and built by Atomic Energy of Canada Limited. In the CANDU reactor, the. fuel elements are con-tained within pressure tubes along with their coolant. The pressure tubes are submerged in the heavy water moderator which totally separates the internal, pressurized water from the moderator. The initial concept of the-CANDU/PHWR envisioned a reactor -using natural uranium fuel, which is uranium with the natural content of U-235, approximately 0.711 weight percent. More recent concepts have been investigated which use low enrichments, up to E-4
6 a level of about 1.2 weight percent U-235, in the reactor fuel. The low level of enrichment does not permit high burnup, but the reactor does~ achieve good utilization of the slightly enriched uranium. Consequently, the slightly-I enriched concept may yield a significant reduction in fuel cycle costs, compared to a natural uranium cycle. As shown in the fuel cycle schematic, Figure E.3, as well as the design char-1. acteristics, Table E-7, the PHWR/CANDU is operated without intentional re- ) cycle (i.e., without recovery of the U-238 or any bred plutonium which may be present in the spent fuel at the end of its cycle through the reactor). A ' batch of fuel remains in the PHWR/CANDU reactor for approximately one cycle of 3-1/4 years before being replaced by a fresh batch. No reactors of the ! - PHWR/CANDU type have yet been built in the United States. Data for the PHWR were provided by Combustion Engineering, Inc. E.4 THE LIQUID METAL FAST BREEDER REACTOR - LMFBR As the name of the reactor indicates, the LMFBR utilizes liquid metal coolant in the current design and fission is produced by neutrons having a fast spectrum, nominally in excess of 0.1 MeV. The fuel for the UTEBR is primarily fissile plutonium, mixed with depleted uranium U-238, having a content of fissile U-235 of 0.2 weight percent or less. In addition to the fissile fuel elements in the reactor core, blankets of fertile material are placed both top and bottom and around the periphery of the active core. These fertile blankets can contain additional depleted U-238 or natural thorium Th-232. The term breeder for this reactor type arises fro ~m its ability to produce more fissile material than is consumed. This yields a net gain of fissile material f rom previously non-fissile material with each refueling. E-5
The breeder thus permits the utilization of the much more abundant non-fissile isotope U-238, by converting it to fissile plutonium and converting the non-fissile Th-232 to the fissile U-233. This augmentation of the fissile fuel resources extends the potential for producing power from fissile reactions, significantly beyond the time range of any alternative power source now envisioned, except that of the sun or pcwer from the fusion of the hydrogen isotopes. The function of the UHFBR is twofold:
- a. To produce electric power through conversion of fission heat energy to steam and, subsequently through a steam turbine, to electricity; and
- b. to produce more fissile material than is consumed in the operation of the reactor.
For this second reason, the LMTBR is intrinsically committed to reprocessing of both fuel and blanket materials, since the recovery of fissile material i from these sources is required for continuing operation of existing reactors.
- The data for two of the principal options of the UHFBR type are given in i
Table E-8. A schematic flow diagram of these two options is given in Figure E.4. The CHFBR fuel cycle permits a number of options, including: e The fertile U-238 in the blankets can consist of uranium depleted in U-235 to levels produced as " tails" from the en-I richment plants or as uranium recovered from reprocessing of LWR spent fuels. 4 E-6
P e In addition, thorium can be used as a fertile blanket material (as noted in the preceding paragraphs). This is usually fresh, unirradiated material, but at lea'ts in theory, the irradiated Th can be recovered and recycled. However, a cooling period of about 10 years is needed to insure that some of the more ob-jectionable induced activities have decayed. There is presently no firm plan to use U-233 bred from Th-232 in the LMFBR. The neutronic behavior of Pu (FIS) with fast neutrons, is signifi-cantly better in the LMFBR than that of U-233. Conversely, the neutronic behavior of U-233 with thermal neutrons is superior to all other fissile nuclides and insures its use in thermal reactors rather than in breeders. e The LMFBR operates on a fast neutron spectrum and its efficiency is not compromised by the ingrowth.of fission products of high cross-section, but it is not now clear how the fuel reprocessing l and separation will be handled. The recovery of plutonium l from the core and frqm the fertile blanket can be carried through to the point where essentially pure plutonium is obtained. There is concern that unadulterated plutonium or other fissile material will somehow find its way into the hands of terrorists or other antisocial groups. There are options in which Pu can be mixed again with the fertile blanket and fission products can be retained rather than removed, thus making the finished fuel elements far more difficult to fabricate and significantly reducing the risk cf diversion by sub-national groups for use in nuclear weapons. ' The fabrication of fuel using the unspiked mixed oxides of uranium and plu-tonium is significantly more expensive than for uranium oxide fuel. The deliberate addition of fission products (" spiking") will further increase costs. Similarly, the reprocessing of spent fuels is complicated if the fission products are not initially removed, as high level waste, from the uranium and plutonium. The option to retain some level of fission product activity in the reprocessing plant product, also requires the use of properly shielded equipment at all points in the processing line. This is compared to a reprocessing flow sheet which removes the high level fission product wastes and delivers essentially clean uranium and plutonium either intermixed or separated from each other. E-7
i These options make it difficult to present a consistent figure for: e the cost of fuel fabrication for plutonium fuels, e the cost of fuel reprocessing which may include co-processing and spiking, and e the cost of shipping mixed oxide and spiked fuels. The technical data, mass flows, and schematic flow diagrams for the LMFBR were provided by Argonne National Laboratory, the Hanford Engineering Devel-
, opment Laboratory and the U.S. Department of Energy.
E.5 THE GAS COOLED FAST BREEDER REACTOR - GCFR The Gas Cooled Fast Breeder Reactor incorporates features which are common
,co the HTGR (see paragraph E.2) and to the LMFBR (see paragraph E.2). The coolant for the GCFR is helium gas at high pressure. The fission reaction depends primarily on fast neutrons. The fuel, which is Euperficially similar to LMFBR fuel, is designed to be plutonium with blankets of either uranium or thorium. The design characteristics of the CCFR are summarized in Table E-9. The flow diagram for the GCFR is the same as for the LMFBR and is shown in Figure E.4 The design data for the GCFR and for its flow sheet were provided by General Atomic Company.
?
1 l l i 1 l
\
E-8 1 i [. ~-
. \ .l TABLE E-1 ENERGY ECONOMIC DATA BASE REACTOR TYPES, CYCLE, RATING, AND START-UP DATE i
(t) NOMINALW START-UP NASAP THEPML DATE REACTOR TYPE CYCLE RATING 1 JANUARY AND CYCLE DESIGNATION (MWt) + YEAR LWR (Browaway) US(LE)/U-T 3800 1987 LWR (Pu Recycle) US(LE) + Pu(RE)/U 3800 1991 HTGR (Throwaway) U5/U/Ih-207.-T 3360 1995 HTGR (233U Recycle) US (DE)/U/W-207. 3360 1995 PINR (Throwaway) US (NAT)/U-T 3990 1995 (CANDU - NAT. U) PfMR (Throwaway) US (SE)/U-T 3990 (CANDU - Slightly 1995 Ehriched - 1.27.) UEBR (U Blanket) Pu/U/U/U-HT 3318 2001 LMFBR (Th Blanket) Pu/U/Th/Ih-HT 3411 2001 GCFR (U Blanket) Pu/U/U/U 3290 2001 GCFR (Th Blanket) Pu/U/Ih/Th 3290 2001 l (1) Nonproliferation Alternate Systems Assessment Program. (2) The nominal thermal ratings may not agree with the actual ther=al ratings selected for the EEDB. E-0
T,._ ..r: E-2 EWERCY ECONOMIC IMTA BASE BASIC FEATURES OF BASEI.INE REACTOR / RIEL, CYCLE SYSTEMS Reactor System nermal Reactor Designation Fuel Cycle Output Start Reactor Type Fuel Type Alternative (HWt) Date IVR-US(II)/U-T LWR (IMR) low-enriched uranium throwaway 3800 Jan. 1, 1987 (UO2 ) t IMR-US(II)+ IRR(IMR) low-enriched uranium recycle of Pu(RE)/U 3800 Jan. 1, 1991 and plutonium oxide plutonium and (UO2 - Puo2) uranium (self-generated) IITGR- IITCR medium-enriched throwaway 3360 Jan. 1, 1995 U5/U/n-20%-T uranium (20%) and thorium (UC 2 -n02 ) IITCR- IITCR medium-enriched recycle of U-233 3360 Jan. 1, 1995 US (DE) Al/Th-207 uranium (denatured (self-generated) M 20%) and thorium J. (UC2-Th02) O PilWR- FIIWR natural uranium (UO2) throwaway 3990 Jan. 1, 1995 US(NAT)/U-T (CANDU) PIIWR- PilWR slightly-enriched (1.27.) throwaway 3990 Jan. 1, 1995 U5(SE)/U-T (CANDU) uranium (UO2 ) INFBR- IRFBR Pu/ depleted uranium- recycle of plutonium 3318 Jan. 1, 2001 Pu/U/U/U-IIT core, and depleted in breeders uranium-blankets (Puo2-UO2 /UO2 /UO2 ) IRFBR- LMFBR Pu/ depleted uranium- recycle of plutonium 3411 Jan. 1, 2001 Pu/U/n/n-IIT core, and thorium blankets in breeders, recycle (Puo2-UO2/n 02/Th02 ) of U-233 in converters CCFR-Pu/U/U/U CCFR Pu/ depleted uranium- recycle of plutonium 3290 Jan. 1, 2001 core, and depleted in breeders uranium blankets (Puo2-UO2/UO2/1102) CCFR-Pu/U/n/Th CCFR Pu/ depleted uranium-
~
recycle of plutonium 3290 Jan. 1, 2001 core, and thorium- in breeders, recycle blankets of U-233 in converters - (pug 2-UO2/n 02/n 02)
TABLE E-3 ENERGY ECONOMIC DATA BASE DESIGN CHARACTERISTICS OF PWR PWR-US(LE)/U-T I%'R-US (LE)+Pu (RE) /U Disposal Recycle Reactor Thermal Output 3,800 MWt 3,800 MWt Number of Fuel Assemblies 241 241 Fuel Type Oxide Fuel (UO2) Oxide Fuel (UO2 /Pu02-UO2) Approximate Fraction of Core Replaced at Each Refueling 1/3 1/3 Start of Plutonium Recycle N/A Cycle 4 Initial Core (Average) Discharge Burnup - 21,082 MWD /MTU 21,077 MWD /MTU Core Loading 99.313 MTU 99.313 MTU Fresh Fuel Enrichment 2.22 w/o U-235 Spent Fu'el Enrichment 2.22 w/o U-235 0.73 w/o U-235 0.73 w/o U-235 Fissile Plutonium Discharged 5.427 Kg/MTUt 5.246 Kg/MTU t Replacement Loadings Lischarge Burnup 30,360 MWD /MTU 30,360 MWD /MTH Core Loading 102.783 }frU 102.782 Fresh Fuel Enrichment 3.01 w/o U-235 3.30 w/o *) Fissile Plutonium Charged --- 9.807 Kg/tfrHi Spent Fuel Enrichment 0.85 w/o U-235 0.76 w/o U-235(**) Fissile Plutonium Discharged 6.596 Kg/MTUi 10.887 Kg/MTHi (*) Mixture of 3.20 w/o U-235 (22319 Kg), natural uranium (11387 Kg), and 336 Kg of fissile plutonium, per batch. (**) Mixture of 0.95 w/o U-235 (21627 Kg) and 0.39 w/o U-235 (11154 Kg), per batch. E-11
TABLE E-4 ENERGY ECONOMIC DATA BASE - DESIGN CHARACTERISTICS OF BWR Disposal Recycle Reactor Ther=al Output 3,579 Wt 3,579 Wt ' Number of Fuel Assemblies 748 752 Fuel Type Oxide Fuel (UO2) Mixed Oxide Fuel (UO2+Pu02) Approximate Fraction of Core Replaced at Each Refueling 0.25 0.25 Start of Plutoniu= Recycle N/A Cycle 5 Initial Core (Average) Discharge Burnup 17,500 WD/MTU 21,211 W D/MTHM Core Loading 136.136 MIU 136.907 MTHM s Fresh Fuel Enrichment 1.9 w/o 235U 2.16 w/o 235 U Fissile Plutonium Loaded N/A 0.35 w/o FIS Pu Spent Fuel Enrichment 0.7 w/o 235 U (485g$) ' 0.85 w/o 2 U Fissile Plutonium Discharged 4.745 Kg/HTUt 7.178 Kg/MTHM t Replacement Loadings Discharge Burnup 28,400 MWD /MTU 28,010 WD/MTHM Core Loading 156.032 MTHM Fresh Fuel Enrichment 136.136 g35 2.8 w/o U l.84 w/o 235 g Fissile Plutonium Loaded N/A 1.29 w/o FIS Pu (2016 Kg) Spent Fuel Enrichment 0.8 w/o 235 U 0.66 w/o 235 U Fissile Plutonium Discharged 8.242 Kg/MTUt 11.818 Kg/MTHM t (1) Data not available for fuel cycle cost calculations; included for comparison only. E-12
TABLE E-5 ENERGY ECONOMIC DATA BASE FUEL CYCLE DATA SOURCE BY REACTOR TYPE i 1 a SYSTEM DA'TA REACTOR DESIGNED PROVIDED TYPE BY BY PWR Combustion Engineering Combustion Engineering i I BWR General Electric General Electric HTCR General Atomic General Atomic PHWR Combustion Engineering Combustion Engineering LMFBR Argonne National Lab. & Department of Energy Hanford Engineering Development Lab.
. GCFR General Atomic General Atomic
- Mass flow information provided by source indicated through NASAP.
**BWR data not available for fuel cycle costs; PWR data used for BWR (Model A1).
i E-13 1 t ne- , ,- , ~ , . , , - . - - - , , , --- --.-- . . - - , - - - - - - - ---
TAntE E-6 ENERGY ECONOMIC DATA BASE DESIGN CilARACTERISTICS OF HTCR HTCR-US/U/n -207.-T tiTCR-US(DE)/U/Th-207. Reactor lhermal Output 3.360 MWt 3,360 MWt Number of Fuel Blocks 5,288 5,288 Approximate Fraction of Core Replaced at Each Refueling 1/4 1/4 Start of U-233 Recycle --- Cycle 3 Initial Core (Average) Discharge Burnup 52,900 MWD /ttni Core 1.oading 52,925 MWD /MTil C/Th Ratio 41.130 MTH 41.130 Knl 350 350 Thorium Charged 31.802 Nr 31.798 MT Enrichment of Uranium Charged 19.8 w/o U-235 m Enrichment of Uranium 19.8 w/o U-235 & Discharged U-233 Discharged 12.8 w/o* 12.8 w/o* 75.5 Kg/MTUf 75.5 Kg/MTUr Fissile Plutonium Discharged 12.071 Kg/tfruf 12.014 Kg/HTUf Replacement Loadings Discharge Burnup 133,100 MWD /Nnt Core Loading 132,500 MWD /NDI C/Th Ratio 29.504 MTH 29.648 MTH 850 850 n orium Charged 446 Kg/MTHi Enrichment of Uranium Charged 444 Kg/MDit Recycled U-233 Charged 19.8 w/o U-235 19.0 w/o*** Enrichment of Uranium 11.927 Kg/MTHi Discharged U-233 Discharged 4.9 w/o** 4.7 w/o 27.5 Kg/MTUf 28.9 Kg/MTUf Fissile Plutonium Discharged 13.702 Kg/MTUf 13.6,30 Kg/MTUr . Mixture of 625.1 Kg of U-233 and 434.7 Kg of'U-235 in total uranium of 8275.9 Kg discharged. Mixture of 88.3 Kg of U-233 and 69.0 Kg of U-235 in total uranium of 3211.'1 Kg discharged. Mixture of U-235 makeup (696.5 Kg) and U-233 recycled (88.4 Kg) in total uranium loaded (4122.7 Kg).
TABLE E-7 ENERGY ECONOMIC DATA BASE DESIGN CilARACTERISTICS OF PINR PINR-US (NAT) /U PINR-US(SE)/U Reactor Thermal Output 3,990 MWt 3,990 MWt Number of Coolant Channels 380 380 Number of Fuel Bundles per Channel 12 12 Fuel Type Oxide Fuel Oxide Fuel Initial Core (Average) Discharge Burnup 4,759 MWD /KrU 6,556 HWD/MTU Core Loading 148.388 Kru 148.388 MTU Fresh Fuel Enrichment 0.711 w/o U-235 0.711 w/o U-235 i Replacement Loadings Discharge Burnup 6,100 NWD/Kru 19,749 HWD/MTU Annual Requirement 179.059 MTU 55.304 MTU Fresh Fuel Enrichment 0.711 w/o U-235 1.2 w/o U-235 i I f
TABl.E C-8 ENERGY ECONOMIC DATA BASE DESIGN CIIARACTERISTICS OF LMFBR IJtFBR-Pu/U/U/U LMFBR-Pu/U/Th/Th Reactor lhermal Output 3,318 MWt 3,411 MWt Number of Elements core Fuel 678 Axial Blanket 432 678 432 Radial Blanket 420 . 252 Fuel Type Oxide Fuel Oxide Fuel Breeding Ratio 1.1417 N/A Initial Core (Average) Discharge Burnup 45,983 MWD /MTilM 34,650 MWD /MTilM Core Loading 22.668 MTi!M 34.370 KntM Fissile Plutonium Loaded 154.314 Kg/MTili 121.559 Kg/Knli Fissile Plutonium Discharged 136.713 Kg/M1111 117.457 Kg/MTHi Initial Uranium Enrichment 0.20 w/o U-235 0.20 w/o U-235 Final Uranium Enrichment 0.13 w/o U-235 0.15 w/o U-235 Replacement Core Loadings Discharge Burnup 67,590 MWD /KnIM 53,150 MWD /MillM Core Loading 23.316 KnIM Fissile Plutonium Charged 32.994 MTIIM 154.315 Kg/MTili 121.537 Kg/Knli Fissile Plutonium Discharged 134.243 Kg/MTili 116.142 Kg/MTiti Initial Uranium Enrichment 0.20 w/o U-235 0.20 w/o U-235 Final Uranium Enrichment 0.13 w/o U-235 0.13 w/o U-235
TARI.E E-8 (Cont . ) ENERCY ECONOMIC DATA BASE DESIGN CilARACTERISTICS OF LMFBR IJtFBR-Pu/U/U/U INFBR-Pu/U/Th/Th Axial Blanket Loading ! 19.038 MTilM 22.470 MTitM Fissile Plutonium Discharged 22.691 Kg/MTili --- U-233 Discharged --- Initial Uranium Enrichment 18.069 Kg/MTiti 0.20 w/o U-235 --- Final Uranium Enrichment 0.16 w/o U-235 --- 1 Radial Blanket
- Loading 44.796 MritM 42.815 MTHM Fissile Plutonium Discharged 20.895 Kg/M11It ---
m U-233 Discharged --- 4 Initial Uranium Enrichment 16.466 Kg/MTiti
" 0.2 w/o U-235 ---
Final Uranium Enrichment 0.18 w/o U-235 --- A 1 o e
TABLE E-9 ENERGY ECONOMIC DATA BASE DESIGN CIIARACTERISTICS OF CCFR cCFR-Pu/U/U/u ccFR-Pu/U/Th/Th Reactor Thermal Output 3,290 We 3,290 W t Number of Elements Core Fuel 253 253 Axial Blanket 253 253 Radial Blanket 198 198 Fuel Type Oxide Fuel Oxide Fuel Conversion Ratio 1.51 1.48 Initial Core (Average) in ' h Discharge Burnup 50,332 MWD / Mill 50,356 MWD /MTil Core Loading 28.620 Krli 28.982 MTII Fissile Plutonium Loaded 138.539 Kg/MTili 142.330 Kg/MTIII Fissile Plutonium Discharged 127.079 Kg/Mrlit 128.921 Kg/MTili Fresh Uranium Enrichment 0.25 w/o U-235 0.25 w/o U-235 Spent Uranium Enrichment 0.17 w/o U-235 0.17 w/o U-235 Replacement Core Loadings Discharge Burnup 75,576 MWD / Mill 75,574 MWD /MTil Core Loading 28.981 Mrli 23.981 HTII Fissile Plutonium Charged 144.885 Kg/HTili 151.875 Kg/MTiti Fissile Plutonium Discharged 124.471 Kg/M111 1 127.829 Kg/Mrili Fresh Uranium Enrichment 0.25 w/o U-235 0.25 w/o U-235 Spent Uranium Enrichment 0.14 w/o U-235 0.14 w/o U-235
TAlti.E E-9 (Cont.) ENERGY ECONOKiC DATA BASE DESIGN CilARACTERISTICS OF CCFR CCFR-Pu/U/U/U CCFR-Pu/U/Th/Th Axial Blanket Loading 33.0L Mril 28.493 MTil Fissile Plutonium Discharged 28.356 Kg/ Milli --- Fissile U-233 Discharged --- Fresh Uranium Enrichment 31.787 Kg/Mllii Spent Uranium Enrichment 0.25 w/o U-235 --- 0.20 w/o U-235 --- Radial Blanket es Loading 99.305 h Fissile Plutonium Discharged 85.938 Mril 15.591 Kg/HTiti --- Fissile U-233 Discharged --- Fresh Uranium Enrichment 16.868 Kg/Mllig Spent Uranium Enrichment 0.25 w/o U-235 --- 0.22 w/o U-235 --- l 6
f FIGURE E-1 LWR FUEL CYCLE NATURAL 2 MU NE
= ENRICHMENT = FABellCATION 5 PWR l U O REPOSITORY (A) THROW-AWAY CYCLE (PWR-US(LE)/U-T)
?
1 Ei UO 2 NATURAL r SPENT FUEL O ENRICHMENT & FABRICATION U l PWR , O REPROCESSING
= '
PuO2-UO2 Jl il i l Pu FOR RECYCLE U FOR RECYCLE if WASTE DISPOSAL (B) PLUTONIUM AND URANIUM RECYCLE (PWR US(LE) + Pu(RE)/U)
FIGURE E-2 HTGR FUEL CYCLE Th (1) l I NATURAL N I H N 2N2 MM NR U FABRICATION 5 HTGR O REPOSITOW (A) THROW-AWAY CYCLE (HTGR U5/U/Th-20%T) T I 7 p Th (1) I f UC2-Th02 NATURAL Ir SPENT FUEL U = ENRICHMENT & FABRICATION I HTGR a REPROCESSING
='
dI
- g 2:
U-233 FOR RECYCLE m 3 O 2 If (1) THORlUM ADDITIONS ARE GENERALLY MADE FROM FRESH, UNIRRADIATED - MATERIAL DISPOSAL (B) U-233 RECYCLE (HTGR-US (DE)/U/Th-20%) l
FIGURE E-3 PHWR (CANDU) FUEL CYCLE UO 2 SPENT FUEL C FABRICATION U i CANDU C REPOSITORY i
?
tj (A) NATURAL URANIUM THROW AWAY CYCLE (CANDU-US(NAT)/U-T) NATURAL 002 SPENT FUEL U = ENRICHMENT C FABRICATION 5' CANDU l O REPOSITORY (B) SLIGHTLY ENRICHED URANIUM THROW AWAY CYCLE (CANDU-US(SE)/U-T) l
FIGURE E-4 LMFBR/GCFR FUEL CYCLE uO2 (BLANKETS) SPENT FUEL / DEPLETED '
= FABRICATION -{ OR =
U REPROCESSING --
= GCFR PuO 2-UO 2 (CORE) ( A IOACME Il ll l WASTE
' l EXCESS l Pu (1) MAKEUP Pu--- ! ^ "
Jr ] [ OTHER WASTE BREEDERS DISPOSAL (A) URANIUM BLANKETS (LMFBR-Pu/U/U/U-HT OR GCFR-Pu/U/U/U) u Th (2) I Th02 (BLANKETS) SPENT FUEL / DEPLETED r LMFBR BLANKETS U FABRICATION j OR = REPROCESSING -
=' GCFR PuO2-UO2 jl 1g (CORE) RADIOACTIVE ALL l U-233 WASTE pp _j U-238 AND Pu FOR RECYCLE (1) MAKEUP Pu IS SUPPLIED FOR THE INITIAL CORE; RECYCLE Pu IS OTHER WAS TE USED FOR RE-LOAD CORES CONVERTERS DISPOSAL (2) THORIUM ADDITIONS ARE GENERALLY MADE FROM FRESH, UNIRRADIATED MATERIAL (B) THORIUM BLANKETS (LMFBR-Pu/U/Th/Th/ OR GCFR-Pu/U/Th/Th) 9}}